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As
filed with the U.S. Securities and Exchange Commission on March 9, 2022.
Registration
No. 333-________
UNITED
STATES
SECURITIES
AND EXCHANGE COMMISSION
Washington,
D.C. 20549
FORM
F-1
REGISTRATION
STATEMENT UNDER THE SECURITIES ACT OF 1933
Indonesia
Energy Corporation Limited
(Exact
name of Registrant as specified in its charter)
Not
Applicable
(Translation
of Registrant’s name into English)
Cayman
Islands |
|
1311 |
|
Not
Applicable |
(State
or other jurisdiction of
incorporation or organization) |
|
(Primary
Standard Industrial
Classification Code Number) |
|
(I.R.S.
Employee
Identification
number) |
GIESMART
PLAZA 7th Floor
Jl.
Raya Pasar Minggu No. 17A
Pancoran
– Jakarta 12780 Indonesia
+62
21 2696 2888
(Address,
including zip code, and telephone number, including area code,
of Registrant’s principal executive offices)
James
J. Huang
Chief
Investment Officer
GIESMART
PLAZA 7th Floor
Jl.
Raya Pasar Minggu No. 17A
Pancoran
– Jakarta 12780 Indonesia
+62
21 2696 2888
(Name,
address, including zip code, and telephone number, including area code, of agent for service)
Copies
to:
Barry
I. Grossman, Esq.
Lawrence A. Rosenbloom, Esq.
Ellenoff
Grossman & Schole LLP
1345
Avenue of the Americas, 11th Floor
New
York, NY 10105
Tel:
(212) 370-1300
Fax:
(212) 370-7889 |
Approximate
date of commencement of proposed sale to the public: As soon as practicable after the effective date of this registration statement.
If
any of the securities being registered on this Form are to be offered on a delayed or continuous basis pursuant to Rule 415 under the
Securities Act of 1933, check the following box. ☐
If
this Form is filed to register additional securities for an offering pursuant to Rule 462(b) under the Securities Act, please check the
following box and list the Securities Act registration statement number of the earlier effective registration statement for the same
offering. ☐
If
this Form is a post-effective amendment filed pursuant to Rule 462(c) under the Securities Act, check the following box and list the
Securities Act registration statement number of the earlier effective registration statement for the same offering. ☐
If
this Form is a post-effective amendment filed pursuant to Rule 462(d) under the Securities Act, check the following box and list the
Securities Act registration statement number of the earlier effective registration statement for the same offering. ☐
Indicate
by check mark whether the registrant is an emerging growth company as defined in Rule 405 of the Securities Act of 1933. Emerging growth
company ☒
If
an emerging growth company that prepares its financial statements in accordance with U.S. GAAP, indicate by check mark if the registrant
has elected not to use the extended transition period for complying with any new or revised financial accounting standards provided pursuant
to Section 7(a)(2)(B) of the Securities Act.
The
Registrant hereby amends this registration statement on such date or dates as may be necessary to delay its effective date until the
Registrant shall file a further amendment which specifically states that this registration statement shall thereafter become effective
in accordance with Section 8(a) of the Securities Act of 1933, as amended, or until the registration statement shall become effective
on such date as the Commission, acting pursuant to said Section 8(a), may determine.
The
information in this preliminary prospectus is not complete and may be changed. We may not sell these securities until the registration
statement filed with the Securities and Exchange Commission is effective. This preliminary prospectus is not an offer to sell these securities
and we are not soliciting offers to buy these securities in any jurisdiction where the offer or sale is not permitted.
PRELIMINARY
PROSPECTUS |
SUBJECT
TO COMPLETION, DATED MARCH 9, 2022 |
Up
to 9,100,574
Ordinary
Shares
This
prospectus relates to the resale, from time to time, by the selling shareholder named herein (which we refer to herein as the Selling
Shareholder) of (i) an aggregate of up to 8,333,334 of our ordinary shares, par value $0.00267 per share (which we refer to
herein as the ordinary shares), potentially issuable upon the conversion of an outstanding convertible promissory note held by the
Selling Shareholder and (ii) an aggregate of up to 767,240 ordinary shares potentially issuable upon exercise of outstanding warrants
held by the Selling Shareholder (which we refer to herein as the Warrants).
We
are not selling any securities under this prospectus and we will not receive proceeds from the sale of our ordinary shares by the Selling
Shareholder. However, we may receive proceeds from the cash exercise of the Warrants, which, if exercised in cash at the current applicable
exercise price of $6.00 per share with respect to all of the 767,240 ordinary shares, would result in gross proceeds to us of
approximately $4,603,440.
We
will pay the expenses of registering the ordinary shares offered by this prospectus, but all selling and other expenses incurred by the
Selling Shareholder will be paid by the Selling Shareholder. The Selling Shareholder may sell our ordinary shares offered by this prospectus
from time to time on terms to be determined at the time of sale through ordinary brokerage transactions or through any other means described
in this prospectus under “Plan of Distribution.” The prices at which the Selling Shareholder may sell shares will be determined
by the prevailing market price for our ordinary shares or in negotiated transactions.
Our
ordinary shares are traded on NYSE American LLC (or NYSE American) under the symbol “INDO.” On March 8, 2022, the
last reported sale price for our ordinary share on NYSE American was $31.50.
Investing
in our securities is highly speculative involves a significant degree of risk. See “Risk Factors” beginning on page 12 of
this prospectus for a discussion of information that should be considered in connection with an investment in our securities.
Neither
the Securities and Exchange Commission nor any state securities commission has approved or disapproved of these securities or determined
if this prospectus is truthful or complete. Any representation to the contrary is a criminal offense.
The
date of this prospectus is _______________, 2022.
TABLE
OF CONTENTS
You
should rely only on the information contained in this prospectus or in any related free-writing prospectus. Neither we nor the Selling
Shareholder have authorized anyone to provide you with information different from that contained in this prospectus or any free-writing
prospectus. We are offering to sell, and seeking offers to buy, the ordinary shares only in jurisdictions where offers and sales are
permitted. The information contained in this prospectus is current only as of the date of this prospectus, regardless of the time of
delivery of this prospectus or of any sale of the ordinary shares.
We
have not taken any action to permit a public offering of the ordinary shares outside the United States or to permit the possession or
distribution of this prospectus outside the United States. Persons outside the United States who come into possession of this prospectus
must inform themselves about and observe any restrictions relating to the offering of the ordinary shares and the distribution of the
prospectus outside the United States.
We
obtained the statistical data, market data and other industry data and forecasts described in this prospectus from market research, publicly
available information and industry publications. Industry publications generally state that they obtain their information from sources
that they believe to be reliable, but they do not guarantee the accuracy and completeness of the information. Similarly, while we believe
that the statistical data, industry data and forecasts and market research are reliable, we have not independently verified the data,
and we do not make any representation as to the accuracy of the information. We have not sought the consent of the sources to refer to
their reports appearing or incorporated by reference in this prospectus.
PROSPECTUS
SUMMARY
This
summary highlights certain information contained elsewhere in this prospectus. You should read the entire prospectus carefully, including
our financial statements and related notes, and especially the risks described under “Risk Factors” beginning on page 12
of this prospectus. We note that our actual results and future events may differ significantly based upon a number of factors. The reader
should not put undue reliance on the forward-looking statements in this document, which speak only as of the date on the cover of this
prospectus.
All
references to “the Company”, “we,” “us,” “our,” or similar terms used in this prospectus
refer to Indonesia Energy Corporation Limited,
a Cayman Islands exempted company with limited liability, including its consolidated subsidiaries, unless the context otherwise indicates.
In addition, references in this prospectus to “Government” refer to the government of Indonesia and its agencies.
Please
see “Glossary of Terms” for a listing of oil and gas-related defined terms used throughout this prospectus.
Overview
We
are an oil and gas exploration and production company focused on the Indonesian market. Alongside operational excellence, we believe
we have set the highest standards for ethics, safety and corporate social responsibility practices to ensure that we add value to society.
Led by a professional management team with extensive oil and gas experience, we seek to bring forth at all times the best of our expertise
to ensure the sustainable development of a profitable and integrated energy exploration and production business model.
Our
mission is to efficiently manage targeted profitable energy resources in Indonesia. Our vision is to be a leading company in the Indonesian
oil and gas industry for maximizing hydrocarbon recovery with the minimum environmental and social impact possible.
We
currently have rights through contracts with the Indonesian government to one oil and gas producing block (called Kruh Block) and one
oil and gas exploration block (called Citarum Block). We have also identified a potential third exploration block, known as the Rangkas
Area, and we may seek to acquire or otherwise obtain rights to additional oil and gas producing assets.
We
produce oil through a subsidiary which operates the Kruh Block under an agreement with PT Pertamina (Persero), the Indonesian state-owned
oil and gas company (or Pertamina). Our operatorship Kruh Block runs until May 2030 under a ten year Joint Operation Partnership (or
KSO) with Pertamina. Kruh Block covers an area of 258 km2 (63,753 acres) and is located onshore 16 miles northwest of Pendopo,
Pali, South Sumatra.
Citarum
Block is an exploration block covering an area of 3,924.67 km2 (969,807 acres). This block is located onshore in West Java
and only 16 miles south of the capital city of Indonesia, Jakarta. Our rights to Citarum Block run until July 2048 under Production Sharing
Contract (or PSC) agreement with the Indonesian Special Task Force for Upstream Oil and Gas Business Activities (known as SKK Migas).
We
were incorporated on April 24, 2018 as an exempted company with limited liability under the laws of the Cayman Islands and are a holding
company for WJ Energy Group Limited (or WJ Energy), which in turn owns our Indonesian holding and operating subsidiaries.
Indonesia’s
Oil and Gas Industry and Economic Information
The
largest economy in Southeast Asia, Indonesia (located between the Indian and Pacific oceans and bordered by Malaysia, Singapore, East
Timor and Papua New Guinea) has charted impressive economic growth since overcoming the Asian financial crisis of the late 1990s. The
Indonesian economy continued to recover in 2021 despite moderating due to the COVID-19 Delta variant wave mid-year. The Indonesian economy
is estimated to have expanded 3.7 percent during 2021 and is forecast to accelerate to 5.2 percent in 2022, according to the World Bank.
Today, Indonesia is the world’s 10th largest economy, a member of the G-20 and the world’s fourth most populous
nation with a population, according to the Central Intelligence Agency’s World Factbook, as of July 2021 of over 275 million. Indonesia
also has a prominent presence in other commodities markets such as thermal coal, copper, gold and tin, with Indonesia being the world’s
second largest tin producer and largest tin exporter, as well as in the agriculture industry as a producer of rice, palm oil, coffee,
medicinal plants, spices and rubber according to the Indonesia Commodity & Derivatives Exchange and the World Factbook.
The
Indonesian oil and gas industry is among the oldest in the world. Indonesia has been active in the oil and gas sector for over 130 years
after its first oil discovery in North Sumatra in 1885. The major international energy companies began their significant exploration
and development operations in the mid-20th century. According to the Special Taskforce for Upstream Oil and Gas Business Activities
(SKK Migas – Satuan Kerja Khusus Pelaksana Kegiatan Usaha Hulu Minyak dan Gas Bumi) Annual Report 2020 and the BP Statistical Review
of World Energy 2021, Indonesia held proven oil reserves of 2.44 billion barrels at the end of 2020. According to its public filings,
Chevron has been very active in Indonesia for over 50 years. Chevron has produced a very large amount of oil — 12 billion barrels
— over this period with billions of those barrels having been produced in Sumatra (the location of our Kruh Block, as described
below).
According
to the BP 2021 Report, Indonesia’s oil consumption in 2020 reached 1.45 million barrels per day, 51% of which was met by domestic
production. The MEMR specified that Indonesia exported 31.45 million barrels of oil and imported 79.69 million barrels of oil in 2020.
SKK Migas recorded Thailand and Singapore as the top two countries Indonesia exported oil and condensate to in 2020, respectively at
10.18 million barrels and 4.13 million barrels.
Further,
we believe that Indonesia’s expanding economy, in combination with the government’s intention to lower reliance on coal as
a source for energy supply in industries, power generation and transportation, will cause Indonesian domestic demand for gas to rise
in the future. Indonesia’s power infrastructure needs substantial investment if it is not to inhibit Indonesia’s economic
growth. According to the MEMR 2020 Report, generating capacity at the end of 2020 was standing at around 72.8 gigawatts or an increase
of 4.5% compared to 69.7 gigawatts generating capacity in 2019. According to the 2017 Indonesian General National Energy Plan, the Government
has targeted an increase in power generation capacity to 190 gigawatts in 2030 and 443 gigawatts in 2050 to keep up with the electricity
demand from Indonesia’s growing middle class population and its manufacturing sector. The Indonesian Secretariat General of National
Energy Council has reported that Indonesia’s gas demand is estimated to rise from 1.67 TCF in 2015 to 2.45 TCF in 2025 with the
bulk of demand originating from Java and Bali, particularly for power stations and fertilizer plants.
According
to Indonesia Energy Outlook 2020, a report published by the Indonesian Agency for the Assessment and Application of Technology, from
2018 to 2050, Indonesia’s total energy demand is expected to grow at an average rate of 3.9% per year. For the same period, natural
gas demand average growth rate is estimated at 3.8% per year, industrial sector energy demand average growth rate is expected at 4.4%
per year and total electricity demand is expected to increase 630% by 2050, with 24% of it will be generated by gas.
In
terms of gas distribution, Indonesia still lacks an extensive gas pipeline network because the major gas reserves are located away from
the demand centers due to the particular territorial composition of the archipelagic state of Indonesia. Indonesian gas pipeline networks
have been developed based on business projects; thus, they are composed of a number of fragmented systems. The developed gas networks
are located mostly near consumer centers. Total gas transmission and distribution pipeline infrastructure in 2020 was 15.725,06 km, which
is 6.51% higher compared to 2019 but still 46% lower compared to 2019 additional pipeline length. By
2024, Indonesia is expected to have a total of 17,300 km of gas pipeline network according to Oil and Gas Downstream Regulatory Agency
(BPH MIGAS) 2020 Performance Report.
In
West Java, where the Citarum Block is located, the total natural gas demand is expected to increase significantly from 2,521 MMSCFD in
2020 to 3,032 MMSCFD by 2035 according to Petromindo, an Indonesian petroleum, mining and energy news outlet. This will require
additional gas supply of 603 MMSCFD in 2020 and 1,836 MMSCFD in 2028 including import. Being relatively low-carbon compared to coal,
as well as being medium-cost, gas is likely to remain a favored fuel for at least the next decade, especially given Indonesia’s
extensive gas reserves. Moreover, energy demand in Indonesia is expected to increase as Indonesia’s economy and population grow.
Our
Opportunity
Beginning
in 2014, our management team identified a significant opportunity in the Indonesian oil and gas industry through the acquisition of medium-sized
producing and exploration blocks. In general terms, our goal was to identify assets with the highest potential for profitable oil and
gas operations. As described further below, we believe that our two current assets — Kruh and Citarum — represent just these
types of assets.
We
believe these medium-sized blocks were available for two main reasons: (i) a general lack of investment in the industry by smaller companies
such as ours and (ii) the fact that these blocks are overlooked by the major oil and gas exploration companies; many of which operate
within Indonesia.
The
fundamentals for the lack of investment in our target sector are the industry’s intensive capital requirements and high barriers
to entry, including high startup costs, high fixed operating costs, technology, expertise and strict government regulations. We have
and will continue to seek to overcome this through the careful deployment of investor capital as well as cash from our producing operations.
In
addition, the medium-sized blocks we target are overlooked by the larger competitors because their asset selection is subject to a higher
threshold criterion in terms of reserve size and upside potential to justify the deployment of their human resources and capital. This
means that a very small company is not capable of operating these blocks, a new investor is unlikely to enter this sector and the major
producers are competing for the larger assets.
This
scenario creates our corporate opportunity: the availability of overlooked assets including producing and exploration projects with untapped
potential resources in Indonesia that creates the potential to both generate economic profit and expand our operations in the years to
come.
An
important fact is that, since we started our operations in 2014, the natural resources industry has gone through a dramatic change due
to oil price volatility. The challenges imposed by low oil prices during this period created an incentive for us to operate efficiently
by driving our business to make the most use of the resources available within our organization to lower costs and improve operational
productivity. More recently, with an improvement in oil prices, we believe are in a good position to take advantage of our lower producing
costs.
Recent
Developments
Drilling
and Production at the Kruh Block
With
respect to our drilling program at Kruh Block, in March 2021 we announced our plan to drill a total of 5 wells in 2021, 6 wells in 2022
and 7 wells in 2023, for a total of 18 new wells on Kruh Block. Due to delays in the Government permitting process and COVID-19-related
delays experienced during 2021, our overall drilling program for Kruh Block has similarly been somewhat delayed. We continue to carry
on with our plan on drilling 18 new wells at Kruh Block, but now through 2024 rather than 2023. We completed the drilling of 2 of those
wells in 2021 with the additional 16 more wells expected during the course of 2022 through 2024 as described further below.
We
commenced the drilling of a well named “Kruh-25” at Kruh Block on April 21, 2021 and another well named “Kruh-26”
at Kruh Block on August 22, 2021. As a result of our successful drilling program at Kruh-26, our production rate increased by over 50%
from approximately 160 barrels of oil per day during the first 10 months of 2021 to approximately 245 barrels of oil per day as of late
December 2021. Kruh 25 has not reached its optimal production rate as a result
of significant damage due to flooding during an extended period of heavy monsoon rain in 2021, leading to extremely difficult working
conditions caused by a deteriorated drill site and inadequate equipment performance. We are currently conducting remedial workover activities
at Kruh 25 so that it can attempt to match the results of the Kruh-26 well. We will use Electrical Enhanced Oil Recovery (or EEOR), an
electro kinetic process to improve oil recovery, to help remedy the damage in K-25 reservoirs. Such technique improves viscosity of fluids
by electrochemical reactions such as oxidation and reduction (REDOX reactions). Our other existing producing wells at Kruh Block could
also potentially benefit from this technique.
We
recently provided an update on our 2022 drilling plans and we now expect to commence drilling of our next 2 new wells at Kruh Block in
the first quarter of 2022. Additionally; we plan to commence drilling of a third new well at Kruh Block before the end of the second
quarter of 2022. Drilling operations for these three new wells (named “Kruh-27”, “Kruh-28” and “Kruh-29”)
are being funded from the net proceeds of our January 2022 institutional investor financing from L1 Capital described below (L1
Capital is the Selling Shareholder named in this prospectus). We may seek to start an additional well in 2022 if conditions permit.
L1
Capital Financing
On
January 21, 2022 (the “Initial Closing Date”), we closed an initial $5.0 million tranche (the “First Tranche”)
of a total anticipated $7.0 million private placement with L1 Capital Global Opportunities Master Fund, Ltd. (“L1 Capital”)
pursuant to the terms of Securities Purchase Agreement, dated January 21, 2022, between L1 Capital and us (the “Purchase Agreement”).
In
connection with the closing of the First Tranche, we issued to L1 Capital (i) a 6% Original Issuance Discount Senior Convertible Promissory
Note in a principal amount of up to $7,000,000 (which was subsequently expanded to $10,000,000 as described below, the
“Note”) and (ii) a five year Ordinary Share Purchase Warrant (the “Initial Warrant”) to purchase up to 383,620
of our ordinary shares at an exercise price of $6.00 per share, subject to adjustment. The Purchase Agreement and the Note were amended
on March 4, 2022 as described below (the “L1 Amendment”).
Within
two (2) trading days of the declaration of effectiveness of the registration statement of which this prospectus forms a part, and subject
to the satisfaction of certain conditions precedent, a second tranche of funding under the Note (the “Second Tranche”) shall
be provided by L1 Capital in the principal amount of $5,000,000 (which had been $2,000,000 prior to the L1 Amendment). Such principal
amount, if funded, will be added to the principal amount of the Note, and L1 Capital will be entitled to receive an additional Ordinary
Share Purchase Warrant (carrying the same terms as the Initial Warrant) (the “Second Warrant” and collectively with the Initial
Warrant, the “Warrants”) to purchase up to 383,620 ordinary shares (which had been 153,450 prior to the L1 Amendment),
if the full amount of the Second Tranche is funded, at an exercise price of $6.00 per share, subject to adjustment.
The
amount of the Second Tranche, and the corresponding number of ordinary shares underlying the Second Warrant, is subject to reduction
if the principal amount of the Note (after funding the Second Tranche) would be 20% or more of our then current market
capitalization on the trading day following the date of effectiveness of the registration statement of which this prospectus forms a
part (this percentage was 25% prior to the L1 Amendment).
On
March 4, 2022, in connection with the L1 Amendment, we entered into a First Amendment to the Purchase Agreement with L1 Capital (the
“SPA Amendment”) and an Amended and Restated Senior Convertible Promissory Note, which amends and restates the original Note
in its entirety (the “Replacement Note”), to memorialize the following amendments to the terms of the financing transaction:
1.
The amount of the Second Tranche was increased from $2,000,000 to $5,000,000 (less a 6% original issuance discount as provided for in
the original Note) (the “New Second Tranche Amount”).
2.
Because of the increase in the Second Tranche Amount, at the closing of the Second Tranche, L1 Capital will be entitled to receive a
Warrant (the “Second Warrant”) to purchase up to 383,620 Ordinary Shares (rather than 153,450 Ordinary Shares per the initial
terms, and assuming the full New Second Tranche Amount is funded) at an exercise price of $6.00 per share, subject to adjustment.
3.
Without the prior approval of L1 Capital, we will be restricted in issuing new ordinary shares or ordinary share equivalents (subject
to certain exceptions) during the period from March 4, 2022 through the date that is seven (7) trading days after the registration statement
of which this prospectus forms a part is declared effective; provided that this restriction will not apply if then trading price of our
ordinary shares is over $9.00 with average five (5) day trading volume of 500,000 shares.
4.
The New Second Tranche Amount, and the corresponding number of ordinary shares underlying the Second Warrant, is subject to
reduction if the principal amount of the Replacement Note (after funding the Second Tranche) would be 20% or more (as opposed to 25%
as provided for in the original Note) of our market capitalization on the trading day following the date of effectiveness of the
registration statement of which this prospectus forms a part.
All
references in this prospectus to the “Note” shall refer to the Replacement Note unless the context expressly indicates otherwise.
Amendments
to Employment Agreements
On
January 21, 2022, we entered into a Second Amendment to Employment Agreement (the “Ingriselli Second Amendment”) with Frank
C. Ingriselli, our President. The effective date of the Ingriselli Second Amendment is January 1, 2022. The Ingriselli Second
Amendment amends that certain Employment Agreement between Mr. Ingriselli and us, effective February 1, 2019, as amended by that certain
First Amendment to Employment Agreement, effective as of February 1, 2020 (the “Ingriselli Agreement”).
Pursuant
to the Ingriselli Second Amendment: (i) the term of the Ingriselli Agreement was extended to December 31, 2023, unless terminated earlier
pursuant to the terms of the Ingriselli Agreement; and (ii) Mr. Ingriselli was granted an award of 60,000 ordinary shares, with 30,000
shares vesting on July 1, 2022 and 30,000 vesting on January 1, 2023, with a lock-up period of 180 days from each vesting date.
On
January 21, 2022, we entered into a Second Amendment to Employment Agreement (the “Overholtzer Second Amendment”) with Gregory
Overholtzer, our Chief Financial Officer. The effective date of the Overholtzer Second Amendment is January 1, 2022. The Overholtzer
Second Amendment amends that certain Employment Agreement between Mr. Overholtzer and us, effective February 1, 2019, as amended by that
certain First Amendment to Employment Agreement, effective as of February 1, 2020 (the “Overholtzer Agreement”).
Pursuant
to the Overholtzer Second Amendment, the term of the Overholtzer Agreement was extended to December 31, 2023, unless terminated earlier
pursuant to the terms of the Overholtzer Agreement.
No
further changes were made to either the Ingriselli Agreement or the Overholtzer Agreement.
Option
Exercises
On
March 3, 2022, with the approval of the Compensation Committee of our board of directors, certain of our executive officers exercised
vested options to purchase restricted ordinary shares on a “cashless exercise” basis. The following table shows the ordinary
shares issued to these officers upon such exercise:
Optionee | |
Vested Options Exercised | | |
Option Exercise Price | | |
Closing Price on March 3, 2022 | | |
Net Shares Received Upon Exercise | |
Wirawan Jusuf | |
| 100,000 | | |
$ | 11.00 | | |
$ | 20.20 | | |
| 45,545 | |
James J, Huang | |
| 100,000 | | |
$ | 11.00 | | |
$ | 20.20 | | |
| 45,545 | |
Mirza Said | |
| 100,000 | | |
$ | 11.00 | | |
$ | 20.20 | | |
| 45,545 | |
Chia Hsin “Charlie” Wu | |
| 100,000 | | |
$ | 11.00 | | |
$ | 20.20 | | |
| 45,545 | |
Frank Ingriselli | |
| 37,500 | | |
$ | 11.00 | | |
$ | 20.20 | | |
| 17,079 | |
Total | |
| 437,500 | | |
| | | |
| | | |
| 199,259 | |
All
references herein to our ordinary shares outstanding as of the date of this prospectus take such option exercises into account.
Summary
of Risks Affecting Our Business
Investing
in our ordinary shares is highly speculative and involves a significant degree of risk. You should carefully consider the risks
and uncertainties discussed under the section titled “Risk Factors” elsewhere in this prospectus before making a decision
to invest in our ordinary shares. Certain of the key risks we face include, without limitation:
|
● |
our
operations are solely in Indonesia, and our
lack of asset and geographic diversification increases the risk of an investment in us, and our financial condition and results of
operations may deteriorate if we fail to diversify; |
|
|
|
|
● |
oil
and gas price volatility has and may
continue to adversely affect our results of operations and financial condition; |
|
|
|
|
● |
lower
oil and/or gas prices may also reduce the amount of oil and/or gas that we can produce economically; |
|
|
|
|
● |
there
is inherent credit risk in any gas sales arrangements with the Government to which we may become a party in the future; |
|
|
|
|
● |
the
global pandemic of COVID-19 and volatility in the energy markets may materially and adversely affect our business, financial condition,
operating results, cash flow, liquidity and prospects; |
|
|
|
|
● |
our
business requires significant capital investment and maintenance expenses, which we may be unable to finance on satisfactory terms
or at all; |
|
|
|
|
● |
our
estimated oil reserves are based on assumptions that may prove inaccurate, and thus our estimates of proved reserves and future net
revenue are inherently imprecise. |
|
|
|
|
● |
we
may not find any commercially productive oil and gas reservoirs in connection with our exploration activities. |
|
|
|
|
● |
we
may not adhere to our proposed drilling schedule, and our drilling operations may be curtailed, delayed or cancelled as a result
of a variety of factors that are beyond our control; |
|
|
|
|
● |
we
are subject to complex laws, rules and regulations common to the oil and natural gas industry, including those specific to operating
in Indonesia, which can have a material adverse effect on our business, financial condition and results of operations; |
|
|
|
|
● |
our
Production Sharing Contract for Citarum Block requires or may require us to relinquish portions of the subject contract area in certain
circumstances, which would potentially leave us with less area to explore; |
|
|
|
|
● |
climate
change and climate change legislation and regulatory initiatives could result in increased operating costs and decreased demand for
the oil and natural gas that we produce; |
|
|
|
|
● |
we
are faced with the high risks inherent in the drilling of oil and natural gas wells, including the risk that we may encounter no
commercially productive natural gas or oil reservoirs even if we expend significant costs on such exploration; |
|
|
|
|
● |
we
are a holding company, and will rely on dividends paid by our subsidiaries for our cash needs. Any limitation on the ability of our
subsidiaries to make dividend payments to us, or any tax implications of making dividend payments to us, could limit our ability
to pay our parent company expenses or pay dividends to holders of our ordinary shares; |
|
● |
you
may face difficulties in protecting your interests, and your ability to protect your rights through the U.S. Federal courts may be
limited, as a result of our company being incorporated under the laws of the Cayman Islands; |
|
|
|
|
● |
We
have identified a material weakness in our internal control over financial reporting for the year ended December 31, 2020. |
|
|
|
|
● |
our January 2022 convertible note and warrant financing
with L1 Capital could cause substantial dilution and pressure on the public price of our ordinary shares as repayments under such
note can be paid in ordinary shares priced at a discount to market; |
|
|
|
|
● |
The rights afforded to L1 Capital under our convertible
note and warrant financing with them could discourage investment in our company from third parties; |
|
|
|
|
● |
the market for our ordinary shares has been volatile, and
an active, liquid and orderly trading market for our ordinary shares may not be maintained in the United States, which could limit
your ability to sell our ordinary shares; and |
|
|
|
|
● |
as
a foreign private issuer, we are subject to different U.S. securities laws and NYSE American governance standards than domestic U.S.
issuers. This may afford less protection to holders of our ordinary shares, and you may not receive corporate and company information
and disclosure that you are accustomed to receiving or in a manner in which you are accustomed to receiving it. |
Foreign
Private Issuer Status
We
are a foreign private issuer within the meaning of the rules under the Securities Exchange Act of 1934, as amended (which we refer to
as the Exchange Act). As such, we are exempt from certain provisions applicable to United States domestic public companies. For example:
|
● |
we
are not required to provide as many Exchange Act reports, or as frequently, as a domestic public company; |
|
|
|
|
● |
for
interim reporting, we are permitted to comply solely with our home country requirements, which are less rigorous than the rules that
apply to domestic public companies; |
|
|
|
|
● |
we
are not required to provide the same level of disclosure on certain issues, such as executive compensation; |
|
|
|
|
● |
we
are exempt from provisions of Regulation FD aimed at preventing issuers from making selective disclosures of material information; |
|
|
|
|
● |
we
are not required to comply with the sections of the Exchange Act regulating the solicitation of proxies, consents or authorizations
in respect of a security registered under the Exchange Act; |
|
|
|
|
● |
we
are not required to comply with Section 16 of the Exchange Act requiring insiders to file public reports of their share ownership
and trading activities and establishing insider liability for profits realized from any “short-swing” trading transaction;
and |
|
|
|
|
● |
we
have adopted “home country” practice and thereby opted out of the NYSE American rule that would otherwise require shareholder
approval should we issue more than 19.99% of our then outstanding ordinary shares in a financing that is not a “public offering”
at less than the then current market value. |
Emerging
Growth Company Status
We
are an “emerging growth company,” as defined in the Jumpstart Our Business Startups Act (which we refer to as the JOBS Act),
and we are eligible to take advantage of certain exemptions from various reporting and financial disclosure requirements that are applicable
to other public companies, that are not emerging growth companies, including, but not limited to, (1) presenting
only two years of audited financial statements and only two years of related management’s discussion and analysis of financial
condition and results of operations in this prospectus, (2) not being required to comply with the auditor attestation requirements
of Section 404 of the Sarbanes-Oxley Act of 2002 (the “Sarbanes-Oxley Act”), (3) reduced disclosure obligations regarding
executive compensation in our periodic reports and proxy statements, and (4) exemptions from the requirements of holding a non-binding
advisory vote on executive compensation and shareholder approval of any golden parachute payments not previously approved. We intend
to take advantage of these exemptions. As a result, investors may find investing in our ordinary shares less attractive.
In
addition, Section 107 of the JOBS Act also provides that an emerging growth company can take advantage of the extended transition period
provided in Section 7(a)(2)(B) of the Securities Act of 1933, as amended (which we refer to as the Securities Act), for complying with
new or revised accounting standards. As a result, an emerging growth company can delay the adoption of certain accounting standards until
those standards would otherwise apply to private companies, and we intend to take advantage of this extended transaction period.
We
could remain an emerging growth company for up to five years, or until the earliest of (1) the last day of the first fiscal year in which
our annual gross revenues exceed $1.07 billion, (2) the date that we become a “large accelerated filer” as defined in Rule
12b-2 under the Exchange Act, which would occur if the market value of our ordinary shares that is held by non-affiliates exceeds $700
million as of the last business day of our most recently completed second fiscal quarter and we have been publicly reporting for at least
12 months, or (3) the date on which we have issued more than $1 billion in non-convertible debt during the preceding three-year period.
History
and Corporate Structure
We
were incorporated on April 24, 2018 as an exempted company with limited liability under the laws of the Cayman Islands and are a holding
company for WJ Energy Group Limited (or WJ Energy), which in turn owns our Indonesian holding and operating subsidiaries. We presently
have two shareholders, Maderic Holding Limited (or Maderic) and HFO Investment Group (or HFO), which own 68.29% and 8.47%,
respectively, of our issued shares. Certain of our officers and directors own interests in Maderic and HFO (see “Principal
Shareholders”).
WJ
Energy was incorporated in Hong Kong on June 3, 2014. The initial shareholders of WJ Energy were Maderic and HFO, with each owning 50%
of WJ Energy’s shares. On October 20, 2014, HFO received HKD 4,000 from Maderic as consideration for 4,000 shares in WJ Energy,
which resulted in Maderic owning 90% of WJ Energy and HFO owning 10%.
On
February 27, 2015, WJ Energy formed GWN as a vehicle to acquire and thereafter operate the Kruh Block. On March 20, 2017, PT Harvel Nusantara
Energi, an Indonesian limited liability company (or HNE), was formed by WJ Energy as a required vehicle for oil and gas block acquisitions
in compliance with Indonesian law. On June 26, 2017, Maderic sold 500 shares of WJ Energy to HFO in consideration of HKD 500. Concurrently,
Maderic sold 1,500 shares of WJ Energy to Opera Cove International Limited, an unaffiliated third party (or Opera), in consideration
of HKD 1,500. At the end of such transactions, the outstanding shares of WJ Energy were owned 70% by Maderic, 15% by HFO and 15% by Opera.
On June 25, 2017, Maderic and Opera executed an entrustment agreement giving Maderic legal and beneficial ownership of the shares held
by Opera. On December 7, 2017, PT Cogen Nusantara Energi, an Indonesian limited liability company, was formed under HNE as a required
vehicle for the prospective acquisition of a new oil and gas block through a Joint Study program in consortium with GWN. On May 14, 2018,
PT Hutama Wiranusa Energi, was formed under GWN as a requirement to sign the contract for the acquisition of Citarum Block as part of
the consortium that conducted the Joint Study for the Citarum Block.
On
June 30, 2018, we entered into two agreements with Maderic and HFO (the two then shareholders of WJ Energy): a Sale and Purchase of Shares
and Receivables Agreement and a Debt Conversion Agreement (which we refer to collectively as the Restructuring Agreements). The intention
of the Restructuring Agreements was to restructure our capitalization in anticipation of our initial public offering which was concluded
in December 2019. As a result of the transactions contemplated by the Restructuring Agreements: (i) WJ Energy (including its assets and
liabilities) became a wholly-owned subsidiary of our company, (ii) loans amounting to $21,150,000 and $3,150,000 that were owed by WJ
Energy to Maderic and HFO, respectively, were converted for nominal value into ordinary shares of our company and (iii) we issued an
aggregate of 15,999,000 ordinary shares to Maderic and HFO. The above mentioned transaction is accounted for as a nominal share issuance
(which we refer to as the Nominal Share Issuance). All number of shares and per share data presented in this prospectus have been retroactively
restated to reflect the Nominal Share Issuance.
This
series of transactions resulted in the then ownership of our company being set at 87.04% owned by Maderic (13,925,926 ordinary shares),
and 12.96% owned by HFO (2,074,074 ordinary shares), out of a total of 16,000,000 issued ordinary shares.
On
November 8, 2019, we implemented a one-for-zero point three seven five (1 for 0.375) reverse stock split of our ordinary shares by way
of share consolidation under Cayman Islands law (which we refer to herein as the Reverse Stock Split). As a result of the Reverse Stock
Split, the total of 16,000,000 issued and outstanding ordinary shares prior to the Reverse Stock Split was reduced to a total of 6,000,000
issued and outstanding ordinary shares. The purpose of the Reverse Stock Split was for us to be able to achieve a share price for our
ordinary shares consistent with the listing requirements of the NYSE American. Any fractional ordinary share that would have otherwise
resulted from the Reverse Stock Split was rounded up to the nearest full share. The Reverse Stock Split maintained our founding shareholders’
then percentage ownership interests in our company at 87.04% owned by Maderic (5,222,222 ordinary shares) and 12.96% owned by HFO (777,778
ordinary shares), out of a total of 6,000,000 issued ordinary shares. The Reverse Stock Split also increased the par value of our ordinary
shares from $0.001 to $0.00267 and decreased the number of authorized ordinary shares of our company from 100,000,000 to 37,500,000 and
authorized preferred shares from 10,000,000 to 3,750,000.
As
of the date of this prospectus, Maderic owns 68.29% of our issued and outstanding shares, while HFO owns approximately 8.47%
of our issued and outstanding shares. As of the date of this prospectus, we have 7,647,214 ordinary shares issued and
outstanding. The following diagram illustrates our corporate structure, including our consolidated
holding and operating subsidiaries, as of the date of this prospectus:
Not
reflected in the above is that, for purposes of compliance with Indonesian law related to ownership of Indonesian companies: (i) WJ Energy
owns 99.90% of the outstanding shares of GWN and HNE, and (ii) GWN and HNE each own 0.1% of the outstanding shares of the other; and
(iii) GWN owns 99.50% of the outstanding shares of HWE, and the remaining 0.50% is owned by HNE; and (iv) HNE owns 99.90% of the outstanding
shares of CNE, and the remaining 0.10% is owned by GWN.
Corporate
Information
Our
principal executive offices are located at GIESMART PLAZA 7th Floor, Jl. Raya Pasar Minggu No. 17A, Pancoran – Jakarta
12780 Indonesia. Our telephone number at this address is +62 21 2696 2888. Our registered office in the Cayman Islands is located at
Ogier Global (Cayman) Limited, 89 Nexus Way, Camana Bay, Grand Cayman, Cayman Islands. Our web site is located at www.indo-energy.com.
The information contained on our website is not incorporated by reference into this prospectus, and the reference to our website in this
prospectus is an inactive textual reference only.
THE
OFFERING
Ordinary
shares offered by Selling Shareholder: |
|
Up
to 9,100,574 ordinary shares of our company, which includes (i) up to 8,333,334 ordinary shares potentially issuable
upon the conversion of (or monthly installment payments under) an outstanding convertible promissory note held by the Selling Shareholder
(the “Note”), and (ii) up to 767,240 ordinary shares potentially issuable upon the exercise of outstanding warrants
to purchase ordinary shares issued to the Selling Shareholder (the “Warrants”). |
|
|
|
Number
of ordinary shares outstanding before this offering: |
|
7,647,214
ordinary shares outstanding immediately prior
to this offering. |
|
|
|
Number
of ordinary shares outstanding after this offering: |
|
Up to 16,747,788 ordinary shares may
be outstanding after this offering is completed(1). |
|
|
|
Use
of proceeds: |
|
We
will not receive any proceeds from the sale by the Selling Stockholder of the ordinary shares being offered by this prospectus. However,
we may receive proceeds from the cash exercise of the Warrants, which, if exercised in cash at the current exercise price with respect
to all Warrants, would result in gross proceeds to us of approximately $4,603,440, assuming the current exercise price of
the Warrants of $6.00 per share. The proceeds from such Warrant exercises, if any, will be used for working capital and general corporate
purposes. No assurances can be given that all or any portion of the Warrants will be exercised. |
Trading
symbol: |
|
Our
ordinary shares are currently traded on the NYSE American under the symbol “INDO”. |
|
|
|
Risk
factors: |
|
Investing
in our ordinary shares is highly speculative and involves a significant degree of risk. As an investor you should be able to bear
a complete loss of your investment. You should carefully consider the information set forth in the “Risk Factors” section
beginning on page 12. |
Unless
we indicate otherwise, all information in this prospectus is based on 7,647,214 ordinary shares issued and outstanding as of the
date of this prospectus.
(1)
Assumes: (i) conversion of all principal under the Note into 8,333,334 ordinary shares
at an assumed conversion price of $1.20 per share, which is the floor price for conversion of the Note and (ii) full exercise of all
of the Warrants. The number of ordinary shares issuable upon conversion or repayment of the Note may be substantially less than
the number of ordinary shares registered hereunder as the Note may be converted or repaid based on prevailing market prices for our ordinary
shares during the term of the Note.
SUMMARY
SELECTED FINANCIAL DATA
The
following table summarizes certain of our financial data. We have derived the following statements of operations data and balance sheets
data for the years ended December 31, 2019 and 2020 from our audited financial statements and six months period ended June 30, 2020 and
2021 from our unaudited condensed consolidated financial statements included elsewhere in this prospectus. Our historical results are
not necessarily indicative of the results that may be expected in the future. The following summary financial data should be read in
conjunction with “Management’s Discussion and Analysis of Financial Condition and Results of Operations” and our audited
financial statements and related notes included elsewhere in this prospectus. Numbers in the following tables are in U.S. dollars and,
except share and per share amounts, in thousands.
STATEMENTS
OF OPERATIONS DATA:
| |
For the Twelve Months Ended December 31, | | |
For the six months ended June 30, 2021 | |
| |
2020 | | |
2019 | | |
(unaudited) | |
| |
| | |
| | |
| |
Revenue | |
$ | 1,981 | | |
$ | 4,183 | | |
$ | 1,057 | |
Lease operating expenses | |
| 2,018 | | |
| 2,474 | | |
| 1,145 | |
Depreciation, depletion and amortization | |
| 699 | | |
| 877 | | |
| 283 | |
General and administrative expenses | |
| 6,534 | | |
| 2,434 | | |
| 2,563 | |
Exchange gain (loss) | |
| 132 | | |
| (52 | ) | |
| (33 | ) |
Other income (expense) | |
| 186 | | |
| (20 | ) | |
| 34 | |
Loss before Income tax | |
| (6,952 | ) | |
| (1,674 | ) | |
| (2,932 | ) |
Income tax provision | |
| - | | |
| - | | |
| - | |
Net loss | |
$ | (6,952 | ) | |
$ | (1,674 | ) | |
$ | (2,932 | ) |
| |
| | | |
| | | |
| | |
Loss per ordinary share attributable to the Company | |
| | | |
| | | |
| | |
Basic and diluted | |
$ | (0.94 | ) | |
$ | (0.28 | ) | |
$ | (0.39 | ) |
Weighted average ordinary share outstanding | |
| | | |
| | | |
| | |
Basic and diluted | |
| 7,395,120 | | |
| 6,048,568 | | |
| 7,433,673 | |
BALANCE
SHEET DATA:
| |
As of December 31, | | |
As of June 30, 2021 | |
| |
2020 | | |
2019 | | |
(unaudited) | |
| |
| | |
| | |
| |
Current assets | |
$ | 11,241 | | |
$ | 15,074 | | |
$ | 8,933 | |
Total assets | |
| 15,576 | | |
| 21,155 | | |
| 14.186 | |
Current liabilities | |
| 1,828 | | |
| 2,739 | | |
| 2,444 | |
Total liabilities | |
| 3,218 | | |
| 4,961 | | |
| 3,834 | |
Ordinary shares | |
| 20 | | |
| 20 | | |
| 20 | |
Total equity | |
$ | 12,358 | | |
$ | 16,194 | | |
$ | 10,352 | |
NON-GAAP
FINANCIAL MEASURES:
Adjusted
EBITDA and Adjusted EBITDA less Capital Expenditures
Adjusted
EBITDA is not a measure of net income (loss) and Adjusted EBITDA less capital expenditures is not a measure of cash flow, in both cases,
as determined by GAAP. Adjusted EBITDA and Adjusted EBITDA less capital expenditures are supplemental non-GAAP financial measures used
by management and external users of our financial statements, such as industry analysts, investors, lenders and rating agencies. We define
Adjusted EBITDA as earnings before interest expense, income taxes, depreciation, depletion, amortization and accretion, write down of
other assets, share based compensation to employees and non-employees, and other unusual out of period and infrequent items. We define
Adjusted EBITDA from cash flow less capital expenditures as Adjusted EBITDA less capital expenditures.
Our
management believes Adjusted EBITDA provides useful information in assessing our financial condition, results of operations and cash
flows and is widely used by the industry and the investment community. The measure also allows our management to more effectively evaluate
our operating performance and compare the results between periods without regard to our financing methods or capital structure. Adjusted
EBITDA less capital expenditures is used by management as a measure of cash generated by the business, after accounting for capital expenditures,
available for investment, dividends, debt reduction or other purposes. While Adjusted EBITDA and Adjusted EBITDA less capital expenditures
are non-GAAP measures, the amounts included in the calculation of Adjusted EBITDA and Adjusted EBITDA less capital expenditures were
computed in accordance with GAAP. These measures are provided in addition to, and not as an alternative for, income and liquidity measures
calculated in accordance with GAAP. Certain items excluded from Adjusted EBITDA are significant components in understanding and assessing
our financial performance, such as our cost of capital and tax structure, as well as the historic cost of depreciable and depletable
assets. Our computations of Adjusted EBITDA and Adjusted EBITDA less capital expenditures may not be comparable to other similarly titled
measures used by other companies. Adjusted EBITDA and Adjusted EBITDA less capital expenditures should be read in conjunction with the
information contained in our financial statements prepared in accordance with GAAP.
The
following table presents a reconciliation of Adjusted EBITDA to the GAAP financial measure of net income (loss) and a reconciliation
of the GAAP financial measure of net cash provided by (used in) operating activities to the non-GAAP financial measures of Adjusted EBITDA
and Adjusted EBITDA less capital expenditures for each of the periods indicated.
| |
For the Twelve Months Ended December 31, | | |
For the Six Months Ended June 30, 2021 | |
| |
2020 | | |
2019 | | |
(unaudited) | |
| |
| | |
| | |
| |
Net loss reconciliation to Adjusted EBITDA | |
| | | |
| | | |
| | |
Net loss | |
$ | (6,951,698 | ) | |
$ | (1,673,735 | ) | |
$ | (2,932,213 | ) |
Add (Subtract): | |
| | | |
| | | |
| | |
Depreciation, depletion, amortization and accretion | |
| 698,851 | | |
| 876,676 | | |
| 282,948 | |
Interest expense | |
| 35,271 | | |
| 41,999 | | |
| 9,437 | |
Income tax expense (benefit) | |
| - | | |
| - | | |
| - | |
Realized actuarial gain | |
| (46,805 | ) | |
| - | | |
| - | |
Income from accounts payable written-off | |
| (146,662 | ) | |
| - | | |
| - | |
Write down of other assets | |
| - | | |
| - | | |
| - | |
Accrual of uncertain withholding taxes | |
| - | | |
| - | | |
| - | |
Amortization of deferred charges | |
| 72,756 | | |
| 57,418 | | |
| 40,094 | |
Amortization of Share-based compensation | |
| 3,007,081 | | |
| 247,817 | | |
| 651,852 | |
Adjusted EBITDA | |
$ | (3,331,206 | ) | |
$ | (449,825 | ) | |
$ | (1,947,882 | ) |
| |
For the Twelve Months Ended December 31, | | |
For the Six Months Ended June 30, 2021 | |
| |
2020 | | |
2019 | | |
(unaudited) | |
| |
| | |
| | |
| |
Adjusted EBITDA | |
$ | (3,331,206 | ) | |
$ | (449,825 | ) | |
$ | (1,947,882 | ) |
Subtract: | |
| | | |
| | | |
| | |
Capital Expenditures | |
| (357,333 | ) | |
| (1,045,579 | ) | |
| (892,183 | ) |
Adjusted EBITDA less Capital Expenditures | |
$ | (3,688,539 | ) | |
$ | (1,495,404 | ) | |
$ | (2,840,065 | ) |
RISK
FACTORS
An
investment in our ordinary shares is highly speculative and involves a significant degree of risk. You should carefully consider
all of the information in this prospectus, including the risks and uncertainties described below, before making an investment in our
ordinary shares. Any of the following risks could have a material adverse effect on our business, financial condition and results of
operations. In any such case, the market price of our ordinary shares could decline, and you may lose all or part of your investment.
Risks
Related to Our Business
Our
lack of asset and geographic diversification increases the risk of an investment in us, and our financial condition and results of operations
may deteriorate if we fail to diversify.
Our
business focus is on oil and gas exploration in limited areas in Indonesia and exploitation of any significant reserves that are found
within our license areas. As a result, we lack diversification, in terms of both the nature and geographic scope of our business. We
will likely be impacted more acutely by factors affecting our industry or the regions in which we operate than we would if our business
were more diversified. If we are unable to diversify our operations, our financial condition and results of operations could deteriorate.
Oil
and gas price volatility has and may continue to adversely affect our results of operations and financial condition.
Our
revenues, cash flow, profitability and future rate of growth are substantially dependent upon prevailing prices for oil and gas, over
which we have no control. If oil prices are higher, we can generate more cash from our drilling operations, and if oil prices are lower,
our ability to generate cash is reduced. In addition, our ability to borrow funds and to obtain additional capital on attractive terms
is also substantially dependent on oil and gas prices. Historically and recently, world-wide oil and gas prices and markets have been
very volatile and are likely to continue to be volatile in the future.
Prices
for oil and gas are subject to wide fluctuations in response to relatively minor changes in the supply of and demand for oil and gas,
market uncertainty and a variety of additional factors that are beyond our control. These factors include international political conditions
(including wars, conflicts, trade and other disputes, cyberattacks and similar occurrences), the domestic and foreign supply of oil and
gas, the level of consumer demand and factors effecting such demand, weather conditions, domestic and foreign governmental regulations,
the price and availability of alternative fuels and overall economic conditions. In addition, various factors, including the effect of
domestic and foreign regulation of production and transportation, general economic conditions, changes in supply due to drilling by other
producers and changes in demand may adversely affect our ability to market our oil and gas production. Any significant decline in the
price of oil or gas would adversely affect our revenues, operating income, cash flows and borrowing capacity and may require a reduction
in the carrying value of our oil and gas properties and our planned level of capital expenditures. This risk was demonstrated in 2020
and 2021 with very significant swings in the price of oil as a result of the global COVID-19 pandemic and in 2022 with Russia’s
invasion of Ukraine. We may continue to be subject to oil and gas price-related risks while the pandemic persists and for so long as
the global economy remains uncertain.
There
is inherent credit risk in any gas sales arrangements with the Government to which we may become a party in the future.
Natural
gas supply contracts in Indonesia are negotiated on a field-by-field basis among SKK Migas, gas buyers and sellers. The common clause
in gas supply contracts is a “take-or-pay arrangement” in which the buyer is required to either pay the price corresponding
to certain pre-agreed quantities of natural gas and offtake such quantities or pay their corresponding price regardless of whether it
purchases them. Under certain circumstances, such as industrial or economic crisis in Indonesia or globally, the buyer may be unwilling
or unable to make these payments, which could trigger a renegotiation of contracts and become the subject of legal disputes between parties.
When and if we establish natural gas production and enter into related contracts with the Government, this contract term could have a
material adverse effect on our business, financial condition and result of operation by reducing our net profit or increasing our total
liabilities in the future, or both.
We
face credit risk from the Government and the ability of Pertamina to pay our company for the operating costs and profit sharing split
in a timely manner.
Our
current cash inflow is dependent on a “cost recovery” and profit-sharing arrangement with Pertamina, meaning that all operating
costs (expenditures made and obligations incurred in the exploration, development, extraction, production, transportation, marketing,
abandonment and site restoration) are advanced by our company and later repaid by Pertamina plus a share of the profit from operations.
Any delay of payment by Pertamina may adversely affect our operations and delay the schedule of capital investments which could have
otherwise have an adverse effect on our business, prospects, financial condition and results of operations.
Drilling
oil and natural gas wells is a high-risk activity.
Our
growth is materially dependent upon the success of our drilling program. Drilling for natural gas and oil involves numerous risks, including
the risk that no commercially productive natural gas or oil reservoirs will be encountered. The cost of drilling, completing and operating
wells is substantial and uncertain, and drilling operations may be curtailed, delayed or cancelled as a result of a variety of factors
beyond our control, including:
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unexpected
drilling conditions, pressure or irregularities in formations; |
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equipment
failures or accidents; |
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adverse
weather conditions; |
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decreases
in natural gas and oil prices; |
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surface
access restrictions; |
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loss
of title or other title related issues; |
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compliance
with, or changes in, governmental requirements and regulation; and |
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costs
of shortages or delays in the availability of drilling rigs or crews and the delivery of equipment and materials. |
We
experienced difficulties in drilling in 2021 at our Kruh-25 well when the well collapsed during the rainy season. Our future drilling
activities may not be successful and, if unsuccessful, such failure will have an adverse effect on our future results of operations and
financial condition. Our overall drilling success rate or our drilling success rate for activity within a particular geographic area
may decline. We may be unable to lease or drill identified or budgeted prospects within our expected time frame, or at all. We may be
unable to lease or drill a particular prospect because, in some cases, we identify a prospect or drilling location before seeking an
option or lease rights in the prospect or location. Similarly, our drilling schedule may vary from our capital budget. The final determination
with respect to the drilling of any scheduled or budgeted wells will be dependent on a number of factors, including:
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the
results of exploration efforts and the acquisition, review and analysis of the seismic data; |
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the
availability of sufficient capital resources to us and the other participants for the drilling of the prospects; |
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the
approval of the prospects by other participants after additional data has been compiled; |
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economic
and industry conditions at the time of drilling, including prevailing and anticipated prices for natural gas and oil and the availability
of drilling rigs and crews; |
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our
financial resources and results; and |
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the
availability of leases and permits on reasonable terms for the prospects and any delays in obtaining such permits. |
These
projects may not be successfully developed and the wells, if drilled, may not encounter reservoirs of commercially productive natural
gas or oil.
Lower
oil and/or gas prices may also reduce the amount of oil and/or gas that we can produce economically.
Sustained
substantial declines in oil and/or gas prices may render a significant portion of our exploration, development and exploitation projects
unviable from an economic perspective, which may result in us having to make significant downward adjustments to our estimated proved
reserves. As a result, a prolonged or substantial decline in oil and/or gas prices, such as we have experienced since mid-2014 and which
was exacerbated during the COVID-19 pandemic during 2020 and 2021 caused, and would likely in the future cause, a material and adverse
effect on our future business, financial condition, results of operations, liquidity and ability to finance capital expenditures. Additionally,
if we experience significant sustained decreases in oil and gas prices such that the expected future cash flows from our oil and gas
properties falls below the net book value of our properties, we may be required to write down the value of our oil and gas properties.
Any such asset impairments could materially and adversely affect our results of operations and, in turn, the trading price of our ordinary
shares.
The
outbreak of COVID-19 and volatility in the energy markets may materially and adversely affect our business, financial condition, operating
results, cash flow, liquidity and prospects.
The
outbreak of COVID-19 and its development into a pandemic in March 2020 have resulted in significant disruption globally. Actions taken
by various governmental authorities, individuals and companies around the world to prevent the spread of COVID-19 have restricted travel,
business operations, and the overall level of individual movement and in-person interaction across the globe, including the United States
and Indonesia. Furthermore, the impact of the pandemic, including a resulting reduction in demand for oil and natural gas, coupled with
the sharp decline in commodity prices following the announcement of price reductions and production increases in March 2020 by members
of the Organization of the Petroleum Exporting Countries (“OPEC”) has led to significant global economic contraction generally
and in the oil and gas exploration industry in particular. While an agreement to cut production has since been announced by OPEC and
its allies, the situation, coupled with the impact of COVID-19, has continued to result in a significant downturn in the oil and gas
industry.
The
COVID-19 pandemic has caused us to modify our business practices, including by restricting employee travel, requiring employees to work
remotely and cancelling physical participation in meetings, events and conferences, and we may take further actions as may be required
by government authorities or that we determine are in the best interests of our employees, customers and business partners. There is
no certainty that such measures will be sufficient to mitigate the risks posed by COVID-19 or otherwise be satisfactory to government
authorities. If a number of our employees were to contract COVID-19 at the same time, our operations could be adversely affected.
A
sustained disruption in the capital markets from the COVID-19 pandemic, specifically with respect to the energy industry, could negatively
impact our ability to raise capital. In the past, we have financed our operations by the issuance of equity securities. However, we cannot
predict when the macro-economic disruption stemming from COVID-19 will ebb or when the economy will return to pre-COVID-19 levels, if
at all. This macro-economic disruption may disrupt our ability to raise additional capital to finance our operations in the future, which
could materially and adversely affect our business, financial condition and prospects, and could ultimately cause our business to fail.
The
extent to which COVID-19 ultimately impacts our business, results of operations and financial condition will depend on future developments,
which are uncertain and cannot be predicted, including, but not limited to, the duration and spread of COVID-19 or variants of COVID-19,
its severity, the actions to contain COVID-19 or treat its impact (such as vaccinations), and how quickly and to what extent normal economic
and operating conditions can resume. Even after COVID-19 has subsided, we may continue to experience materially adverse impacts to our
business as a result of its global economic impact, including any recession that has occurred or may occur in the future, and lasting
effects on the volatility in the price of oil and natural gas.
We
may not be able to fund the capital expenditures that will be required for us to increase reserves and production.
We
must make capital expenditures to develop our existing reserves and to discover new reserves. Historically, we have financed our capital
expenditures primarily through related and non-related party financings as well as our initial public offering and recent financing with
L1 Capital. We expect to continue to utilize these or similar resources (as well as funds from potential equity and debt financings and
any future net positive cash flow) in the future.
However,
we cannot assure you that we will have sufficient capital resources in the future to finance all of our planned capital expenditures.
This is particularly the case as we raised less funds than we had anticipated in our December 2019 initial public offering, which has
required us to modify our drilling and other operational plans during 2020 and 2021.
Moreover,
volatility in oil and gas prices, the timing of our drilling programs and drilling results will affect our cash flow from operations.
Lower prices and/or lower production could also decrease revenues and cash flow, thus reducing the amount of financial resources available
to meet our capital requirements, including reducing the amount available to pursue our drilling opportunities. If our cash flow from
operations does not increase as a result of capital expenditures, a greater percentage of our cash flow from operations will be required
for debt service and operating expenses and our capital expenditures would, by necessity, be decreased.
Strategic
determinations, including the allocation of capital and other resources to strategic opportunities, are challenging, and our failure
to appropriately allocate capital and resources among our strategic opportunities may adversely affect our financial condition and reduce
our growth rate.
Our
future growth prospects are dependent upon our ability to identify optimal strategies for our business. In developing our business plan,
we have and will continue to consider allocating capital and other resources to various aspects of our businesses including well-development
(primarily drilling), reserve acquisitions, exploratory activity, corporate items and other alternatives. We also have and will continue
to consider our likely sources of capital. Our ability to fund our current business plan is dependent on our available capital. As we
raised less funds than we had anticipated in our December 2019 initial public offering, we have been faced with challenges relative to
the allocation of those funds, which has required us to modify our business plan and which could create challenges for our ability to
fully fund our plans. In addition, notwithstanding the determinations made in the development of our business plan, business opportunities
not previously identified periodically come to our attention, including possible acquisitions and dispositions. If we fail to identify
optimal business strategies or fail to optimize our capital investment and capital raising opportunities and the use of our other resources
in furtherance of our business strategies, our financial condition and growth rate may be adversely affected. Moreover, economic or other
circumstances may change from those contemplated by our business plan, and our failure to recognize or respond to those changes may limit
our ability to achieve our objectives.
Our
expectations for future drilling activities will be realized over several years, making them susceptible to uncertainties that could
materially alter the occurrence or timing of such activities.
We
have identified drilling locations and prospects for future drilling opportunities, including development and exploratory drilling activities,
at both Kruh Block and Citarum Block. These drilling locations and prospects represent a significant part of our future drilling plans.
Our ability to drill and develop these locations depends on a number of factors, including the availability of capital, regulatory approvals,
negotiation of agreements with third parties, commodity prices, costs, access to and availability of equipment, services, resources and
personnel and drilling results. There can be no assurance that we will drill these locations or that we will be able to produce oil from
these locations or any other potential drilling locations. Changes in the laws or regulations on which we rely in planning and executing
its drilling programs could adversely impact our ability to successfully complete those programs.
Our
estimated oil reserves are based on assumptions that may prove inaccurate.
Oil
engineering is a subjective process of estimating accumulations of oil and gas that cannot be measured in an exact way, and estimates
of other engineers may differ materially from those set out herein. Numerous assumptions and uncertainties are inherent in estimating
quantities of proved oil, including projecting future rates of production, timing and amounts of development expenditures and prices
of oil and gas, many of which are beyond our control. Results of drilling, testing and production after the date of the estimate may
require revisions to be made. Accordingly, reserves estimates are often materially different from the quantities of oil and gas that
are ultimately recovered, and if such recovered quantities are substantially lower that the initial reserves estimates, this could have
a material adverse impact on our business, financial condition and results of operations.
We
may not find any commercially productive oil and gas reservoirs in connection with our exploration activities.
Our
business prospects are currently dependent on extracting assets from our Kruh Block and on finding sufficient reserves in our Citarum
Block. Drilling involves numerous risks, including the risk that the new wells we drill will be unproductive or that we will not recover
all or any portion of our capital investment. Drilling for oil and gas may be unprofitable. Wells that are productive but do not produce
sufficient net revenues after drilling, operating and other costs are unprofitable. By their nature, estimates of undeveloped reserves
are less certain. Recovery of such reserves will require significant capital expenditures and successful drilling and completion operations.
In addition, our properties may be susceptible to drainage from production by other operations on adjacent properties. If the volume
of oil and gas we produce decreases, our cash flow from operations may decrease.
We
may be unable to expand operations by securing rights to additional producing our exploration blocks.
One
of our key business strategies is expand our asset portfolio, which may include producing our exploration blocks. We have currently identified
one such potential block – the Rangkas Area – and our goal will be to secure rights to conduct activities in Rangkas and
other areas in Indonesia, However, due to the competitive tender process and uncertainties around Government contracting, among other
factors, we may be unable to secure rights to conduct exploration or production activities in any additional areas. In particular, we
face competition from other oil and gas companies in the acquisition of new oil blocks through the Indonesian government’s tender
process. Our competitors for these tenders include Pertamina, the Indonesian state-owned national oil company (who can tender for blocks
on its own), and other well-established large international oil and gas companies. Such companies have substantially greater capital
resources and are able to offer more attractive terms when bidding for concessions. If we are unable to secure rights to additional blocks,
we would be left without additional opportunities for revenue and profit and remain subject to the risks associated with our current
lack of asset diversification, all of which would harm our results of operations.
We
may not be able to keep pace with technological developments in our industry.
The
oil and gas industry is characterized by rapid and significant technological advancements and introductions of new products and services
using new technologies. As others use or develop new technologies, we may be placed at a competitive disadvantage, and competitive pressures
may force us to implement those new technologies at substantial cost. In addition, other oil and gas companies may have greater financial,
technical and personnel resources that allow them to enjoy technological advantages and may in the future allow them to implement new
technologies before we can. We may not be able to respond to these competitive pressures and implement new technologies on a timely basis
or at an acceptable cost. If one or more of the technologies we use now or in the future were to become obsolete or if we are unable
to use the most advanced commercially available technology, our business, financial condition and results of operations could be materially
adversely affected.
We
have previously had to modify and in the future we may not adhere to our proposed drilling schedule.
While
we have internally approved plans for development of Kruh Block and have publicly stated our intentions with respect to new drilling
activity for Kruh Block, our final determination of whether and when to drill any scheduled or budgeted wells (whether in Kruh Block
or otherwise) will be dependent on a number of factors, including:
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prevailing
and anticipated prices for oil and gas; |
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the
availability and costs of drilling and service equipment and crews; |
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economic
and industry conditions at the time of drilling; |
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the
availability of sufficient capital resources; |
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the
results of our exploration efforts; |
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the
acquisition, review and interpretation of seismic data; |
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our
ability to obtain permits for and to access drilling locations; and |
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continuous
drilling obligations. |
Although
we have identified or budgeted for numerous drilling locations, we may not be able to drill those locations within our expected time
frame or at all. In addition, our drilling schedule may vary from our expectations because of future uncertainties.
Moreover,
conditions (such as weather, Government permitting, our capital resources, and similar matters) have in the past required us, and may
in the future require us, to modify or delay our drilling programs. Some of the factors that impact the timing of our drilling plans
are beyond our control. Any delay in implementing our drilling programs could damage our reputation and share price, and could also have
a material adverse effect on our results of operations (including our cash flows).
Seasonal
weather conditions and other factors could adversely affect our ability to conduct drilling activities.
Our
operations could be adversely affected by weather conditions. Severe weather conditions limit and may temporarily halt our ability to
operate during such conditions. We experienced weather related challenges with the collapse of our Kruh-25 well in 2021, which set back
our production in 2021. These constraints and the resulting shortages or high costs could delay or temporarily halt our oil and gas operations
and materially increase our operating and capital costs, which could have a material adverse effect on our business, financial condition
and results of operations.
The
lack of availability or high cost of drilling rigs, equipment, supplies, personnel and oil field services could adversely affect our
ability to execute our exploitation and development plans on a timely basis and within our budget.
Our
industry is cyclical and, from time to time, there has been a shortage of drilling rigs, equipment, supplies, oil field services or qualified
personnel. During these periods, the costs and delivery times of rigs, equipment and supplies are substantially greater. In addition,
the demand for, and wage rates of, qualified drilling rig crews rise as the number of active rigs in service increases. During times
and in areas of increased activity, the demand for oilfield services will also likely rise, and the costs of these services will likely
increase, while the quality of these services may suffer. If the lack of availability or high cost of drilling rigs, equipment, supplies,
oil field services or qualified personnel were particularly severe in any of our areas of operation, we could be materially and adversely
affected. Delays could also have an adverse effect on our results of operations, including the timing of the initiation of production
from new wells.
Our
drilling operations may be curtailed, delayed or cancelled as a result of a variety of factors that are beyond our control.
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Our
drilling operations are subject to a number of risks, including: |
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unexpected
drilling conditions; |
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facility
or equipment failure or accidents; |
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adverse
weather conditions; |
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unusual
or unexpected geological formations; |
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fires,
blowouts and explosions; and |
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uncontrollable
pressures or flows of oil or gas or well fluids; and |
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public
health risks and pandemic outbreaks, such as the recent novel coronavirus pandemic |
With
respect to the novel coronavirus pandemic in particular, the full effects of this outbreak around the world are presently unknown and
unpredictable and could have a material adverse effect on (i) the demand for our oil and gas in Indonesia, (ii) our ability to staff
our drilling operations and (iii) our supply chain.
Any
of these events could adversely affect our ability to conduct operations or cause substantial losses, including personal injury or loss
of life, damage to or destruction of property, natural resources and equipment, pollution or other environmental contamination, loss
of wells, regulatory penalties, suspension of operations, and attorney’s fees and other expenses incurred in the prosecution or
defense of litigation.
We
do not insure against all potential operating risks. We might incur substantial losses from, and be subject to substantial liability
claims for, uninsured or underinsured risks related to our oil and gas operations.
We
do not insure against all risks. Our oil and gas exploitation and production activities are subject to hazards and risks associated with
drilling for, producing and transporting oil and gas, and any of these risks can cause substantial losses resulting from:
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environmental
hazards, such as uncontrollable flows of oil, gas, brine, well fluids, toxic gas or other pollution into the environment, including
groundwater, shoreline contamination, underground migration and surface spills or mishandling of chemical additives; |
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abnormally
pressured formations; |
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mechanical
difficulties, such as stuck oil field drilling and service tools and casing collapse; |
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leaks
of gas, oil, condensate, and other hydrocarbons or losses of these hydrocarbons as a result of accidents during drilling and completion
operations, or in the gathering and transportation of hydrocarbons, malfunctions of pipelines, measurement equipment or processing
or other facilities in our operations or at delivery points to third parties; |
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fires
and explosions; |
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personal
injuries and death; |
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regulatory
investigations and penalties; and |
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natural
disasters and pandemics. |
We
have general insurance covering typical industry risks with an insured limit per event of US$35,000,000 with an insured limit per block
of US$100,000,000. However, we do not know the extent of the losses caused by any occurrence and there is a risk that our insurance may
be inadequate to cover all applicable losses, to the extent losses are covered at all. Losses and liabilities arising from uninsured
and underinsured events or in amounts in excess of existing insurance coverage could have a material adverse effect on our business,
financial condition or results of operations.
Our
use of seismic data is subject to interpretation and may not accurately identify the presence of oil and natural gas.
Even
when properly used and interpreted, seismic data and visualization techniques are tools only used to assist geoscientists in identifying
subsurface structures as well as eventual hydrocarbon indicators, and do not enable the interpreter to know whether hydrocarbons are,
in fact, present in those structures. In addition, the use of seismic and other advanced technologies requires greater pre-drilling expenditures
than traditional drilling strategies, and we could incur losses as a result of these expenditures. Because of these uncertainties associated
with our use of seismic data, some of our drilling activities may not be successful or economically viable, and our overall drilling
success rate or our drilling success rate for activities in a particular area could decline, which could have a material adverse effect
on us.
We
may suffer delays or incremental costs due to difficulties in the negotiations with landowners and local communities where our reserves
are located.
Access
to the sites where we operate require agreements (including, for example, assessments, rights of way and access authorizations) with
the landowners and local communities. If we are unable to negotiate agreements with landowners, we may have to go to court to obtain
access to the sites of our operations, which may delay the progress of our operations at such sites. There
can be no assurance that disputes with landowners and local communities will not delay our operations or that any agreements we reach
with such landowners and local communities in the future will not require us to incur additional costs, thereby materially adversely
affecting our business, financial condition and results of operations. Local communities may also protest or take actions that restrict
or cause their elected government to restrict our access to the sites of our operations, which may have a material adverse effect on
our operations at such sites.
Unfavorable
credit and market conditions could negatively impact the Indonesian economy and may negatively affect our ability to access capital,
our business generally and results of operations.
Global
financial crises and related turmoil in the global financial system have may have had a negative impact on our business, financial condition
and results of operations. In particular, if disruptions in international credit markets, exacerbated by the sovereign debt crises or
global pandemics, adversely impact the Indonesian economy (where our oil and gas products are sold by the Government), our business may
suffer and may adversely affect our ability to access the credit or capital markets at a time when we would need financing, which could
have an impact on our flexibility to react to changing economic and business conditions. Any of the foregoing factors or a combination
of these factors, or similar factors not known to us presently, could have an adverse effect on our liquidity, results of operations
and financial condition.
The
marketability of our production depends largely upon the availability, proximity and capacity of oil and gas gathering systems, pipelines,
storage and processing facilities.
The
marketability of our production depends in part upon processing and storage. Transportation space on such gathering systems and pipelines
is occasionally limited and at times unavailable due to repairs or improvements being made to such facilities or due to such space being
utilized by other companies with priority transportation agreements. Our access to transportation options can also be affected by Indonesian
law, regulation of oil and gas production and transportation, general economic conditions and changes in supply and demand. These factors
and the availability of markets are beyond our control. If our access to these transportation and storage options dramatically changes,
the financial impact on us could be substantial and adversely affect our ability to produce and market our oil and gas.
Cyber-attacks
targeting systems and infrastructure used by the oil and gas industry may adversely impact our operations.
Our
business has become increasingly dependent on digital technologies to conduct certain exploration, development and production activities.
We depend on digital technology to estimate quantities of oil reserves, process and record financial and operating data, analyze seismic
and drilling information, and communicate with our employees and third-party partners. Unauthorized access to our seismic data, reserves
information or other proprietary information could lead to data corruption, communication interruption, or other operational disruptions
in our exploration or production operations. In addition, computer technology controls nearly all of the oil and gas distribution systems
in Indonesia, which are necessary to transport our production to market. A cyber-attack directed at oil and gas distribution systems
could damage critical distribution and storage assets or the environment, delay or prevent delivery of production to markets and make
it difficult or impossible to accurately account for production and settle transactions.
While
we have not experienced significant cyber-attacks, we may suffer such attacks in the future. Further, as cyber-attacks continue to evolve,
we may be required to expend significant additional resources to continue to modify or enhance our protective measures or to investigate
and remediate any vulnerability to cyber-attacks.
We
rely on independent experts and technical or operational service providers over whom we may have limited control.
We
use independent contractors to provide us with certain technical assistance and services. We rely upon the owners and operators of rigs
and drilling equipment, and upon providers of field services, to drill and develop our prospects to production. We also rely upon the
services of other third parties to explore and/or analyze our prospects to determine a method in which the prospects may be developed
in a cost-effective manner. Our limited control over the activities and business practices of these service providers, any inability
on our part to maintain satisfactory commercial relationships with them or their failure to provide quality services could materially
adversely affect our business, results of operations and financial condition.
Market
conditions for oil and gas, and particularly volatility of prices for oil and gas, could adversely affect our revenue, cash flows, profitability
and growth.
Our
revenue, cash flows, profitability and future rate of growth depend substantially upon prevailing prices for oil and gas. Prices also
affect the amount of cash flow available for capital expenditures and our ability to borrow money or raise additional capital. Lower
prices may also make it uneconomical for us to increase or even continue current production levels of oil and gas.
Prices
for oil and gas are subject to large fluctuations in response to relatively minor changes in the supply and demand for oil and gas, market
uncertainty and a variety of other factors beyond our control, including:
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changes
in foreign and domestic supply and demand for oil and gas; |
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political
stability and economic conditions in oil producing countries, particularly in the Middle East; |
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weather
conditions; |
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price
and level of foreign imports; |
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terrorist
activity; |
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availability
of pipeline and other secondary capacity; |
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general
economic conditions; |
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global
risks of more coronavirus outbreaks, or other global or local public health uncertainties; |
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domestic
and foreign governmental regulation; and |
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the
price and availability of alternative fuel sources. |
Estimates
of proved reserves and future net revenue are inherently imprecise.
The
process of estimating oil reserves in accordance with SEC requirements is complex and involves decisions and assumptions in evaluating
the available geological, geophysical, engineering and economic data. Accordingly, these estimates are imprecise. Actual future production,
oil and gas prices, revenues, taxes, capital expenditures, operating expenses and quantities of recoverable oil reserves most likely
will vary from those estimated. Any significant variance could materially affect the estimated quantities and present value of our reserves.
In addition, we may adjust estimates of proved reserves to reflect production history, results of exploration and development, prevailing
oil and gas prices and other factors, many of which are beyond our control.
Unless
we replace our oil reserves, our reserves and production will decline over time. Our business is dependent on our continued successful
identification of productive fields and prospects and the identified locations in which we drill in the future may not yield oil or natural
gas in commercial quantities.
Production
from oil properties declines as reserves are depleted, with the rate of decline depending on reservoir characteristics. Accordingly,
our current proved reserves will decline as these reserves are produced. Our future oil reserves and production, and therefore our cash
flows and income, are highly dependent on our success in efficiently developing our current reserves and economically finding or acquiring
additional recoverable reserves. While we have had success in identifying and developing commercially exploitable deposits and drilling
locations in the past, we may be unable to replicate that success in the future. We may not identify any more commercially exploitable
deposits or successfully drill, complete or produce more oil reserves, and the wells which we have drilled and currently plan to drill
within our blocks or concession areas may not discover or produce any further oil or gas or may not discover or produce additional commercially
viable quantities of oil or gas to enable us to continue to operate profitably. If we are unable to replace our current and future production,
the value of our reserves will decrease, and our business, financial condition and results of operations will be materially adversely
affected.
Our
business requires significant capital investment and maintenance expenses, which we may be unable to finance on satisfactory terms or
at all.
The
oil and natural gas industry is capital intensive and we expect to make substantial capital expenditures in our business and operations
for the exploration and production of oil reserves. The actual amount and timing of our future capital expenditures may differ materially
from our estimates as a result of, among other things, commodity prices, actual drilling results, the availability of drilling rigs and
other equipment and services, and regulatory, technological and competitive developments. In response to increases in commodity prices,
we may increase our actual capital expenditures. We will likely need to raise additional financing to support our business, and we intend
to finance our future capital expenditures through cash generated by our operations and potential future financing arrangements. However,
our financing needs may require us to alter or increase our capitalization substantially through the issuance of debt or equity securities
or the sale of assets. We also face the risk that financing arrangements (including bank loans or public or private offerings of debt
or equity securities) may not be available to us when needed on favorable terms or at all, which could adversely impact our ability to
operate our company.
If
our capital requirements vary materially from our current plans, we may require further financing. In addition, we will likely incur
significant financial indebtedness in the future, which may involve restrictions on other financing and operating activities. These changes
could cause our cost of doing business to increase, limit our ability to pursue acquisition opportunities, reduce cash flow used for
drilling and place us at a competitive disadvantage. A significant reduction in cash flows from operations or the availability of credit
could materially adversely affect our ability to achieve our planned growth and operating results.
Our
estimates regarding our market are based on our research but may prove incorrect.
This
prospectus contains certain data and information that we obtained from private publications. Statistical data in these publications also
include projections based on a number of assumptions. Our industry may not grow at the rate projected by market data, or at all. Failure
of this market to grow at the projected rate may have a material and adverse effect on our business and the market price of our ordinary
shares. In addition, the rapidly changing nature of the oil and gas industry results in significant uncertainties for any projections
or estimates relating to the growth prospects or future condition of our market. Furthermore, if any one or more of the assumptions underlying
the market data are later found to be incorrect, actual results may differ from the projections based on these assumptions. You should
not place undue reliance on these or other forward-looking statements. See “Cautionary Note Regarding Forward-Looking Statements.”
Risks
Related to Regulation of Our Oil and Gas Business
We
are subject to complex laws common to the oil and natural gas industry, particularly in Indonesia, which can have a material adverse
effect on our business, financial condition and results of operations.
The
oil and natural gas industry is subject to extensive regulation and intervention by governments throughout the world, including extensive
Indonesian regulations, in such matters as the award of exploration and production interests, the imposition of specific exploration
and drilling obligations, allocation of and restrictions on production, price controls, required divestments of assets and foreign currency
controls, and the development and nationalization, expropriation or cancellation of contract rights.
We
have been required in the past, and may be required in the future, to make significant expenditures to comply with governmental laws
and regulations, including with respect to the following matters:
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licenses, permits and other authorizations for drilling operations;
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reports
concerning operations; |
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compliance
with environmental, health and safety laws and regulations; |
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compliance
with the requirements to divest parts of our interest to domestic parties; |
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compliance
with requirements to sell certain portion of our production to domestic market; |
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adjustment
to the split between the contractor and the Government in respect of the production; |
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compliance
with local content requirements; |
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drafting
and implementing emergency planning; |
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plugging
and abandonment costs; and |
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taxation. |
Under
these laws and regulations, we could be liable for, among other things, personal injury, property damage, environmental damage and other
types of damage. Failure to comply with these laws and regulations may also result in the suspension or termination of our operations
and subject us to administrative, civil and criminal penalties. Moreover, these laws and regulations could change in ways that could
substantially increase our costs. Any such liabilities, obligations, penalties, suspensions, terminations or regulatory changes could
have a material adverse effect on our business, financial condition or results of operations.
In
addition, the terms and conditions of the agreements under which our oil and gas interests are held generally reflect negotiations with
governmental authorities and can vary significantly. These agreements take the form of special contracts, concessions, licenses, associations
or other types of agreements. Any suspensions, terminations or regulatory changes in respect of these special contracts, concessions,
licenses, associations or other types of agreements could have a material adverse effect on our business, financial condition or results
of operations.
Our
PSC for Citarum Block requires or may require us to relinquish portions of the subject contract area in certain circumstances, which
would potentially leave us with less area to explore.
Pursuant
to our production sharing contract with SKK Migas for Citarum Block, there are circumstances under which we are required or may be required
to relinquish portions of the contract area back to the Government, with such portions being subject to be agreed to between us and the
Government. Such circumstances include if we are unable to complete the work programs agreed to in our PSC for Citarum. If we relinquish
or are required to relinquish portions of Citarum, we could be left with fewer areas to explore and a resulting diminishment of potential
resources we could capitalize on. See “Business—Our Assets—Citarum Block” for further information. We may be
required to agree to similar provisions in future contracts with the Government.
The
interpretation and application of laws and regulations in Indonesia involves uncertainty.
The
courts in Indonesia may offer less certainty as to the judicial outcome or a more drawn out judicial process than is the case in more
established legal systems. Businesses can become involved in lengthy judicial proceedings over simple issues when rulings are not clearly
defined. Moreover, such problems can be compounded by the poor quality of legal drafting and excessive delays in the legal process for
resolving issues or disputes. These characteristics of the legal system in Indonesia could expose us to several kinds of risks, including
the possibility that effective legal redress may be more difficult to obtain; a higher degree of discretion on the part of the Government;
the lack of judicial or administrative guidance on interpreting the relevant laws or regulations; inconsistencies and conflicts between
and within various laws, regulations, decrees, orders and resolutions; or the relative inexperience or lack of predictability of the
judiciary and courts in such matters.
The
enforcement of laws in Indonesia may depend on and be subject to the interpretation of the relevant local authority. Such authority may
adopt an interpretation of an aspect of local law which differs from the advice given to us by local lawyers or even previous advice
given by the local authority itself. Matters of local autonomy are extremely controversial in Indonesia, adding further uncertainty to
the interpretation and application of the relevant legal and regulatory requirements. Furthermore, there is limited or no relevant case
law providing guidance on how courts would interpret such laws and the application of such laws to its concessions, join operations,
licenses, license applications or other arrangements. Even where such case law exists, it lacks the binding precedential value found
in the U.S. legal system.
For
example, on November 13, 2012, the Constitutional Court of the Republic of Indonesia (Mahkamah Konstitusi Republic Indonesia,
or MK) issued Decision 36/PUU-X/2012 (or MK Decision 36/2012). In it, the MK declared several articles in the Oil and Gas Law of 2001
invalid and dissolved Badan Pelaksana Minyak dan Gas Bumi (or BP Migas) for failing to directly manage oil and gas resources as
required by its interpretation of Article 33 of the Constitution of the Republic of Indonesia. In response to MK Decision 36/2012, the
Government created SKK Migas and authorized it to take over the functions of BP Migas pursuant to Presidential Regulation No. 9 of 2013
on the Implementation of Management of Natural oil and Gas Upstream Business Activities. However, while these arrangements have not been
challenged to date, there is a risk that future challenge to the current arrangements, and changes in Indonesian law generally, could
require us to modify our operation and development plans, and could adversely impact our results of operations.
Increased
regulation by the Government and governmental agencies may increase the cost of regulatory compliance and have an adverse impact on our
business, financial condition and results of operations.
Our
business operations in Indonesia are subject to an expanding system of laws, rules and regulations issued by numerous government bodies.
The evolving roles of SKK Migas and The Ministry of Energy and Mineral Resources of Indonesia (or MEMR), together with political changes
in Indonesia, has allowed other governmental agencies such as the Ministry of Trade, the Ministry of Forestry, the Ministry for Environment
and Bank Indonesia to increase their roles in regulating the oil and gas industry in Indonesia. In addition, the Indonesian tax authorities
have recently initiated additional tax audits and implemented measures to increase tax revenues from the oil and gas industry.
The
continued expansion of the roles of governmental agencies may result in the adoption of new legislation, regulations and practices with
which we would be required to comply. Such legislation, regulations and practices may be more stringent and may cause the amount and
timing of future legal and regulatory compliance expenditures to vary substantially from their current levels. They could also require
changes to our operations and development plans, which could adversely impact our results of operations.
The
interpretation and application of the Oil and Gas Law of 2001 and the anticipated enactment of a new oil and gas law is uncertain and
may adversely affect our business, financial condition and results of operations.
In
Indonesia, the complexity of the laws and regulations relating to oil and gas activities is compounded by uncertainties in the legal
and regulatory framework. Indonesia’s Oil and Gas Law of 2001 went into effect on November 23, 2001 (or the Oil and Gas Law). This
law sets forth a statutory body of general principles governing oil and gas activities, which are further developed and implemented in
a series of Government regulations, presidential decrees and ministerial decrees. The provisions of the Oil and Gas Law are generally
broad, and few sources of interpretative guidance are available. In addition, not all of the implementing regulations to the Oil and
Gas Law have been issued and some have only recently been enacted. It is uncertain how these regulations will affect us and our operations
without clear instances of their application, while the uncertainty surrounding the Oil and Gas Law and its implementing regulations
has increased the risks, and may result in increases in the costs, of conducting oil and gas activities in Indonesia.
The
Government may also adopt new laws and/or policies regarding oil and gas exploration, development and production that differ from the
policies currently in place and that adversely impact the cost of doing business in Indonesia. If and to the extent any changes to the
current legal and regulatory framework are detrimental to our business and our position, our business, development plans, financial condition
and results of operations could be adversely affected.
We
and our operations are subject to numerous environmental, health and safety laws and regulations which may result in material liabilities
and costs.
We
and our operations are subject to various international, domestic and foreign local environmental, health and safety laws and regulations
governing, among other things, the emission and discharge of pollutants into the ground, air or water; the generation, storage, handling,
use, transportation and disposal of regulated materials; and human health and safety. Our operations are also subject to certain environmental
risks that are inherent in the oil and gas industry and which may arise unexpectedly and result in material adverse effects on our business,
financial condition and results of operations. Breach of environmental laws, as well as impacts on natural resources and unauthorized
use of such resources, could result in environmental administrative investigations and/or lead to the termination of our concessions
and contracts. Other potential consequences include fines and/or criminal environmental actions
We
are required to obtain environmental permits from governmental authorities for our operations, including drilling permits for our wells.
We may not be at all times in complete compliance with these permits and the environmental and health and safety laws and regulations
to which we are subject. If we violate or fail to comply with such requirements, we could be fined or otherwise sanctioned by regulators,
including through the revocation of our permits or the suspension or termination of our operations. If we fail to obtain, maintain or
renew permits in a timely manner or at all (such as due to opposition from partners, community or environmental interest groups, governmental
delays or any other reasons) or if we face additional requirements due to changes in applicable laws and regulations, our operations
could be adversely affected, impeded, or terminated, which could have a material adverse effect on our business, financial condition
or results of operations.
For
example, Law No. 32 of 2009 on Protection and Management of Environment (or the Environmental Law) as amended by Law No. 11 of 2020 on
Job Creation (or the Omnibus Law) and its implementing regulation, Government Regulation No. 22 of 2021 on Environmental Protection and
Management (or GR 22/2021), require an entity conducting oil and gas business operations have its environmental impact assessment report
(Analisis Mengenai Dampak Lingkungan, or AMDAL), as well as an environmental management effort plan (Upaya Pengelolaan Lingkungan
Hidup, or UKL) or an environmental monitoring effort plan (Upaya Pemantauan Lingkungan Hidup or UPL), approved. Under the
Environmental Law, our environmental permit may be revoked should we fail to meet the obligations contained in the relevant AMDAL or
UKL or UPL, which can in turn lead to the nullification of our business license.
We,
as the owner, shareholder or the operator of certain of our past, current and future discoveries and prospects, could be held liable
for some or all environmental, health and safety costs and liabilities arising out of our actions and omissions as well as those of our
block partners, third-party contractors, predecessors or other operators. To the extent we do not address these costs and liabilities
or if we do not otherwise satisfy our obligations, our operations could be suspended, terminated or otherwise adversely affected. We
have also contracted with and intend to continue to hire third parties to perform services related
to our operations. There is a risk that we may contract with third parties with unsatisfactory environmental, health and safety records
or that our contractors may be unwilling or unable to cover any losses associated with their acts and omissions. Accordingly, we could
be held liable for all costs and liabilities arising out of the acts or omissions of our contractors, which could have a material adverse
effect on our results of operations and financial condition.
Releases
of regulated substances may occur and can be significant. Under certain environmental laws and regulations applicable to us in Indonesia,
we could be held responsible for all of the costs relating to any contamination at our past and current facilities and at any third party
waste disposal sites used by us or on our behalf. Pollution resulting from waste disposal, emissions and other operational practices
might require us to remediate contamination, or retrofit facilities, at substantial cost. We also could be held liable for any and all
consequences arising out of human exposure to such substances or for other damage resulting from the release of hazardous substances
to the environment, property or to natural resources, or affecting endangered species or sensitive environmental areas. Environmental
laws and regulations also require that wells be plugged and sites be abandoned and reclaimed to the satisfaction of the relevant regulatory
authorities. We are currently required to, and in the future may need to, plug and abandon sites in certain blocks in each of the countries
in which we operate, which could result in substantial costs.
As
in other areas, the interpretation and application of environmental laws in Indonesia involves a degree of uncertainty. Such changes
in the interpretation and application of existing laws and regulations, or the enactment of new, more stringent requirements, may have
and result in an adverse impact on our business, development plans, financial condition and results of operations.
We
may be unable to obtain or maintain special permits to conduct drilling and seismic activities in forest areas in Indonesia.
Some
of our proposed drilling locations are situated within forestry areas. In order to conduct drilling and seismic activities in the forest
area within Indonesia, we will need to obtain “Borrow-to-use permit of forest area (Izin Pinjam Pakai Kawasan Hutan, or IPPKH)”
from the Indonesian Ministry of Forestry. Borrow-to-use permit of forest area is granted for companies to use the forest area other than
forestry activities. The Indonesian government has provided for such requirements in several laws and regulations since 1990 concerning
conservation of natural resources, natural primary forest and the ecosystem. In 2014, the Indonesian government further specified that
priority of Borrow-to-use permit of forest area would be given to geothermal, oil and gas production activities.
The
application for a Borrow-to-use permit must satisfy both administrative and the technical requirements. The maximum validity period for
a Borrow-to-use permit for an exploration or production activity is no more than the validity period of the relevant license for the
exploration and the production activities. However, in respect of a follow through exploration during a production period, the Borrow-to-use
permit may be granted for a maximum period of two years and it is non-extendable. Prior to 2018, the application and process of Borrow-to-use
permit of forest area was complex because applicants had to process different requirements at different offices in the Ministry of Forestry,
and between government agencies and local administrations, frequently with no certainty of processing time and cost.
With
the announcement of “online single submission (OSS)” processing system in 2018 by the Ministry of Forestry, the time required
for processing the permit was changed from 180 work days to 34 work days. However, this new system has yet to be fully implemented, and
numerous documents and other permits (including the local governor’s recommendation and environmental permits) as well as a work
program and maps are required before Borrow-to-use permit of forest area can be submitted to the Ministry of Forestry. Any delay of in
the issuance to us of Borrow-to-use permit of forest area, or our inability to main such permit for any reason, would cause delays in
our ability to conduct drilling and seismic activities in the subject area, which in turn could adversely impact our business plans and
results of operations.
Climate
change and climate change legislation and regulatory initiatives could result in increased operating costs and decreased demand for the
oil and natural gas that we produce.
Climate
change, the costs that may be associated with its effects, and the regulation of greenhouse gas (or GHG) emissions have the potential
to affect our business in many ways, including increasing the costs to provide our products and services, reducing the demand for and
consumption of our products and services (due to change in both costs and weather patterns), and the economic health of the regions in
which we operate, all of which can create financial risks. In addition, legislative and regulatory responses related to GHG emissions
and climate change may increase our operating costs.
Moreover,
experts believe climate change poses potential physical risks, including an increase in sea level and changes in weather conditions,
such as an increase in changes in precipitation and extreme weather events. In addition, warmer winters as a result of global warming
could also decrease demand for natural gas. To the extent that such unfavorable weather conditions are exacerbated by global climate
change or otherwise, our operations may be adversely affected to a greater degree than we have previously experienced, including increased
delays and costs. However, the uncertain nature of changes in extreme weather events (such as increased frequency, duration, and severity)
and the long period of time over which any changes would take place make any estimations of future financial risk to our operations caused
by these potential physical risks of climate change unreliable. Moreover, the regulation of GHGs and the physical impacts of climate
change in the areas in which we, our customers and the end-users of our products operate could adversely impact our operations and the
demand for our products.
Labor
laws and regulations in Indonesia and labor unrest may materially adversely affect our results of operations.
Laws
and regulations which facilitate the forming of labor unions, combined with weak economic conditions, have resulted and may result in
labor unrest and activism in Indonesia. In 2000, the Government issued Law No. 21 of 2000 regarding Labor Unions (or the Labor Union
Law). The Labor Union Law permits employees to form unions without intervention from an employer, the government, a political party or
any other party. On March 25, 2003, President Megawati enacted Law No. 13 of 2003 regarding Employment (or the Labor Law) which, among
other things, increased the amount of severance, pension, medical coverage, service and compensation payments payable to employees upon
termination of employment. The Labor Law requires further implementation of regulations that may substantively affect labor relations
in Indonesia. The Labor Law requires companies with 50 or more employees establish bipartite forums with participation from employers
and employees. The Labor Law also requires a labor union to have participation of more than half of the employees of a company in order
for a collective labor agreement to be negotiated and creates procedures that are more permissive to the staging of strikes. Following
the enactment, several labor unions urged the Indonesian Constitutional Court to declare certain provisions of the Labor Law unconstitutional
and order the Government to revoke those provisions. The Indonesian Constitutional Court declared the Labor Law valid except for certain
provisions, including relating to the right of an employer to terminate its employee who committed a serious mistake and criminal sanctions
against an employee who instigates or participates in an illegal labor strike.
Labor
unrest and activism in Indonesia could disrupt our operations, our suppliers or contractors and could affect the financial condition
of Indonesian companies in general.
Risks
Related to Doing Business in Indonesia
As
the domestic Indonesian market constitutes the major source of our revenue, the downturn in the rate of economic growth in Indonesia
or other countries due to the unprecedented and challenging global market and economic conditions, whether due to the COVID-19 pandemic
or any other such downturn for any other reason, will be detrimental to our results of operations.
The
performance and growth of our business are necessarily dependent on the health of the overall Indonesian economy. Any downturn in the
rate of economic growth in Indonesia, whether due to political instability or regional conflicts, global health crisis, economic slowdown
elsewhere in the world or otherwise, may have a material adverse effect on demand for the commodities we produce. The Indonesian economy
is also largely driven by the performance of the agriculture sector, which depends on the impact of the monsoon season, which is difficult
to predict. In the past, economic slowdowns have harmed manufacturing industries, including companies engaged in the oil and gas extraction.
During 2020, Indonesian gross domestic product declined for the first time in several years with a decline of 2.1% according to the International
Monetary Fund, and any future slowdown in the Indonesian economy could have a material adverse effect on the demand for the commodities
we produce and, as a result, on our business, financial condition and results of operations.
In
addition, the Indonesian securities market and the Indonesian economy are influenced by economic and market conditions in other countries.
Although economic conditions are different in each country, investors’ reactions to developments in one country can have adverse
effect on the securities of companies in other countries, including Indonesia. A loss of investor confidence in the financial systems
of other emerging markets may cause volatility in Indonesian financial markets and, indirectly, in the Indonesian economy in general.
Any worldwide financial instability could also have a negative impact on the Indonesian economy, including the movement of exchange rates
and interest rates in Indonesia. Any slowdown in the Indonesian economy, or future volatility in global commodity prices, could adversely
affect the growth of our business in Indonesia.
The
Indonesian economy and financial markets are also significantly influenced by worldwide economic, financial and market conditions. Any
financial turmoil, especially in the United States, United Kingdom, Europe or China, may have a negative impact on the Indonesian economy.
Although economic conditions differ in each country, investors’ reactions to any significant developments in one country can have
adverse effects on the financial and market conditions in other countries. A loss in investor confidence in the financial systems, particularly
in other emerging markets, may cause increased volatility in Indonesian financial markets.
The
effect and impact of the recently enacted Omnibus Law on job creation in Indonesia are not immediately known and subject to ongoing review.
On
November 2, 2020, the Government of Indonesia issued the Omnibus Law, which aims to attract investment, create new jobs, and stimulate
the economy by, among other things, simplifying the licensing process and harmonizing various laws and regulations, and making policy
decisions faster for the central government to respond to global or other changes or challenges. The Omnibus Law amended more than 75
laws (including aspects of the Oil and Gas Law) and up to April 2021, the central government has issued at least 50 implementing regulations
making the Omnibus Law one of the most sweeping regulatory reform in Indonesian history. The Omnibus Law introduces a number of new concepts,
including a new risk-based assessment (i.e. low, medium and high risks) in issuing licenses for businesses, removes foreign ownership
restrictions in various industries, simplifies environmental assessment requirements and licensing procedures, and provides a more flexible
manpower regulations. Given the extensive breadth of changes introduced by the Omnibus Law, the full impact of various regulation and
policy changes on our business and operation in Indonesia are presently unknown and subject to our ongoing review. Therefore, we are
subject to the risk that compliance with the Omnibus Law may be challenging and may distract our management, and may also require us
to alter operations, which in turn could impact our results of operations.
Current
political and social events in Indonesia may adversely affect our business.
Since
1998, Indonesia has experienced a process of democratic change, resulting in political and social events that have highlighted the unpredictable
nature of Indonesia’s changing political landscape. In 1999, Indonesia conducted its first free elections for representatives in
parliament. In 2004, 2009 and 2014, elections were held in Indonesia to elect the President, Vice-President and representatives in parliament.
Indonesia also has many political parties, without any one party holding a clear majority. Due to these factors, Indonesia has, from
time to time, experienced political instability, as well as general social and civil unrest. For example, since 2000, thousands of Indonesians
have participated in demonstrations in Jakarta and other Indonesian cities both for and against former presidents Abdurrahman Wahid,
Megawati Soekarnoputri and Susilo Bambang Yudhoyono and current President Joko Widodo as well as in response to specific issues, including
fuel subsidy reductions, privatization of state assets, anti-corruption measures, decentralization and provincial autonomy, and the American-led
military campaigns in Afghanistan and Iraq. Although these demonstrations were generally peaceful, some turned violent.
In
addition, effective January 1, 2015, a fixed diesel subsidy of Rp1,000 per liter was implemented and the gasoline subsidy was ended.
Although the implementation did not result in any significant violence or political instability, the announcement and implementation
also coincided with a period where crude oil prices had dropped very significantly from 2014. With the purpose to provide stability of
the retail sale price of the gasoline and diesel, the Energy and Mineral Resources Ministry issued on February 28th Ministerial Decree
No. 62/2020 that erases a price floor for unsubsidized gasoline and diesel set by a previous decree, providing flexibility to reduce
prices as low as possible. The new decree still maintains a price ceiling for such fuels pegged to prices in Singapore. The Government
reviews and adjusts the price for fuel on monthly basis and implements the adjusted fuel price in the following month. There can be no
assurance that future increases in crude oil and fuel prices will not result in political and social instability.
Furthermore,
separatist movements and clashes between religious and ethnic groups have also resulted in social and civil unrest in parts of Indonesia,
such as Aceh in the past and in Papua currently, where there have been clashes between supporters of those separatist movements and the
Indonesian military, including continued activity in Papua, by separatist rebels that has led to violent incidents. There have also been
inter-ethnic conflicts, for example in Kalimantan, as well as inter-religious conflict such as in Maluku and Poso.
Also,
labor issues have also come to the fore in Indonesia. In 2003, the Government enacted a new labor law that gave employees greater protections.
Occasional efforts to reduce these protections have prompted an upsurge in public protests as workers responded to policies that they
deemed unfavorable.
As
a result, there can be no assurance that social, political and civil disturbances will not occur in the future and on a wider scale,
or that any such disturbances will not, directly or indirectly, materially and adversely affect our business, financial condition, results
of operations and prospects.
Deterioration
of political, economic and security conditions in Indonesia may adversely affect our operations and financial results.
Any
major hostilities involving Indonesia, a substantial decline in the prevailing regional security situation or the interruption or curtailment
of trade between Indonesia and its present trading partners could have a material adverse effect on our operations and, as a result,
our financial results.
Prolonged
and/or widespread regional conflict in the South East Asia could have the following results, among others:
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capital
market reassessment of risk and subsequent redeployment of capital to more stable areas making it more difficult for us to obtain
financing for potential development projects; |
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security
concerns in Indonesia, making it more difficult for our personnel or supplies to enter or exit the country; |
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concerns leading to evacuation of our personnel; |
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damage
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inability
of our service and equipment providers to deliver items necessary for us to conduct our operations in Indonesia, resulting in delays;
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the
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Loss
of property and/or interruption of our business plans resulting from hostile acts could have a significant negative impact on our earnings
and cash flow. In addition, we may not have enough insurance to cover any loss of property or other claims resulting from these risks.
Terrorist
activities in Indonesia could destabilize Indonesia, which would adversely affect our business, financial condition and results of operations,
and the market price of our securities.
There
have been a number of terrorist incidents in Indonesia, including the May 2005 bombing in Central Sulawesi, the Bali bombings in October
2002 and October 2005 and the bombings at the JW Marriot and Ritz Carlton hotels in Jakarta in July 2009, which resulted in deaths and
injuries. On January 14, 2016, several coordinated bombings and gun shootings occurred in Jalan Thamrin, a main thoroughfare in Jakarta,
resulting in a number of deaths and injuries.
Although
the Government has successfully countered some terrorist activities in recent years and arrested several of those suspected of being
involved in these incidents, terrorist incidents may continue and, if serious or widespread, might have a material adverse effect on
investment and confidence in, and the performance of, the Indonesian economy and may also have a material adverse effect on our business,
financial condition, results of operations and prospects and the market price of our securities.
Negative
changes in global, regional or Indonesian economic activity could adversely affect our business.
Changes
in the Indonesian, regional and global economies can affect our performance. Two significant events in the past that impacted Indonesia’s
economy were the Asian economic crisis of 1997 and the global economic crisis which started in 2008. The 1997 crisis was characterized
in Indonesia by, among others, currency depreciation, a significant decline in real gross domestic product, high interest rates, social
unrest and extraordinary political developments. While the global economic crisis that arose from the subprime mortgage crisis in the
United States did not affect Indonesia’s economy as severely as in 1997, it still put Indonesia’s economy under pressure.
The global financial markets have also experienced volatility as a result of expectations relating to monetary and interest rate policies
of the United States, concerns over the debt crisis in the Eurozone, and concerns over China’s economic health. Uncertainty over
the outcome of the Eurozone governments’ financial support programs and worries about sovereign finances generally are ongoing.
If the crisis becomes protracted, we can provide no assurance that it will not have a material and adverse effect on Indonesia’s
economic growth and consequently on our business.
An
additional significant event that as of the date of this annual report is still unfolding and uncertain is the novel coronavirus outbreak
which began in early 2020 and the related disease, COVID-19, which was declared as a pandemic by the World Health Organization on March
11, 2020. Indonesian government officials called for social distancing and isolation and considered to enforce a lockdown in affected
areas in an attempt to minimize the spread of the virus. The restrictions currently in place, whether mandated by the Government or implemented
locally, or if other COVID-19 related conditions persist in Indonesia, the adverse economic situation in Indonesia may greatly impact
our business and operations.
Adverse
economic conditions in Indonesia could result in less business activity, less disposable income available for consumers to spend and
reduced consumer purchasing power, which may reduce demand for communication services, including our services, which in turn would have
an adverse effect on our business, financial condition, results of operations and prospects. There is no assurance that there will not
be a recurrence of economic instability in future, or that, should it occur, it will not have an impact on the performance of our business.
Fluctuations
in the value of the Indonesian Rupiah may materially and adversely affect us.
Whilst
our functional currency is the U.S. Dollar, depreciation and volatility of the Indonesian Rupiah could potentially affect our business.
A sharp depreciation of Indonesian Rupiah may potentially create difficulties in purchasing imported goods and services which are critical
for our operation. As shown during the Asian monetary crisis in 1998, imported goods became scarce as suppliers often chose to keep their
stocks in anticipation of further deterioration of the Indonesian Rupiah.
In
addition, while the Indonesian Rupiah has generally been freely convertible and transferable, from time to time, Bank Indonesia has intervened
in the currency exchange markets in furtherance of its policies, either by selling Indonesian Rupiah or by using its foreign currency
reserves to purchase Indonesian Rupiah. We can give no assurance that the current floating exchange rate policy of Bank Indonesia will
not be modified or that the Government will take additional action to stabilize, maintain or increase the Indonesian Rupiah’s value,
or that any of these actions, if taken, will be successful. Modification of the current floating exchange rate policy could result in
significantly higher domestic interest rates, liquidity shortages, capital or exchange controls, or the withholding of additional financial
assistance by multinational lenders. This could result in a reduction of economic activity, an economic recession or loan defaults, and
as a result, we may also face difficulties in funding our capital expenditures and in implementing our business strategy. Any of the
foregoing consequences could have a material adverse effect on our business, financial condition, results of operations and prospects.
Downgrades
of credit ratings of the Government or Indonesian companies could adversely affect our business.
As
of the date of this prospectus, Indonesia’s sovereign foreign currency long-term debt was rated “Baa2” by Moody’s,
“Negative” by Standard & Poor’s and “BBB” by Fitch Ratings. Indonesia’s short-term foreign currency
debt is rated “A-2” by Standard & Poor’s and “F2” by Fitch Ratings.
We
can give no assurance that Moody’s, Standard & Poor’s or Fitch Ratings will not change or downgrade the credit ratings
of Indonesia. Any such downgrade could have an adverse impact on liquidity in the Indonesian financial markets, the ability of the Government
and Indonesian companies, including us, to raise additional financing, and the interest rates and other commercial terms at which such
additional financing is available. Interest rates on our floating rate Rupiah-denominated debt would also likely increase. Such events
could have material adverse effects on our business, financial condition, results of operations, prospects and/or the market price of
our securities.
Indonesia
is vulnerable to natural disasters and events beyond our control, which could adversely affect our business and operating results.
Many
parts of Indonesia, including areas where we operate, are prone to natural disasters such as floods, lightning strikes, cyclonic or tropical
storms, earthquakes, volcanic eruptions, droughts, power outages and other events beyond our control. The Indonesian archipelago is one
of the most volcanically active regions in the world as it is located in the convergence zone of three major lithospheric plates. It
is subject to significant seismic activity that can lead to destructive earthquakes, tsunamis or tidal waves. Flash floods and more widespread
flooding also occur regularly during the rainy season from November to April. Cities, especially Jakarta, are frequently subject to severe
localized flooding which can result in major disruption and, occasionally, fatalities. Landslides regularly occur in rural areas during
the wet season. From time to time, natural disasters have killed, affected or displaced large numbers of people and damaged our equipment.
We cannot assure you that future natural disasters, such as the spread of the novel coronavirus, will not have a significant impact on
us, or Indonesia or its economy. A significant earthquake, other geological disturbance or weather-related natural disaster in any of
Indonesia’s more populated cities and financial centers could severely disrupt the Indonesian economy and undermine investor confidence,
thereby materially and adversely affecting our business, financial condition, results of operations and prospects.
We
may be affected by uncertainty in the balance of power between local governments and the central government in Indonesia
Indonesian
Law No.25 of 1999 regarding Fiscal Decentralization and Law No.22 of 1999 regarding Regional Autonomy were passed by the Indonesian parliament
in 1999 and further implemented by Government Regulation No.38 of 2007. Law No.22 of 1999 has been revoked by and replaced by the provisions
on regional autonomy of Law No.32 of 2004 as amended by Law No.8 of 2005 and Law No.12 of 2008. Law No.32 of 2004 and its amendments
were revoked and replaced by Law No.23 of 2014 regarding Regional Autonomy as amended by Government Regulation in Lieu of Law No.2 of
2014, Law No.2 of 2015 and Law No.9 of 2015. Law No.25 of 1999 has been revoked and replaced by Law No.33 of 2004 regarding the Fiscal
Balance between the Central and the Regional Governments respectively. Currently, there is uncertainty in respect of the balance between
the local and the central governments and the procedures for renewing licenses and approvals and monitoring compliance with environmental
regulations. In addition, some local authorities have sought to levy additional taxes or obtain other contributions. There can be no
assurance that a balance between local governments and the central government will be effectively established or that our business, financial
condition, results of operations and prospects will not be adversely affected by dual compliance obligations and further uncertainty
as to legal authority to levy taxes or promulgate other regulations affecting our business.
Failure
to comply with the U.S. Foreign Corrupt Practices Act of 1977 (or FCPA) could result in fines, criminal penalties, and an adverse effect
on our business.
We
operate in Indonesia, which is a jurisdiction known to be challenged by corruption. As such, we are subject, however, to the risk that
we, our affiliated entities or our or their respective officers, directors, employees and agents may take action determined to be in
violation of such anti-corruption laws, including the FCPA. Any such violation could result in substantial fines, sanctions, civil and/or
criminal penalties, curtailment of operations, and might adversely affect our business, results of operations or financial condition.
In addition, actual or alleged violations could damage our reputation and ability to do business. Furthermore, detecting, investigating,
and resolving actual or alleged violations is expensive and can consume significant time and attention of our management.
Risks
Related to Our Corporate Structure
We
are a holding company, and will rely on dividends paid by our subsidiaries for our cash needs. Any limitation on the ability of our subsidiaries
to make dividend payments to us, or any tax implications of making dividend payments to us, could limit our ability to pay our parent
company expenses or pay dividends to holders of our ordinary shares.
We
are a holding company and conduct substantially all of our business through our operating subsidiaries, which are limited liability companies
established in Indonesia. We will rely on dividends paid by our subsidiaries for our cash needs, including the funds necessary to pay
dividends and other cash distributions to our shareholders, to service any debt we may incur and to pay our operating expenses. If applicable
laws, rules and regulations in Indonesia in the future limit or preclude our Indonesian subsidiaries from making dividends to us, our
ability to fund our holding company obligations or pay dividends on our ordinary shares could be materially and adversely affected. We
may also enter into debt arrangements in the future which limit our ability to receive dividends or distributions from our operating
subsidiaries or pay dividends to the holders of our ordinary shares. Indonesian or Cayman Island tax laws, rules and regulations may
also limit our future ability to receive dividends or distributions from our operating subsidiaries or pay dividends to the holders of
our ordinary shares.
We
may become subject to taxation in the Cayman Islands which would negatively affect our results of operations.
We
have received an undertaking from the Financial Secretary of the Cayman Islands that, in accordance with section 6 of the Tax Concessions
Act (Revised) of the Cayman Islands, until the date falling 20 years after November 2, 2018, being the date of such undertaking, no law
which is enacted in the Cayman Islands imposing any tax to be levied on profits, income, gains or appreciations shall apply to us or
our operations and, in addition, that no tax to be levied on profits, income, gains or appreciations or which is in the nature of estate
duty or inheritance tax shall be payable (i) on or in respect of the shares, debentures or other obligations of our company or (ii) by
way of the withholding in whole or in part of a payment of any “relevant payment” as defined in section 6(3) of the Tax Concessions
Act (Revised). If we otherwise were to become subject to taxation in the Cayman Islands, our financial condition and results of operations
could be materially and adversely affected. See “Taxation—Cayman Islands Taxation.”
You
may face difficulties in protecting your interests, and your ability to protect your rights through the U.S. Federal courts may be limited,
as a result of our company being incorporated under the laws of the Cayman Islands.
We
are a Cayman Islands exempted company with limited liability and substantially all of our assets will be located outside the United States.
In addition, most of our directors and officers are nationals or residents of jurisdictions other than the United States and all or a
substantial portion of their assets are located outside the United States. As a result, it may be difficult for investors to effect service
of process within the United States upon us or our directors or executive officers, or enforce judgments obtained in the United States
courts against us or our directors or officers.
Further,
mail addressed to us and received at our registered office will be forwarded unopened to the forwarding address supplied by our directors.
Our directors will only receive, open or deal directly with mail which is addressed to them personally (as opposed to mail which is only
addressed to us). We, our directors, officers, advisors or service providers (including the organization which provides registered office
services in the Cayman Islands) will not bear any responsibility for any delay, howsoever caused, in mail reaching this forwarding address.
Our
corporate affairs will be governed by our amended and restated memorandum and articles of association, the Companies Law (Revised) (as
the same may be supplemented or amended from time to time) and the common law of the Cayman Islands. The rights of shareholders to take
action against the directors, actions by minority shareholders and the fiduciary responsibilities of our directors to us under Cayman
Islands law are to a large extent governed by the common law of the Cayman Islands. The common law of the Cayman Islands is derived in
part from judicial precedent in the Cayman Islands as well as from English common law, the decisions of whose courts are of persuasive
authority, but are not technically binding on a court in the Cayman Islands. The rights of our shareholders and the fiduciary responsibilities
of our directors under Cayman Islands law are not as clearly established as they would be under statutes or judicial precedent in some
jurisdictions in the United States. In particular, the Cayman Islands has a less developed body of securities laws as compared to the
United States, and certain states, such as Delaware, have more fully developed and judicially interpreted bodies of corporate law. As
a result, there may be significantly less protection for investors than is available to investors in companies organized in the United
States, particularly Delaware. In addition, Cayman Islands companies may not have standing to initiate a shareholders derivative action
in a Federal court of the United States.
The
Cayman Islands courts are also unlikely:
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recognize or enforce against us judgments of courts of the United States based on certain civil liability provisions of United States
securities laws; and |
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impose liabilities against us, in original actions brought in the Cayman Islands, based on certain civil liability provisions of
United States securities laws that are penal in nature. |
There
is no statutory recognition in the Cayman Islands of judgments obtained in the United States, although the courts of the Cayman Islands
will in certain circumstances recognize and enforce a non-penal judgment of a foreign court of competent jurisdiction without retrial
on the merits. The Grand Court of the Cayman Islands may stay proceedings if concurrent proceedings are being brought elsewhere.
Like
many jurisdictions in the United States, Cayman Islands law permits mergers and consolidations between Cayman Islands companies and between
Cayman Islands companies and non-Cayman Islands companies and any such company may be the surviving entity for the purposes of mergers
or the consolidated company for the purposes of consolidations. For these purposes, (a) “merger” means the merging of two
or more constituent companies and the vesting of their undertaking, property and liabilities in one of such companies as the surviving
company and (b) a “consolidation” means the combination of two or more constituent companies into a consolidated company
and the vesting of the undertaking, property and liabilities of such companies to the consolidated company. In order to effect such a
merger or consolidation, the directors of each constituent company must approve a written plan of merger or consolidation, which must,
in most instances, then be authorized by a special resolution of the shareholders of each constituent company and such other authorization,
if any, as may be specified in such constituent company’s articles of association. A merger between a Cayman parent company and
its Cayman subsidiary or subsidiaries does not require authorization by a resolution of shareholders. For this purpose a subsidiary is
a company of which at least 90% of the votes cast at its general meeting are held by the parent company. The consent of each holder of
a fixed or floating security interest over a constituent company is required unless this requirement is waived by a court in the Cayman
Islands. The plan of merger or consolidation must be filed with the Registrar of Companies together with a declaration as to the solvency
of the consolidated or surviving company, a list of the assets and liabilities of each constituent company and an undertaking that a
copy of the certificate of merger or consolidation will be given to the members and creditors of each constituent company and published
in the Cayman Islands Gazette. Dissenting shareholders have the right to be paid the fair value of their shares (which, if not agreed
between the parties, will be determined by the Cayman Islands court) if they follow the required procedures, subject to certain exceptions.
Court approval is not required for a merger or consolidation which is effected in compliance with these statutory procedures.
In
addition, there are statutory provisions that facilitate the reconstruction and amalgamation of companies, provided that the arrangement
is approved by a majority in number of each class of shareholders and creditors with whom the arrangement is to be made, and who must
in addition represent three-fourths in value of each such class of shareholders or creditors, as the case may be, that are present and
voting either in person or by proxy at a meeting, or meetings, convened for that purpose. The convening of the meetings and subsequently
the arrangement must be sanctioned by the Grand Court of the Cayman Islands. While a dissenting shareholder has the right to express
to the court the view that the transaction ought not be approved, the court can be expected to approve the arrangement if it determines
that:
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the
statutory provisions as to the required majority vote have been met; |
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the
shareholders have been fairly represented at the meeting in question, the statutory majority are acting bona fide without coercion
of the minority to promote interests adverse to those of the class and that the meeting was properly constituted; |
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the
arrangement is such that it may reasonably be approved by an intelligent and honest man of that share class acting in respect of
his interest; and |
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the
arrangement is not one which would be more properly sanctioned under some other provision of the Companies Act. |
If
the arrangement and reconstruction is approved, the dissenting shareholder would have no rights comparable to appraisal rights, which
would otherwise ordinarily be available to dissenting shareholders of U.S. corporations, providing rights to receive payment in cash
for the judicially determined value of the shares.
In
addition, there are further statutory provisions to the effect that, when a take-over offer is made and approved by holders of 90.0%
in value of the shares affected (within four months after the making of the offer), the offeror may, within two months following the
expiry of such period, require the holders of the remaining shares to transfer such shares on the terms of the offer. An objection can
be made to the Grand Court of the Cayman Islands, but this is unlikely to succeed unless there is evidence of fraud, bad faith, collusion
or inequitable treatment of shareholders.
As
a result of all of the above, public shareholders may have more difficulty in protecting their interests in the face of actions taken
by management, members of our board of directors or controlling shareholders than they would as public shareholders of a U.S. company.
Provisions
of our charter documents or Cayman Islands law could delay or prevent an acquisition of our company, even if the acquisition may be beneficial
to our shareholders, could make it more difficult for you to change management, and could have an adverse effect on the market price
of our ordinary shares.
Provisions
in our amended and restated memorandum and articles of association may discourage, delay or prevent a merger, acquisition or other change
in control that shareholders may consider favorable, including transactions in which shareholders might otherwise receive a premium for
their shares. In addition, these provisions may frustrate or prevent any attempt by our shareholders to replace or remove our current
management by making it more difficult to replace or remove our board of directors. Such provisions may reduce the price that investors
may be willing to pay for our ordinary shares in the future, which could reduce the market price of our ordinary shares. These provisions
include:
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a
requirement that extraordinary general meetings of shareholders be called only by the directors or, in limited circumstances, by
the directors upon shareholder requisition; |
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an
advance notice requirement for shareholder proposals and nominations to be brought before an annual general meeting; |
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the
authority of our board of directors to issue preferred shares with such terms as our board of directors may determine; and |
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a
requirement of approval of not less than 66 2/3% of the votes cast by shareholders entitled to vote thereon in order to amend any
provisions of our amended and restated memorandum and articles of association. |
We
may be classified as a passive foreign investment company, which could result in adverse U.S. federal income tax consequences to U.S.
holders of our ordinary shares.
A
foreign corporation will be treated as a “passive foreign investment company” (or PFIC) for U.S. federal income tax purposes
if either (1) at least 75% of its gross income for any taxable year consists of certain types of “passive income” or (2)
at least 50% of the average value of the corporation’s assets produce or are held for the production of those types of “passive
income”. For purposes of these tests, “passive income” includes dividends, interest, and gains from the sale or exchange
of investment property and rents and royalties other than rents and royalties which are received from unrelated parties in connection
with the active conduct of a trade or business. U.S. shareholders of a PFIC are subject to a disadvantageous U.S. federal income tax
regime with respect to the income derived by the PFIC, the distributions they receive from the PFIC and the gain, if any, they derive
from the sale of other disposition of their shares in the PFIC.
Based
upon our current and anticipated method of operations, we do not believe that we should be a PFIC with respect to our 2020 taxable year,
and we do not expect to become a PFIC in any future taxable year. However, no assurance can be given that the U.S. Internal Revenue Service
(or IRS) or a court of law will accept this position, and there is a risk that the IRS or a court of law could determine that we are
a PFIC. Moreover, no assurance can be given that we would not constitute a PFIC for any future taxable year if the nature and extent
of our operations change.
If
the IRS were to find that we are or have been a PFIC for any taxable year, our U.S. shareholders would face adverse U.S. federal income
tax consequences and certain information reporting requirements. Under the PFIC rules, unless those shareholders make an election available
under the United States Internal Revenue Code of 1986 as amended (or the Code) (which election could itself have adverse consequences
for such shareholders), such shareholders would be liable to pay U.S. federal income tax at the then prevailing income tax rates on ordinary
income plus interest upon excess distributions and upon any gain from the disposition of their shares of our ordinary shares, as if the
excess distribution or gain had been recognized ratably over the shareholder’s holding period of the shares of our ordinary shares.
The
future development of national security laws and regulations in Hong Kong could impact our Hong Kong holding subsidiary.
On
May 28, 2020, the National People’s Congress of the People’s Republic of China approved a proposal to impose a new national
security law for Hong Kong and authorized the Standing Committee of the National People’s Congress to proceed to work out details
of the legislation to be implemented in Hong Kong (the “Decision”). While the details of the new law are still scarce as
of the date of this annual report, there is a risk that the Decision may trigger sanctions or other forms of penalties by foreign governments,
which may cause economic and other hardship for Hong Kong, including companies such as WJ Energy, our holding subsidiary which is incorporated
in Hong Kong. As the Decision is new and details of the new law remain unavailable as of the date of this prospectus, it is difficult
to predict the impact, if any, that the new law will have on WJ Energy (including, without limitation, the ability of WJ Energy to pay
dividends or make distributions to our company), as such impact will depend on future developments, which are highly uncertain and cannot
be predicted.
Risks
Related to Our Ordinary Shares and this Offering
Our
January 2022 convertible note and warrant financing with L1 Capital could cause substantial dilution and pressure on the public price
of our ordinary shares as repayments under such note can be paid in ordinary shares priced at a discount to market.
Beginning
May 2022, we are required to commence monthly installment payments of our convertible note held by L1 Capital through maturity (or 14
payments) (which we refer to as the Monthly Payments), which Monthly Payments may be made, at our election, in cash or ordinary shares
(or a combination of cash and ordinary shares), with such ordinary shares being issued at a valuation equal to the lesser of: (i) $6.00
per share or (ii) 90% of the average of the two lowest closing bid prices of the ordinary shares for the ten (10) consecutive trading
days ending on the trading day immediately prior to the payment date (the Market Price), with a floor price of $1.20 per share (which
floor price may be waived by us, but not L1 Capital, under certain circumstances). We shall not be permitted to make Monthly Payments
under the note in ordinary shares if certain equity conditions are not met.
If
we elect to Monthly Payments in ordinary shares, the value of such ordinary shares will be at discount to the then current market price
of the ordinary shares. As such, the number of ordinary shares used to repay the note could be substantial, and issuances of ordinary
shares to repay the note could therefore cause substantial dilution to our existing shareholders. Moreover, If the market price of the
ordinary shares decreases in the 10 days following a Monthly Payment made in ordinary shares, L1 Capital will be entitled to receive
an amount in additional ordinary shares or in cash based on a formula to account for the decrease in the share price, which would require
us to issue even more ordinary shares, thus causing additional dilution.
In
addition, any exercise by L1 Capital of the warrants that were issued to them in connection with this financing would cause additional
dilution.
Finally,
the ordinary shares we may use to repay the note and the ordinary shares underlying the L1 Capital warrants are registered for resale
pursuant to the registration statement of which this prospectus forms a part. As such, L1 Capital will have the ability to, in its discretion,
sell any such shares in the public market. Accordingly, there is a risk that such sales could cause pressure on the public price of our
ordinary shares and could force such price downwards, perhaps significant.
The
rights afforded to L1 Capital under our convertible note and warrant financing with them could discourage investment in our company
from third parties
Under
our January 2022 (as amended in March 2022) financing agreements with L1 Capital, L1 Capital has been afforded certain rights
which could discourage third parties from investing in our company based on the perceived preferred position and rights of L1 Capital.
These rights in include:
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the approval of L1 Capital, we are restricted from issuing new ordinary shares or ordinary
share equivalents until the date that is seven (7) trading days following the effectiveness
of the prospectus of which this registration statement forms a part (subject to certain exceptions); |
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indebtedness to L1 Capital is required to be until repaid the senior debt obligation of our
company; |
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January 21, 2023, L1 Capital shall have the right to participate in up to thirty percent
(30%) of our future financings undertaken during that period; |
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our indebtedness to L1 Capital is outstanding, if we issue any debt, including any subordinated
debt or convertible debt, then L1 Capital will have the option to cause us to immediately
utilize 30% of the aggregate proceeds of such issuance to repay the note to L1 Capital. In
addition, if we issue any equity interests for cash as part of a financing transaction (other
than in connection with an “at the market” funding program), then L1 Capital
will have the option to cause us to direct 30% of such proceeds from such issuance to repay
the L1 Capital note; |
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our indebtedness to L1 Capital is outstanding, we shall not (without the prior written consent
of L1 Capital): (i) enter into any financing transactions that qualify as “variable
rate transactions” until thirty (30) days after such time as the L1 Capital note has
been repaid in full and/or has been fully converted into ordinary shares or (ii) utilize
any “at the market” offering program in respect of our ordinary shares in the
thirty (30) day period following any date that we have made payments under the L1 Capital
note in the form of ordinary shares; and |
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our indebtedness to L1 Capital is outstanding, we shall not (without the prior written consent
of L1 Capital): (i) authorize the amendment of any outstanding note, option, warrant, or
other derivative security convertible, exercisable or exchangeable for ordinary shares to
reduce the conversion, exercise or exchange price of any such security or (ii) grant a replacement
note, option, warrant or other derivative security convertible, exercisable or exchangeable
for ordinary shares for the purpose of reducing the conversion, exercise or exchange price
of any such security being replaced; and |
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we enter into a definitive agreement with respect to a change of control of our company,
L1 Capital shall have the right to require our company to prepay the L1 Capital note with
a five percent (5%) payment premium. |
The
existence of this rights of L1 Capital, or the exercise of such rights, may deter potential investors
from providing us needed financing, or may deter investment banks from working with us, which would have a material adverse effect on
our ability to finance our company.
The
market for our ordinary shares has been volatile, and an
active, liquid and orderly trading market for our ordinary shares may not be maintained in the United States, which could limit your
ability to sell our ordinary shares.
The
market for our ordinary shares has been volatile, with times of significant trading volume and times of minimal trading
volume. Although our ordinary shares are listed
on the NYSE American, an active, liquid and orderly U.S. public market for our ordinary shares may not be achieved or sustained,
and the market for our ordinary shares may remain unpredictable. If an active, liquid and orderly market is not
sustained, you may experience difficulty selling your ordinary shares. Moreover, the price of our publicly-listed shares has been
subject to significant price fluctuations, which creates the risk of loss of your investment in our ordinary
shares.
Our
ordinary share price has been and may in the future be volatile and, as a result, you could lose a significant portion or all of your
investment.
The
market price of our ordinary shares on the NYSE American has fluctuated, and may in the future fluctuate (in each case to a significant
extent), as a result of several factors, including the following:
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fluctuations
in oil and other commodity prices (including as a result of external events such as the COVID-19 pandemic and Russia’s invasion
of Ukraine in February 2022); |
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volatility
in the energy industry, both in Indonesia and internationally; |
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variations
in our operating results; |
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risks
relating to our business and industry, including those discussed above; |
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strategic
actions by us or our competitors; |
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reputational
damage from accidents or other adverse events related to our company or its operations; |
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investor
perception of us, the energy sector in which we operate, the investment opportunity associated with the ordinary shares and our future
performance; |
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addition
or departure of our executive officers or directors; |
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changes
in financial estimates or publication of research reports by analysts regarding our ordinary shares, other comparable companies or
our industry generally; |
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trading
volume of our ordinary shares; |
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future
sales of our ordinary shares by us or our shareholders; |
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domestic
and international economic, legal and regulatory factors unrelated to our performance; or |
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the
release or expiration of lock-up or other transfer restrictions on our outstanding ordinary shares. |
Furthermore,
the stock markets often experience significant price and volume fluctuations that have affected and continue to affect the market prices
of equity securities of many companies. These fluctuations often have been unrelated or disproportionate to the operating performance
of those companies. These broad market and industry fluctuations, as well as general economic, political and market conditions such as
recessions or interest rate changes may cause the market price of ordinary shares to decline.
Our
auditor’s opinion on our December 31, 2020 financial statements include an explanatory paragraph in respect to there being substantial
doubt about our ability to continue as a going concern.
We
have experienced net losses of $6,951,698 and $1,673,735, and net cash used in operating activities of $5,186,048 and $439,794 for the
years ended December 31, 2020 and 2019, respectively. As of December 31, 2020, we had net current assets of $9,413,594, however, considering
our planned level of capital expenditures expected during the next twelve months, there will be an expected capital deficit to occur.
These conditions raise substantial doubt about our ability to continue as a going concern, and our auditor’s report on our December
31, 2020 financial statements includes an explanatory paragraph in respect to there being substantial doubt about our ability to continue
as a going concern. In addition, for the six months ended June 30, 2021, we experienced a net loss of $2,932,213 and net cash used
in operating activities of $1,635,829.
If additional financing is required
to alleviate our capital deficit (which additional financial is likely, notwithstanding our financing transaction with L1 Capital
in the first quarter of 2022), we cannot predict whether this additional financing will be in the form of equity, debt, or another
form, and we may not be able to obtain the necessary additional capital on a timely basis, on acceptable terms, or at all, from any source.
In addition, there may be limitations on the amount of capital we can raise as a result of SEC or similar rules and regulations.
In the event that financing sources are not available, or if we are unsuccessful in
increasing our gross profit margin and reducing operating losses, we may be unable to implement our current plans for expansion, repay
debt obligations or respond to competitive pressures, any of which would have a material adverse effect on the our business, prospects,
financial condition and results of operations. If we cannot continue as a viable entity, our shareholders may lose some or all of their
investment in our company.
We
may not be able to maintain the listing of our ordinary on the NYSE American, which could adversely affect our liquidity and the trading
volume and market price of our ordinary shares, and decrease the value of your investment.
Our
ordinary shares are currently traded on the NYSE American. In order to maintain our NYSE American listing, we must maintain certain share
price, financial and share distribution targets, including maintaining a minimum amount of shareholders’ equity and a minimum number
of public shareholders. In addition to these objective standards, the NYSE American may delist the securities of any issuer (i) if, in
its opinion, the issuer’s financial condition and/or operating results appear unsatisfactory; (ii) if it appears that the extent
of public distribution or the aggregate market value of the security has become so reduced as to make continued listing on the NYSE American
inadvisable; (iii) if the issuer sells or disposes of principal operating assets or ceases to be an operating company; (iv) if an issuer
fails to comply with the NYSE American’s listing requirements; (v) if an issuer’s securities sell at what the NYSE American
considers a “low selling price” and the issuer fails to correct this via a reverse split of shares after notification by
the NYSE American; or (vi) if any other event occurs or any condition exists which makes continued listing on the NYSE American, in its
opinion, inadvisable. If the NYSE American delists either our ordinary shares, investors may face material adverse consequences, including,
but not limited to, a lack of trading market for our securities, reduced liquidity, decreased analyst coverage of our securities, and
an inability for us to obtain additional financing to fund our operations.
We
require significant capital to realize our business plan.
Our
ongoing work program is expensive, and we will require significant additional capital in order to fully realize our business plan. This
is particularly true because we raised less funding than we had anticipated in our December 2019 initial public offering.
We
presently have only limited commitments for financing (i.e., our January 2022 financing transaction with L1 Capital),
and no assurance can be provided that we will be able to raise funds when needed. Further, we cannot assure you that our actual cash
requirements will not exceed our estimates. Even if we were to discover be successful in our exploration operations, we will require
additional financing to bring our interests into commercial operation and pay for operating expenses until we achieve a positive cash
flow. Additional capital also may be required in the event we incur any significant unanticipated expenses.
Under
the current capital and credit market conditions, we may not be able to obtain additional equity or debt financing on acceptable terms.
Even if financing is available, it may not be available on terms that are favorable to us or in sufficient amounts to satisfy our requirements.
If
we are unable to obtain additional financing, we may be unable to implement our business plan and our growth strategies, respond to changing
business or economic conditions and withstand adverse operating results. If we are unable to raise further financing when required, our
planned production and exploration activities may have to be scaled down or even ceased, and our ability to generate revenues in the
future would be negatively affected.
Additional
financing could cause your relative interest in our assets and potential earnings to be significantly diluted. Even if we have success,
we may not be able to generate sufficient revenues to offset the cost of our operational plans and administrative expenses.
An
entity controlled by our Chairman owns a substantial majority of our ordinary shares and voting power.
Maderic
Holding Limited, an entity controlled by our Chairman Wirawan Jusuf, owns and exercises voting and investment control of approximately
68.29% of our ordinary shares as of the date of this prospectus. In addition, HFO Investment Group, an entity controlled by the
adult sister of James J. Huang, our Chief Investment Officer, owns and exercises voting and investment control of approximately 8.74%
of our ordinary shares as of the date of this prospectus. As a result of this concentration of share ownership, investors may be prevented
from affecting matters involving our company, including:
|
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fluctuations
in oil and other commodity prices; |
|
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● |
volatility
in the energy industry, both in Indonesia and internationally; |
|
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variations
in our operating results; |
|
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risks
relating to our business and industry, including those discussed above; |
Furthermore,
this concentration of voting power could have the effect of delaying, deterring or preventing a change of control or other business combination
that might otherwise be beneficial to our shareholders. This significant concentration of share ownership may also adversely affect the
trading price for our ordinary shares because investors may perceive disadvantages in owning shares in a company that is controlled by
a company insider. This concentration of ownership could also create conflicts of interests for Dr. Jusuf that may not be resolved in
a manner that all shareholders agree with.
We
have identified a material weakness in our internal control over financial reporting for the year ended December 31, 2020. If we fail
to remediate this weakness or otherwise develop and maintain an effective system of internal control over financial reporting, we may
be unable to accurately report our financial results or prevent fraud.
We
have identified a “material weakness” and other control deficiencies including significant deficiencies in our internal control
over financial reporting for the year ended December 31, 2020. As defined in the standards established by the Public Company Accounting
Oversight Board of the United States, or PCAOB, a “material weakness” is a deficiency, or combination of deficiencies, in
internal control over financial reporting, such that there is a reasonable possibility that a material misstatement of the annual or
interim financial statements will not be prevented or detected on a timely basis.
In
connection with the audits of our consolidated financial statements for the years ended December 31, 2020 and 2019, the material weaknesses
that have been identified in our internal control over financial reporting as of such dates related to our lack of sufficient financial
reporting and accounting personnel with appropriate knowledge of U.S. GAAP and SEC reporting requirements to properly address complex
U.S. GAAP accounting issues and to prepare and review our consolidated financial statements and related disclosures to fulfill U.S. GAAP
and SEC financial reporting requirements. We have implemented are continuing to implement a number of measures to address the material
weakness identified. As the remedial measures had not been fully implemented in the limited time that elapsed since our initial public
offering in December 2019, our management concluded that one material weakness had not been remediated as of December 31, 2020. As a
result of the material weakness, our management has concluded that as of December 31, 2020, our disclosure controls and procedures were
ineffective in ensuring that the information required to be disclosed by us in our annual report is recorded, processed, summarized and
reported to them for assessment, and that the required disclosure is made within the time period specified in the rules and forms of
the SEC. We cannot assure you that we will be able to continue to implement an effective system of internal control, or that we will
not identify material weaknesses or significant deficiencies in the future.
Upon
completion of our initial offering, we became subject to the Sarbanes-Oxley Act of 2002. Section 404 of the Sarbanes-Oxley Act, or Section
404, requires that we include a report from management on the effectiveness of our internal control over financial reporting in our annual
reports on Form 20-F beginning with our Annual Report for the fiscal year ending December 31, 2020. In addition, once we cease to be
an “emerging growth company” as such term is defined under the JOBS Act, our independent registered public accounting firm
must attest to and report on the effectiveness of our internal control over financial reporting. Our management may conclude that our
internal control over financial reporting is not effective. Moreover, even if our management concludes that our internal control over
financial reporting is effective, our independent registered public accounting firm, after conducting its own independent testing, may
issue a report that it is not satisfied with our internal controls or the level at which our controls are documented, designed, operated
or reviewed. In addition, after we become a public company, our reporting obligations may place a significant strain on our management,
operational and financial resources and systems for the foreseeable future. We may be unable to timely complete our evaluation testing
and any required remediation.
During
the course of documenting and testing our internal control procedures, in order to satisfy the requirements of Section 404, we may identify
other weaknesses and deficiencies in our internal control over financial reporting. In addition, if we fail to maintain the adequacy
of our internal control over financial reporting, as these standards are modified, supplemented or amended from time to time, we may
not be able to conclude on an ongoing basis that we have effective internal control over financial reporting in accordance with Section
404. If we fail to achieve and maintain an effective internal control environment, we could suffer material misstatements in our financial
statements and fail to meet our reporting obligations, which would likely cause investors to lose confidence in our reported financial
information. This could in turn limit our access to capital markets, harm our results of operations, and lead to a decline in the trading
price of our ordinary shares. Additionally, ineffective internal control over financial reporting could expose us to increased risk of
fraud or misuse of corporate assets and subject us to potential delisting from the stock exchange on which we list, regulatory investigations
and civil or criminal sanctions. We may also be required to restate our financial statements from prior periods, which would further
damage our reputation and likely adversely impact our share price.
As
a foreign private issuer, we are subject to different U.S. securities laws and NYSE American governance standards than domestic U.S.
issuers. This may afford less protection to holders of our ordinary shares, and you may not receive corporate and company information
and disclosure that you are accustomed to receiving or in a manner in which you are accustomed to receiving it.
As
a “foreign private issuer” for U.S. securities laws purposes, the rules governing the information that we will be required
to disclose differ materially from those governing U.S. corporations pursuant to the Exchange Act. The periodic disclosure required of
foreign private issuers is more limited than that required of domestic U.S. issuers and there may therefore be less publicly available
information about us than is regularly published by or about U.S. public companies. For example, we are not required to file quarterly
reports on Form 10-Q or provide current reports on Form 8-K disclosing significant events within four days of their occurrence and our
quarterly (should we provide them) or current reports may contain less or different information than required under U.S. filings. In
addition, as a foreign private issuer, we are exempt from the proxy rules under Section 14 of the Exchange Act, and proxy statements
that we distribute are not subject to review by the SEC. Our exemption from Section 16 rules under the Exchange Act regarding sales of
ordinary shares by our insiders means that you will have less data in this regard than shareholders of U.S. companies that are subject
to the Exchange Act. As a result, you may not have all the data that you are accustomed to having when making investment decisions. Also,
our officers, directors and principal shareholders are exempt from the reporting and “short-swing” profit recovery provisions
of Section 16 of the Exchange Act and the rules thereunder with respect to their purchases and sales of our ordinary shares.
Moreover,
as a foreign private issuer, we are exempt from complying with certain corporate governance requirements of the NYSE American applicable
to a U.S. issuer, including the requirement that a majority of our board of directors consist of independent directors. For example,
we follow Cayman Islands law with respect to the requirements for meetings of our shareholders, which are different from the requirements
of the NYSE American. Additionally, in January 2022 in connection with our financing with L1 Capital, we formally adopted home country
practice and thereby opted out of the NYSE American rule that would otherwise require shareholder approval should we issue more than
19.99% of our then outstanding ordinary shares in a financing that is not a “public offering” at less than the then current
market value. As the corporate governance standards applicable to us are different than those applicable to domestic U.S. issuers, you
may not have the same protections afforded under U.S. law and the NYSE American rules as shareholders of companies that do not have such
exemptions.
Other
future issuances of additional ordinary shares could cause dilution of ownership interests and adversely affect our share price.
Beyond
our note financing with L1 Capital (the Selling Shareholder named herein), we may choose to raise additional capital due to market conditions
or strategic considerations even if we believe we have sufficient funds for our current or future operating plans. To the extent that
additional capital is raised through the sale of equity or convertible debt securities, the issuance of these securities could result
in further dilution to our stockholders or result in downward pressure on the price of our ordinary shares.
Shares
eligible for future, including as a result of our financing with L1 Capital, sale may depress our stock price.
As
of the date of this prospectus, we had 7,647,214 ordinary shares outstanding, 5,441,481 of which were held by our officers,
directors and affiliates. In addition, 200,000 ordinary shares are subject to outstanding options granted under certain
stock option agreements entered into with our management team. All of the ordinary shares held by affiliates (notably Maderic and
HFO) are restricted or control securities under Rule 144 promulgated under the Securities Act. Sales of these ordinary shares
under Rule 144 or another exemption under the Securities Act or pursuant to a registration statement could have a material adverse effect
on the price of the ordinary shares and could impair our ability to raise additional capital through the sale of equity securities.
Moreover,
under our convertible note financing with L1 Capital, L1 Capital has the right to convert principal under the Note at $6.00 per share,
which could be substantially lower than the prevailing market price of our ordinary shares. Further, we are required to make monthly
installment payments of the Note beginning in May 2022, and should we elect to make such payments in the form of ordinary shares, such
shares will be priced at (and the number of shares to be issued will be determined based upon) the lesser (i) $6.00 per share or (ii)
90% of the average of the two lowest closing bid prices of the ordinary shares for the ten (10) consecutive trading days ending on the
trading day immediately prior to the payment date, with a floor price of $1.20 per share (which floor price may be waived by us, but
not L1 Capital, under certain circumstances). Any payments of the Note in ordinary shares could therefore require us to issue L1 Capital
a significant number of ordinary shares, which could be sold into the market, which could have a material adverse effect on the price
of the ordinary shares and could impair our ability to raise additional capital through the sale of equity securities. L1
Capital holds the Warrants, which are currently exercisable at $6.00 per share. Upon exercise of the Warrants, sales of the underlying
ordinary shares could also have a material adverse effect on the price of the ordinary shares.
We
may issue preferred shares with greater rights than our ordinary shares.
Our
amended articles of association authorize our board of directors to issue one or more series of preferred shares and set the terms of
the preferred shares without seeking any further approval from our shareholders. Any preferred shares that are issued may rank ahead
of our ordinary shares, in terms of dividends, liquidation rights and voting rights.
If
securities or industry analysts do not publish or cease publishing research reports about us, if they adversely change their recommendations
regarding our ordinary shares or if our operating results do not meet their expectations, the price of our ordinary shares could decline.
The
trading market for our ordinary shares will be influenced by the research and reports that industry or securities analysts may publish
about us, our business, our market or our competitors. Securities and industry analysts currently publish limited research on us. If
there is limited or no securities or industry analyst coverage of our company, the market price and trading volume of our ordinary shares
would likely be negatively impacted. Moreover, if any of the analysts who may cover us downgrade our ordinary shares, provide more favorable
relative recommendations about our competitors or if our operating results or prospects do not meet their expectations, the market price
of our ordinary shares could decline. If any of the analysts who may cover us were to cease coverage or fail to regularly publish reports
on us, we could lose visibility in the financial markets, which in turn could cause our share price or trading volume to decline.
As
an “emerging growth company” under the JOBS Act, we are allowed to postpone the date by which we must comply with some of
the laws and regulations intended to protect investors and to reduce the amount of information we provide in our reports filed with the
SEC, which could undermine investor confidence in our company and adversely affect the market price of our ordinary shares.
For
so long as we remain an “emerging growth company” as defined in the JOBS Act, we intend to take advantage of certain exemptions
from various requirements that are applicable to public companies that are not “emerging growth companies” including:
|
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not
being required to comply with the auditor attestation requirements for the assessment of our internal control over financial reporting
provided by Section 404 of the Sarbanes-Oxley Act of 2002; |
|
|
|
|
● |
not
being required to comply with any requirements adopted by the Public Company Accounting Oversight Board requiring mandatory audit
firm rotation or a supplement to the auditor’s report in which the auditor would be required to provide additional information
about the audit and our financial statements; |
|
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reduced
disclosure obligations regarding executive compensation; and |
|
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not
being required to hold a nonbinding advisory vote on executive compensation or seek shareholder approval of any golden parachute
payments not previously approved. |
We
intend to take advantage of these exemptions until we are no longer an “emerging growth company.” We will remain an emerging
growth company until the earlier of: (1) the last day of the fiscal year (a) following the fifth anniversary of the completion of our
initial public offering, (b) in which we have total annual gross revenue of at least $1.07 billion, or (c) in which we are deemed to
be a large accelerated filer, which means the market value of our ordinary shares that is held by non-affiliates exceeds $700 million
as of the prior June 30, and (2) the date on which we have issued more than $1 billion in non-convertible debt during the prior three-year
period.
Because
the likelihood of paying cash dividends on our ordinary shares is remote at this time, investors must look solely to appreciation of
our ordinary shares in the market to realize a gain on their investments.
We
do not know when or if we will pay dividends. We currently intend to retain future earnings, if any, to finance the expansion of our
business. Our future dividend policy is within the discretion of our board of directors and will depend upon various factors, including
our business, financial condition, results of operations, capital requirements and investment opportunities. Accordingly, investors must
look solely to appreciation of our ordinary shares in the market to realize a gain on their investment. This appreciation may not occur.
CAUTIONARY
NOTE REGARDING FORWARD-LOOKING STATEMENTS
This
prospectus contains forward-looking statements that reflect our current expectations and views of future events. The forward looking
statements are contained principally in the sections entitled “Prospectus Summary,” “Risk Factors,” “Management’s
Discussion and Analysis of Financial Condition and Results of Operations” and “Business.” Known and unknown risks,
uncertainties and other factors, including those listed under “Risk Factors,” may cause our actual results, performance or
achievements to be materially different from those expressed or implied by the forward-looking statements.
You
can identify some of these forward-looking statements by words or phrases such as “may,” “will,” “expect,”
“anticipate,” “aim,” “estimate,” “intend,” “plan,” “believe,”
“is/are likely to,” “potential,” “continue” or other similar expressions. We have based these forward-looking
statements largely on our current expectations and projections about future events that we believe may affect our financial condition,
results of operations, business strategy and financial needs. These forward-looking statements include statements relating to:
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our
overall ability to meet our goals and strategies, including our plans to drill additional wells at Kruh Block, to develop Citarum
Block or acquire rights in additional oil and gas assets in the future; |
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the
economic, capital markets and social impact of the worldwide novel coronavirus (COVID-19) pandemic on the demand for our oil and
gas products in Indonesia and the price of our oil and gas products; |
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● |
our
ability to estimate our oil reserves; |
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|
|
● |
our
ability to anticipate our financial condition and results of operations; |
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the
anticipated prices for oil and gas products, the volatility in oil and gas prices, and the growth of the oil and gas market in Indonesia
and worldwide; |
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our
expectations regarding our relationships with the Government and its oil and gas regulatory agencies; |
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relevant
Government policies and regulations relating to our industry; and |
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our
corporate structure and related laws, rules and regulations. |
These
forward-looking statements involve various risks and uncertainties. Although we believe that our expectations expressed in these forward-looking
statements are reasonable, our expectations may later be found to be incorrect. Our actual results of operations or the results of other
matters that we anticipate herein could be materially different from our expectations. Important risks and factors that could cause our
actual results to be materially different from our expectations are generally set forth in “Risk Factors,” “Management’s
Discussion and Analysis of Financial Condition and Results of Operations,” “Business,” “Regulation” and
other sections in this prospectus. You should thoroughly read this prospectus and the documents that we refer to with the understanding
that our actual future results may be materially different from and worse than what we expect. We qualify all of our forward-looking
statements by these cautionary statements.
The
forward-looking statements made in this prospectus relate only to events or information as of the date on which the statements are made
in this prospectus. Except as required by law, we undertake no obligation to update or revise publicly any forward-looking statements,
whether as a result of new information, future events or otherwise, after the date on which the statements are made or to reflect the
occurrence of unanticipated events. You should read this prospectus and the documents that we refer to in this prospectus and have filed
as exhibits to the registration statement, of which this prospectus is a part, completely and with the understanding that our actual
future results may be materially different from what we expect.
USE
OF PROCEEDS
We
are not selling any securities under this prospectus and will not receive any proceeds from the sale of the ordinary shares offered by
this prospectus by the Selling Shareholder. However, we may receive proceeds from the cash exercise of the Warrants, which, if exercised
in cash at the current exercise price with respect to all Warrants, would result in gross proceeds to us of approximately $4,603,440.
The proceeds from such Warrant exercises, if any, will be used for working capital and general corporate purposes. We cannot predict
when or whether the Warrants will be exercised, and it is possible that some or all of the Warrants may expire unexercised. For information
about the Selling Stockholder, see “Selling Shareholder.”
The
Selling Shareholder will pay any underwriting discounts and commissions and expenses incurred by the Selling Shareholder for brokerage
or legal services or any other expenses incurred by the Selling Shareholder in disposing of the ordinary shares offered hereby. We will
bear all other costs, fees and expenses incurred in effecting the registration of the ordinary shares covered by this prospectus, including
all registration and filing fees and fees and expenses of our counsel and accountants.
CAPITALIZATION
The
following table sets for our capitalization as of June 30, 2021 and December 31, 2020:
| |
As of
June 30, 2021 | |
As of December 31, 2020 |
| |
(in US$ thousands) |
Debt: | |
| |
|
Unsecured long-term debt, net of deferred finance costs | |
| 1,000 | | |
| 1,000 | |
Short term bank loan | |
| 980 | | |
| 980 | |
Total debt | |
| 1,980 | | |
| 1,980 | |
| |
| | | |
| | |
Equity: | |
| | | |
| | |
Ordinary shares, US$0.00267 par value, 37,500,000 shares authorized, 7,442,955 and 7,427,955 ordinary shares outstanding as of June 30, 2021 and December 31, 2020, respectively | |
| 20 | | |
| 20 | |
Additional paid-in capital | |
| 40,999 | | |
| 40,073 | |
Accumulated deficit | |
| (30,667 | ) | |
| (27,735 | ) |
Accumulated other comprehensive income | |
| — | | |
| — | |
Total equity | |
| 10,352 | | |
| 12,358 | |
| |
| | | |
| | |
Total capitalization | |
| 12,332 | | |
| 14,338 | |
ENFORCEABILITY
OF CIVIL LIABILITIES
We
were incorporated under the laws of the Cayman Islands in order to enjoy the following benefits:
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political
and economic stability; |
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an
effective judicial system; |
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a
favorable tax system; |
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the
absence of exchange control or currency restrictions; and |
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the
availability of professional and support services. |
However,
the Cayman Islands has a less developed body of securities laws as compared to the United States and these securities laws provide significantly
less protection to investors.
Our
constitutional documents do not contain provisions requiring that disputes, including those arising under the securities laws of the
United States, between us, our officers, directors and shareholders, be arbitrated. Currently, substantially all of our operations are
conducted outside the United States, and substantially all of our assets are located outside the United States. All of our officers are
nationals or residents of jurisdictions other than the United States and a substantial portion of their assets are located outside the
United States. As a result, it may be difficult for a shareholder to effect service of process within the United States upon these persons,
or to enforce against us or them judgments obtained in United States courts, including judgments predicated upon the civil liability
provisions of the securities laws of the United States or any state in the United States.
Ogier,
our counsel as to the laws of the Cayman Islands, and Adnan Kelana Haryanto & Hermanto, our counsel as to Indonesian law, have advised
us, respectively, that there is uncertainty as to whether the courts of the Cayman Islands and Indonesia, respectively, would:
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recognize
or enforce judgments of United States courts obtained against us or our directors or officers predicated upon the civil liability
provisions of the securities laws of the United States or any state in the United States; or |
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entertain
original actions brought in the Cayman Islands or Indonesia against us or our directors or officers predicated upon the securities
laws of the United States or any state in the United States. |
MANAGEMENT’S
DISCUSSION AND ANALYSIS OF
FINANCIAL CONDITION AND RESULTS OF OPERATIONS
Introduction
The
following discussion and analysis of our financial condition and results of operations should be read in conjunction with the consolidated
financial statements and related notes appearing elsewhere in this prospectus. The following discussion contains “forward-looking
statements” that reflect our future plans, estimates, beliefs and expected performance. We caution you that assumptions, expectations,
projections, intentions or beliefs about future events may, and often do, vary from actual results and the differences can be material.
Please
refer to the sections of this prospectus captioned “Risk Factors” and “Cautionary Note Regarding Forward Looking Statements”
for important information to be read in conjunction with the below discussion.
As
described elsewhere in this prospectus, all share amounts and per share amounts set forth below have been presented on a retroactive
basis to reflect a reverse stock split by way of share consolidation of our outstanding ordinary shares at a ratio of one-for-zero point
three seven five (1 for 0.375) shares which was implemented on November 8, 2019.
We have omitted a discussion
of our results of operations for the year ended December 31, 2018 in reliance on Item 5, Instruction 6 of Form 20-F. Such discussion
can be found in our Annual Report on Form 20-F for the year ended December 31, 2020 filed with the SEC on May 18, 2021.
Business
Overview
We
are an oil and gas exploration and production company focused on the Indonesian market. Alongside operational excellence, we believe
we have set the highest standards for ethics, safety and corporate social responsibility practices to ensure that we add value to society.
Led by a professional management team with extensive oil and gas experience, we seek to bring forth at all times the best of our expertise
to ensure the sustainable development of a profitable and integrated energy exploration and production business model.
We
produce oil through our subsidiary GWN, which is a party that we acquired in 2014 and operates the Kruh Block, under a Technical Assistance
Contract (or TAC) with PT Pertamina (Persero) (or Pertamina) until May 2020. GWN shall continue the operatorship of the block from May
2020 until May 2030 under a Joint Operation Partnership (or KSO) with Pertamina. Kruh Block covers an area of 258 km2 (63,753
acres) and is located onshore 16 miles northwest of Pendopo, Pali, South Sumatra. The TAC contract is based on a “cost recovery”
system, in which all operating costs (expenditures made and obligations incurred in the exploration, development, extraction, production,
transportation, marketing, abandonment and site restoration) are advanced by GWN upon occurrence and later reimbursed to GWN by Pertamina
based on certain agreed conditions, which are described elsewhere in this prospectus captioned “Business—Our Assets”.
Our
reserves estimate of 3 fields (Kruh, North Kruh and West Kruh) within the Kruh TAC block was based on two major sources: (i) an integrated
study of geology, geophysics and reservoir including reserve evaluation of Kruh, North Kruh and West Kruh fields by LEMIGAS (a Government
oil and gas research and development center responsible for exploration and production technology development and assessment of oil and
gas fields) in 2005, and (ii) additional reservoir and production data since 2005, particularly from the addition of 3 new wells since
2013.
The
content and reserves in the LEMIGAS report (2005) was approved by Pertamina. The methods used in updating the proved, probable and possible
reserves of LEMIGAS report with additional reservoir and production data was based on guidelines from the SPE-PRMS (Society of Petroleum
Engineers-Petroleum Resources Management System) and SEC guidelines.
Our
proved oil reserves have not been estimated or reviewed by independent petroleum engineers. The estimate of the proved reserves for the
Kruh Block was prepared by representatives of our company, a team consisting of engineering, geological and geophysical staff based on
the definitions and disclosure guidelines of the United States Securities and Exchange Commission (or SEC) contained in Title 17, Code
of Federal Regulations, Modernization of Oil and Gas Reporting, Final Rule released January 14, 2009 in the Federal Register.
Our
estimates of the proven reserves are made using available geological and reservoir data as well as production performance data. These
estimates are reviewed annually by internal reservoir engineers, and Pertamina, and revised as warranted by additional data. Revisions
are due to changes in, among other things, development plans, reservoir performance, TAC effective period and governmental restrictions.
Kruh
Block’s general manager, Mr. Denny Radjawane, and our Chief Operating Officer, Mr. Charlie Wu, have reviewed the reserves estimate
to ensure compliance to SEC guidelines for (1) the appropriateness of the methodologies employed; (2) the adequacy and quality of the
data relied upon; (3) the depth and thoroughness of the reserves estimation process; (4) the classification of reserves appropriate to
the relevant definitions used; and (5) the reasonableness of the estimated reserve quantities. The estimate of reserves was also reviewed
by our Chief Business Development Officer and our Chief Executive Officer.
The
table below shows the individual qualifications of our internal team that prepares the reserves estimation:
| |
| |
| |
Total | | |
| |
Reserve | |
University | |
| |
professional | | |
Field of professional experience (years) | |
Estimation Team* | |
degree major | |
Degree level | |
| experience (years) | | |
| Drilling & Production | | |
| Petroleum Engineering | | |
| Production Geology | | |
| Reserve Estimation | |
Charlie Wu | |
Geosciences | |
Ph.D. | |
| 44 | | |
| 12 | | |
| | | |
| 32 | | |
| 23 | |
| |
| |
| |
| | | |
| | | |
| | | |
| | | |
| | |
Denny Radjawane | |
Geophysics | |
M.S. | |
| 31 | | |
| 12 | | |
| | | |
| 19 | | |
| 15 | |
Fransiska Sitinjak | |
Petroleum Engineering | |
M.S. | |
| 18 | | |
| 5 | | |
| 13 | | |
| | | |
| 9 | |
Yudhi Setiawan | |
Geology | |
B.S. | |
| 19 | | |
| 13 | | |
| 2 | | |
| 4 | | |
| 2 | |
Oni Syahrial | |
Geology | |
B.S. | |
| 15 | | |
| 1 | | |
| | | |
| 14 | | |
| 9 | |
Juan Chandra | |
Geology | |
B.S. | |
| 16 | | |
| 1 | | |
| | | |
| 15 | | |
| 10 | |
The
individuals from the reserves estimation team are members of at least one of the following professional associations: American Association
of Petroleum Geologists (AAPG), Indonesian Association of Geophysicist (HAGI), Indonesian Association of Geologists (IAGI), Society of
Petroleum Engineers (SPE), Society of Indonesian Petroleum Engineers (IATMI) and Indonesian Petroleum Association (IPA).
We
acquired Citarum Block, which is also described in the section of this prospectus captioned “Business—Our Assets”.
Citarum Block is an exploration block covering an area of 3,924.67 km2 (969,807 acres). This block is located onshore in West Java and
only 16 miles south of the capital city of Indonesia, Jakarta.
Our
Citarum PSC contract, valid until July, 2048, is based on the “gross split” regime, in which the production of oil and gas
is to be divided between the contractor and the Indonesian Government based on certain percentages in respect of (a) the crude oil production
and (b) the natural gas production. Our share will be the Base Split share plus a Variable and Progressive component. Our Crude Oil Base
Split share is 43% and our Natural Gas Base Split share is 48%. Our share percentage is determined based on both variable (such as carbon
dioxide and hydrogen sulfide content) and progressive (such as crude oil and refined gas prices) components.
Thus,
pursuant to our Citarum PSC contract, once Citarum commences production, we are entitled to at least 65% of the natural gas produced,
calculated as 48% from the Base Split plus a Variable Component of 5% from the first Plan of Development (POD I) in Citarum, a Variable
Component of 2% from the use of Local Content, as the oil and gas onshore services are mostly closed or restricted for foreign companies
(as described below under “—Legal Framework for the Oil and Gas Industry in Indonesia), and a 10% increase for the first
180 BSCF produced or 30 million barrels of oil equivalent which according to our economic model, the cumulative production of 180 BSCF
will only be achieved in 2025, if our exploration efforts succeed.
In
mid-2018, we identified an onshore open area in the province of West Java, adjacent to our Citarum block. We believe that this area,
also known as the Rangkas Area, holds large amounts of crude oil due to its proven petroleum system. To confirm the potential of Rangkas
Area, in July 2018, we formally expressed our interest to the DGOG of MEMR to conduct a Joint Study in the Rangkas Area and we attained
the approval to initiate our Joint Study program in this area on November 5, 2018. The Rangkas Joint Study covered an area of 3,970 km2
(or 981,008 acres) and was completed in November 2019. The DGOG accepted completion of the joint study and inquired IEC’s interest
for further process to tender the block. The study result suggested an effective petroleum system for oil and gas accumulations. Furthermore
with the opportunity to integrate the operation of Citarum and Rangkas together efficiently, we decided to issue a Statement of Interest
Letter in December 2019 to the Ministry of Energy (DGOG) as we intend to enter into a PSC contract for the Rangkas through a direct tender
process. We will have the right to change our offer in order to match the best offer following the results of the bidding process which
has not taken place as of the date of this prospectus. The timeline for the tender is contingent upon the DGOG’s plans and schedule.
We
currently generate revenue from Kruh Block and profit sharing from the sale of the crude oil under our new 10-year Joint Operation Partnership
(or KSO) that commenced in May 2020 by Pertamina. Prior to May 2020, Kruh Block was operated under a TAC agreement. Under our KSO, we
have the operatorship to, but not the ownership of, the extraction and production of oil from the designated oil deposit location in
Indonesia until May 2030. During the operations, our company pays all expenditures and obligations incurred including but not limited
to exploration, development, extraction, production, transportation, abandonment and site restoration. Under the TAC, revenue is recognized
based on the prevailing ICP through GWN from the 65% (sixty-five percent) of monthly proceeds as monthly cost recovery entitlement plus
26.7857% (twenty six point seven eight five seven percent) of the remaining proceeds from the sale of the crude oil after monthly cost
recovery entitlement as part of the profit sharing. For the KSO, with an 80% cap on the proceeds of such sale as part of the cost recovery
scheme, on a monthly basis, calculated by multiplying the quantity of crude oil produced by our company and the prevailing ICP published
by the Government of Indonesia plus 80% of the operating cost per bbl multiplying Non-Shareable Oil (“NSO”). In addition,
we are also entitled to an additional 23.5294% (twenty-three point five two nine four percent) of the remaining 20% of such sales proceeds
as part of the profit sharing. The main differences between the two contracts are that: (1) in the TAC, all oil produced is shareable
between Pertamina and its contractor, while in the KSO, a NSO production is determined and agreed between Pertamina and its partners
so that the baseline production, with an established decline rate, belongs entirely to Pertamina, so that the partners’ revenue
and production sharing portion shall be determined only from the production above the NSO baseline; (2) in the TAC, the cost recovery
was capped at 65% (sixty-five percent) of the proceeds from the sale of the oil produced in the block, while in the KSO, the cost recovery
is capped at 80% of the proceeds from the sale of the oil produced within Kruh Block for the cost incurred during the term under the
KSO plus 80% of the operating cost per bbl multiplying NSO. Any remaining cost recovery balance from the KSO period of contract is carried
over to the next period, although the cost recovery balance from the TAC contract will not be carried over to the KSO, meaning that the
cost recovery balance were reset to nil with the commencement of the operatorship under the KSO in May 2020.
Our
revenue and potential for profit depend mostly on the level of oil production in Kruh Block and the ICP that is correlated to international
crude oil prices. Therefore, the biggest factor affecting our financial results in 2020 and 2019 was the volatility in the price of crude
oil. For the year ended December 31, 2020, ICP decreased to an average of $37.58 per Bbl., 39.28% lower when compared to the ICP average
of $61.89 per Bbl. for the year ended December 31, 2019, which affected our company’s financial performance in 2019. For the year
ended December 31, 2021, ICP increased to an average of $67.02 per Bbl., 78% higher when compared to the ICP average of $37.58 per Bbl.,
for the year ended December 31, 2020, which would affect our company’s financial performance. The ICP continued generally to
increase during 2021 and into 2022.
We
commenced new drilling operations in Kruh Block in March 2021. Our originally anticipated drilling commencement date was delayed due
to COVID-19 and the Government permitting process. The first new well was spudded in April 2021 and drilling of the second
well commenced in August 2021. We are drilling of additional wells in the first half of 2022.
Selected
Key Financial Results For the Periods Presented
Overview
For
the six months ended June 30, 2021
|
● |
Total
oil production by IEC for the six months ended June 30, 2021 was 30,140 Bbl, a decline of 6,469 Bbl for the
same period in 2020, which resulted in lower cost recovery entitlements for the six months ended June 30, 2021 than for the same
period in 2020. This decrease was due to the decrease of the reservoir pressure which comes naturally in the primary production phase
for our four existing wells at Kruh Block. |
|
|
|
|
● |
The
Indonesian Crude Price (“ICP”) increased approximately 62% from an average price of $37.41 per Bbl for the six months
ended June 30, 2020 to $60.48 per Bbl for the same period in 2021, increasing our revenues and cost recovery entitlements. |
|
|
|
|
● |
The
average production cost per Bbl for the six months ended June 30, 2021 was $47.37 compared to $36.80 for same period in 2020. The
higher production cost per Bbl in 2021 was due to the decrease in production, the effect of certain fixed costs attributable to
our wells, and an increase of COVID-19-related costs. |
|
|
|
|
● |
Kruh
Block: with respect to our currently producing Kruh Block, our KSO contract commenced in May 2020 for a period ending in May
2030, and we received government approval on our drilling and seismic program for Kruh Block. During and subsequent to the six months
ended June 30, 2021, we commenced, and in two cases, completed, drilling of three new wells at Kruh Block. |
|
|
|
|
● |
Citarum
Block: with respect to Citarum Block, we are currently designing the 2D seismic program, and we plan to start conducting such
program during 2022. |
For
the years ended December 31, 2020 and 2019
Financial
and operating results for the year ended December 31, 2020 compared to the year ended December 31, 2019 are as follows:
|
● |
Total
oil production decreased approximately 20.29%, from 90,989 Bbl. for the year ended December 31, 2019 to 72,524 Bbl. for the same
period in 2020, which resulted in lower revenue and cost recovery entitlements for the year ended December 31, 2020 than for the
same period in 2019. This decrease was due to the decrease of the reservoir pressure which comes naturally in the primary recovery
production phase for our four existing wells. |
|
|
|
|
● |
ICP
decreased 39.28% from an average price of $61.89 per Bbl. for the year ended December 31, 2019 to $37.58 per Bbl. for the same period
in 2020, reducing our revenue and cost recovery entitlements. The ICP, which correlates to the international crude oil price, is
determined by MEMR. Throughout 2020, increases in U.S. petroleum production put downward pressure on crude oil prices. In addition,
the production increases likely limited the effect on prices from the attack on key energy installations in Saudi Arabia on September
16, 2019, production cut announcements from the Organization of the Petroleum Exporting Countries (OPEC), and U.S. sanctions on Iran
and Venezuela that limited crude oil exports from those countries. This production increase accompanied by weaker demand growth,
have led to a large build up in stocks caused the decrease of crude oil price. |
|
|
|
|
● |
Revenue
decreased by $2,202,581, or 52.65%, from $4,183,354 for the year ended December 31, 2019 to $1,980,773 for the same period in 2020
due to a combination of lower ICP and lower production. |
|
|
|
|
● |
General
and administrative expenses increased by $4,099,543 or 168.42%, for the year ended December 31, 2020 when compared to the same period
in 2019. Major expenses for the years ended December 31, 2020 were employee salary (including share-based compensation expense),
professional fees, director and officer insurance expense, and travel expenses. |
|
|
|
|
● |
The
amount of lease operating expenses decreased by approximately $456,374 or 18.45%, for the year ended December 31, 2020 when compared
to the same period in 2019 mainly because of the decline in production in Kruh Block. |
|
|
|
|
● |
We
incurred net loss of $6,951,698 for the year ended December 31, 2020 from a net loss of $1,673,735 for the same period in 2019 due
to a combination of the factors stated above. |
|
|
|
|
● |
The
average production cost per barrel of oil for the year ended December 31, 2020 was $27.82 compared to $21.34 for the year ended December
31, 2019, computed using production costs disclosed pursuant to FASB ASC Topic 932 and only to exclude ad valorem and severance taxes,
an increase of 30% due to a combination of the factors discussed above. |
Trends
Affecting Future Operations
The
factors that will most significantly affect results of operations will be (i) the selling prices of crude oil and natural gas (which
prices have fluctuated significantly in recent years), and (ii) the amount of production from oil or gas wells in which we have an
interest. Our revenues will also be significantly impacted by its ability to maintain or increase oil or gas production through exploration
and development activities.
It
is expected that the principal source of cash flow will be from the production and sale of crude oil and natural gas capitalized property
which are depleting assets. Cash flow from the sale of oil and gas production depends upon the quantity of production and the price obtained
for the production. An increase in prices will permit us to finance operations to a greater extent with internally generated funds and
may allow us to obtain equity financing more easily or on better terms, and lessens the difficulty of obtaining financing. However, price
increases heighten the competition for oil and gas prospects, increase the costs of exploration and development, and, because of potential
price declines, increase the risks associated with the purchase of producing properties during times that prices are at higher levels.
A
decline in oil and gas prices (including as was experienced in the first quarter of 2020) (i) will reduce our internally generated cash
flow, which in turn will reduce the funds available for exploring for and replacing oil and gas capitalized property, (ii) will increase
the difficulty of obtaining equity and debt financing and worsen the terms on which such financing may be obtained, (iii) will reduce
the number of oil and gas prospects which have reasonable economic terms, (iv) may cause us to permit leases to expire based upon the
value of potential oil and gas capitalized property in relation to the costs of exploration, (v) may result in marginally productive
oil and gas wells being abandoned as non-commercial, and (vi) may increase the difficulty of obtaining financing. However, price declines
reduce the competition for oil and gas properties and correspondingly reduce the prices paid for leases and prospects.
The
global outbreak and pandemic of the novel coronavirus (COVID-19) in 2020, including in Indonesia, has and may continue to impact our
operations, which might affect our total oil production. Since the outbreak, crude oil prices have been negatively impacted to a significant
extent due to low oil demand, increased production and disputes between the Organization of the Petroleum Exporting Countries (or OPEC)
and Russia on production cuts. As a consequence, our revenue and profit is expected to decrease due to the factors discussed above, and
other unforeseen and unpredictable consequences of the COVID-19 outbreak.
Further,
in the first half of 2020 there was a sharp decline in commodity prices following the announcement of price reductions and production
increases in March 2020 by members of OPEC, which has led to significant global economic contraction generally and in the oil and gas
exploration industry in particular. Together with the COVID-19 pandemic, it is unclear and not predictable what the long lasting
effects will be on global energy prices and our results of operations and financial condition. Please see the Risk Factor entitled
“The outbreak of COVID-19 and volatility in the energy markets may materially and adversely affect our business, financial condition,
operating results, cash flow, liquidity and prospects.” More recently, however, there has been a sharp increase in commodity
prices including for, among other reasons, Russia’s invasion of Ukraine in February 2022. It is unclear and not predictable whether
this condition will continue. Please see the risk factor entitled “Oil and gas price volatility has and may continue to adversely
affect our results of operations and financial condition.”
We
commenced new drilling operations in Kruh Block in March 2021. Our originally anticipated drilling commencement date was delayed due
to COVID-19 and the Government permitting process. The first new well was spudded in April 2021 and drilling of the second well
commenced in August 2021. The reserve estimate will be updated in mid-2022 after the drilling of two more wells in the first half of
2022.
Other
than the foregoing, the management is unaware of any other trends, events or uncertainties that will have, or are reasonably expected
to have, a material impact on sales, revenues or expenses.
Results
of Operations
The
table below sets forth certain line items from our Consolidated Statement of Operations for the years ended December 31, 2020 and
2019:
| |
For The Years Ended |
| |
December 31, | | |
December 31, | |
| |
2020 | | |
2019 | |
Revenue | |
$ | 1,980,773 | | |
$ | 4,183,354 | |
Lease operating expenses | |
| 2,017,856 | | |
| 2,474,230 | |
Depreciation, depletion and amortization | |
| 698,851 | | |
| 876,676 | |
General and administrative expenses | |
| 6,533,642 | | |
| 2,434,099 | |
Exchange gain (loss) | |
| 132,033 | | |
| (51,584 | ) |
Other income (expenses), net | |
| 185,845 | | |
| (20,500 | ) |
(Loss) income before income tax | |
| (6,951,698 | ) | |
| (1,673,735 | ) |
Income tax provision | |
| - | | |
| - | |
Net (loss) income | |
$ | (6,951,698 | ) | |
$ | (1,673,735 | ) |
Six
Months Ended June 30, 2021 and 2020
Revenue
Revenues
increased $35,440, or approximately 3%, to $1.06 million for the six months ended June 30, 2021 when compared with the same period in
2020. Despite the reduction in total oil production, the increase was due to an increase in the ICP.
Lease
operating expenses
Lease
operating expenses increased by $85,620, or 8%, for the six months ended June 30, 2021 compared to the same period in 2020 mainly because
of an increase in health, safety, security and environmental (“HSSE”) expenses and costs associated with the COVID-19 pandemic
in 2021. Furthermore, as the productions of the existing wells at Kruh Block have moved into a more stable level, less incidental or
unexpected maintenance has been required, which also contributed to the stability in lease operating expenses.
Depreciation,
depletion and amortization (DD&A)
DD&A
decreased by $4,812, or 2%, for the six months ended June 30, 2021 compared to the same period in 2020 due to the reduced depletion amount
charged to expense from the reduced production for the six months ended June 30, 2021.
General
and Administrative Expenses
General
and administrative expenses decreased by $950,356 to $2,562,531 for the six months ended June 30, 2021 when compared to the same period
in 2020 due to decrease in amortization of share-based compensation, which accounted for approximately $900,000 of the
total reduction.
Exchange
(loss) gain
We
had an exchange loss of $33,462 for the six months ended June 30, 2021, a decrease of $132,903 when compared to exchange gain of $99,441
for the same period ended in 2020.
Other
income, net
We
had other income of $34,479 for the six months ended June 30, 2021 as compared with $175,639 for the same period in 2020, the other income
for the six months ended June 30, 2021 was mainly due to the income from a short term deposit, while we had income from a write off of
a long-aged payable in the same period in 2020.
Net
Loss
We
had net loss for the six months ended June 30, 2021 in the amount of $2,932,213 compared to $3,563,138 for the same period in 2020. The
reduction in net loss was mainly as a result of an increase in revenue and a decrease in general and administrative expenses.
Year
ended December 31, 2020 compared with year ended December 31, 2019
Revenue
Total
revenue for the year ended December 31, 2020 were $1,980,773 compared to $4,183,354 for the year ended December 31, 2019, a decrease
of $2,202,581 due to decrease in production and ICP.
Lease
operating expenses
Lease
operating expenses decreased by $456,374, or 18.45%, for the year ended December 31, 2020 compared to the same period in 2019 mainly
because of the decline in production in Kruh Block.
Depreciation,
depletion and amortization (DD&A)
The
amount of DD&A decreased by $177,825, or 20.28%, for the year ended December 31, 2020 compared to the same period in 2019 due to
(i) a decline in depletion expense of $162,790 from the reduced production and (ii) the reduced depreciation of $15,035 coming naturally
from the declining balance method.
General
and Administrative Expenses
General
and administrative expenses increased by $4,099,543, or 168.42%, for the year ended December 31, 2020 when compared to the same period
in 2019 due to an increase of employee salary and share-based compensation, professional fees, D&O insurance expense, and travel
expenses.
Exchange
gain
We
had exchange gain of $132,033 for the year ended December 31, 2020, as compared to exchange loss of $51,584 for the same periods ended
in 2019. The change was primarily due to the fluctuation of the exchange rate.
Other
income (expenses), net
There
was other income, net for the year ended December 31, 2020 when compared to net other expenses in the same period in 2019 due to the
income from the write-off of account payable and realized actuarial gain, partially offset by the record of non-recoverable expense related
to Kruh Block’s operations in the year ended December 31, 2020.
Net
Loss
We
had net loss for the year ended December 31, 2020 in the amount of $6,951,698 compared to $1,673,735 for the same periods in 2019, which
was due to the combination of the above factors discussed.
Critical
Accounting Policies
We
prepare our consolidated financial statements in conformity with U.S. GAAP, which requires us to make judgments, estimates and assumptions.
We continually evaluate these estimates and assumptions based on the most recently available information, our own historical experiences
and various other assumptions that we believe to be reasonable under the circumstances. Since the use of estimates is an integral component
of the financial reporting process, actual results could differ from our expectations as a result of changes in our estimates. Some of
our accounting policies require a higher degree of judgment than others in their application and require us to make significant accounting
estimates.
The
following descriptions of critical accounting policies, judgments and estimates should be read in conjunction with our consolidated financial
statements and other disclosures included in this annual report. When reviewing our consolidated financial statements, you should consider
(i) our selection of critical accounting policies, (ii) the judgments and other uncertainties affecting the application of such policies
and (iii) the sensitivity of reported results to changes in conditions and assumptions.
Revenue
recognition– We adopted ASC Topic 606, “Revenue from Contracts with Customers” on January 1, 2019, using the modified
retrospective method applied to contract that was not completed as of January 1, 2019, the TAC with Pertamina. Under the modified retrospective
method, prior period financial positions and results will not be adjusted. The cumulative effect adjustment recognized in the opening
balances included no significant changes as a result of this adoption.
We
recognize revenues from the entitlement of Oil & Gas Property - Kruh Block Proven and profit sharing from the sale of the crude oil
under the TAC with Pertamina, when the Entitlement Calculation Sheets have been submitted to Pertamina after the monthly ICP has been
published by the Government of Indonesia. We deliver the crude oil we produce to Pertamina Jirak Gathering Station (“Pertamina-Jirak”),
located approximately 3 miles away from Kruh Block. After the volume and quality of the crude oil delivered is accepted and recorded
by Pertamina, Pertamina is responsible for the ultimate sales of the crude to the end-users. The total volume of crude oil sold is confirmed
by Pertamina and, combining with the monthly published ICP, we calculate the entire amount of our entitlement with Pertamina through
the Entitlement Calculation Sheets, at which point revenue is recognized.
We
currently generate revenue from Kruh Block and profit sharing from the sale of the crude oil under our new 10-year Joint Operation Partnership
(or KSO) that commenced in May 2020 by Pertamina. Prior to May 2020, Kruh Block was operated under a TAC agreement. In the KSO contract,
revenue is recognized through GWN from the 80% (eighty percent) of monthly proceeds excluding NSO (non-shareable oil) as monthly cost
recovery entitlement plus 23.5294% (twenty-three point five two nine four percent) of the remaining proceeds from the sale of the crude
oil after monthly cost recovery entitlement as part of the profit sharing.
Both
of these two portions are recognized as revenue, net of tax. Accordingly, there were no significant changes to the timing or valuation
of revenue recognized for sales of production from exploration and production activities.
We
do not have any contract assets (unbilled receivables) since revenue is recognized when control of the crude oil is transferred to the
refinery and the payment for the crude oil is not contingent on a future event.
There
were no significant contract liabilities or transaction price allocations to any remaining performance obligations as of December 31,
2020.
Use
of estimates– The preparation of the consolidated financial statements in conformity with US GAAP requires our management to
make a number of estimates and assumptions relating to the reported amounts of assets and liabilities and the disclosure of contingent
assets and liabilities at the date of the consolidated financial statements and the reported amounts of revenues and expenses during
the period. Significant accounting estimates reflected in our consolidated financial statements include but are not limited to estimates
and judgments applied in the allowance for receivables, write down of other assets, estimated useful lives of property and equipment,
oil and gas depletion, impairment of long-lived assets, provision for post-employment benefit and going concern. Actual results could
differ from those estimates and judgments.
Accounts
receivable and other receivables, net– Accounts receivable and other receivables are recorded at net realizable value consisting
of the carrying amount less an allowance for uncollectible accounts as needed. The allowance for doubtful accounts is our best estimate
of the amount of probable credit losses in our existing accounts receivable and other receivables. We determine the allowance based on
aging data, historical collection experience, customer specific facts and economic conditions. Account balances are charged off against
the allowance after all means of collection have been exhausted and the potential for recovery is considered remote. We did not have
any off-balance-sheet credit exposure relating to our customers, suppliers or others. For the years ended December 31, 2020 and
2019, we did not record any allowances for doubtful accounts against accounts receivable and other receivables nor did we charge
off any such amounts, respectively.
Impairment
of long-lived assets– We review our long-lived assets for impairment whenever events or changes in circumstances indicate that
the carrying amount of an asset may no longer be recoverable. When these events occur, we assess the recoverability of the long-lived
assets by comparing the carrying value of the long-lived assets to the estimated undiscounted future cash flows expected to result from
the use of the assets and their eventual disposition where the fair value is lower than the carrying value, measurement of an impairment
loss is recognized in the consolidated statements of operations and comprehensive income (loss) for the difference between the fair value,
using the expected future discounted cash flows, and the carrying value of the assets.
Oil
and gas property, net, full cost method – We follow the full-cost method of accounting for the oil and gas property. Under
the full-cost method, all productive and non-productive costs incurred in the acquisition, exploration and development associated with
properties with proven reserves, such as the TAC Kruh Block, are capitalized. As of December 31, 2020 and 2019, all capitalized costs
associated with Kruh Block’s reserves were subject to amortization.
Capitalized
costs are subject to a quarterly ceiling test that limits such costs to the aggregate of the present value of estimated future net cash
flows of proved reserves, computed using the unweighted arithmetic average of the first-day-of the-month oil and gas prices for each
month within the 12-month period prior to the end of reporting period, discounted at 10%, and the lower of cost or fair value of proved
properties. If unamortized costs capitalized exceed the ceiling, the excess is charged to expense in the period the excess occurs. There
were no cost ceiling write-downs for the years ended December 31, 2020 and 2019, respectively.
Depletion
for each of the reported periods is computed on the units-of-production method. Depletion base is the total capitalized oil and gas property
in the previous period, plus the period capitalization and future development costs. Furthermore, the depletion rate is calculated as
the depletion base divided by the total estimated proved reserves that expected to be extracted during the operatorship. Then, depletion
is calculated as the production of the period times the depletion rate.
For
the years ended December 31, 2020 and 2019, the estimated proved reserves were considered based on the operatorship of
the Kruh Block expiring in May 2030, as we completed all administrative steps of the process to obtain the extension of the operatorship
of the Kruh Block in the last quarter of 2018 and the uncertainty regarding the extension was removed.
The
costs associated with properties with unproved reserves or under development, such as PSC Citarum Block, are not initially included in
the full-cost depletion base. The costs include but are not limited to unproved property acquisition costs, seismic data and geological
and geophysical studies associated with the property. These costs are transferred to the depletion base once the reserve has been determined
as proven.
Liquidity
and Capital Resources
Six
Months Ended June 30, 2021 and 2020
We
generated a net loss of $2,932,213 and net cash used in operating activities of $1,635,829 for the six months ended June 30, 2021. In
addition, we have an accumulated deficit of $30,666,995 and working capital of $6,488,761 as of June 30, 2021. Our operating results
for future periods are subject to numerous risks and uncertainties, and it is uncertain if we will be able to reduce or eliminate our
net losses and achieve profitability for the foreseeable future. If we are unable to increase revenue or manage operating expenses in
line with revenue forecasts, we may not be able to achieve profitability. Moreover, considering our planned level of capital expenditures
during the next twelve months, we expect to incur a capital deficit. These conditions raise substantial doubt about our ability to continue
as a going concern.
Our
principal sources of liquidity include cash generated from operating activities (although our overall cash flows were negative during
the period), proceeds from our initial public offering which was completed on December 19, 2019, as well as short-term and long-term
borrowings from third parties or related parties. On November 14, 2016, PT Green World Nusantara, an indirect, wholly-owned subsidiary
of our company, entered in an agreement and credit facility in the form of an overdraft loan from PT Bank UOB Indonesia with a principal
amount not exceeding $1,900,000, an automatically renewable term of 1 year first due on November 14, 2017, and floating interest rate
spread of 1% per annum above the interest rate earned by the collateral account in which we deposit a balance of $2 million for the purpose
of pledging this loan. The pledge decreased to $1,000,000 since the facility decreased from $1,900,000 to $1,000,000 based on Latest
Amendment of Credit Agreement No. 0875 dated April 1, 2020. The unpaid borrowings were extended and due on November 14, 2021, and
subsequently extended to November 14, 2022. At June 30, 2021, the principal amount outstanding under the facility was approximately $980,452.
As
of August 31, 2021, we had approximately $2.77 million of cash and cash equivalents, which are unrestricted as to withdrawal or use and
are placed with financial institutions. In addition, and notwithstanding the going concern matters discussed above included as part of
our condensed consolidated financial statements as of June 30, 2021, we believe we may have continued access to financial support
from our principal shareholder in fulfilling our capital requirements (although we have no formal commitments in this regard).
We also expect that we will be able to fund any shortfall in cash requirements through bank debt with banks in Indonesia with which we
have pre-existing relationships and through potential public or private issuances of our securities. We will also continue to focus on
improving operational efficiency and cost reductions and developing our core cash-generating business as planned. We intend to meet our
cash requirements for the 12 months following the date of the issuance of this prospectus through operations and the foregoing potential
funding opportunities.
Based
on our current liquidity and anticipated funding requirements, particularly if our efforts discussed above are unsuccessful, we will need additional capital in the future to fund our operations. If we determine that our cash requirements exceed the amount of
cash and cash equivalents we have on hand at the time, we may seek to issue equity or debt securities or obtain credit facilities. The
issuance and sale of additional equity would result in further dilution to our shareholders. The incurrence of indebtedness would result
in increased fixed obligations and could result in operating covenants that might restrict our operations. We cannot assure you that
financing will be available from any source in amounts or on terms acceptable to us, if at all or, therefore, that we will be able to
satisfy our anticipated funding requirements.
Year
ended December 31, 2020 compared with year ended December 31, 2019
We
generated a net loss of $6,951,698 and net cash used in operating activities of $5,571,947 for the year ended December 31, 2020. In addition,
we have an accumulated deficit of $27,734,782 and working capital of $9,413,594 as of December 31, 2020. Our operating results for future
periods are subject to numerous uncertainties and it is uncertain if we will be able to reduce or eliminate our net losses and achieve
profitability for the foreseeable future. If we are unable to increase revenue or manage operating expenses in line with revenue forecasts,
we may not be able to achieve profitability.
Moreover,
considering our planned level of capital expenditures expected during the next twelve months, there will be an expected capital deficit
to occur. These conditions raise substantial doubt about our ability to continue as a going concern, and our auditor’s report on
our December 31, 2020 financial statements includes an explanatory paragraph in respect to there being substantial doubt about our ability
to continue as a going concern.
Our
principal sources of liquidity include cash generated from operating activities (although our overall cash flows were negative during
the period), proceeds from our initial public offering which was completed on December 19, 2019 (the “IPO”), as well
as short-term and long-term borrowings from third parties or related parties. On July 19, 2016, we entered into a loan agreement with
Thalesco Eurotronics Pte Ltd. (a third party) and obtained a loan facility in the amount of $2,000,000 with original maturity date on
July 30, 2017, renewed until July 30, 2020 to finance the drilling of one well in Kruh Block.On June 3, 2019, the loan was further extended
until May 22, 2023. The loan bears an interest rate of 1.5% per annum. We also obtained a credit facility in the form of an overdraft
loan with a principal amount not exceeding $1,900,000, an automatically renewable term of 1 year first due on November 14, 2017, and
floating interest rate spread of 1% per annum above the interest rate earned by the collateral account in which we deposited a balance
of $2,000,000 for the purpose of pledging this loan. On August 25, 2020 we repaid $1,000,000 towards the loan from Thalesco Eurotronics
Pte Ltd. As of the end of 2020 and 2019, the amount due to Thalesco Eurotronics Pre Ltd. was $1,000,000 and $2,000,000, respectively.
On
December 23, 2019, we consummated our IPO of 1,363,637 shares of our ordinary shares at a public offering price of $11.00 per ordinary
share for gross proceeds of $15,000,007 before underwriting discounts, commissions and expenses.
As
of February 28, 2022 (and after giving effect to our January 2022 financing transaction with L1 Capital), we had approximately
$2.8 million of cash and cash equivalents, which are unrestricted as to withdrawal or use and are placed with financial institutions.
In addition, and notwithstanding the going concern opinion included as part of our auditor’s report on our financial statements
for the year ended December 31, 2020, we believe we may have continued access to financial support from our principal shareholder
in fulfilling our capital requirements (although we have no formal commitments in this regard). We expect to fund any shortfall
in cash requirements through bank debt with banks in Indonesia with which we have pre-existing relationships and through potential public
or private issuances of our securities. We will also continue to focus on improving operational efficiency and cost reductions and developing
our core cash-generating business as planned. We intend to meet our cash requirements for the 12 months following the date of the issuance
of this prospectus through operations and the foregoing potential funding opportunities.
Based
on our current liquidity and anticipated funding requirements, we will need additional capital in the future to fund our operations.
If we determine that our cash requirements exceed the amount of cash and cash equivalents we have on hand at the time, we may seek to
issue equity or debt securities or obtain credit facilities. The issuance and sale of additional equity would result in further dilution
to our shareholders. The incurrence of indebtedness would result in increased fixed obligations and could result in operating covenants
that might restrict our operations. We cannot assure you that financing will be available from any source in amounts or on terms acceptable
to us, if at all or, therefore, that we will be able to alleviate our anticipated funding requirements.
In
light of the COVID-19 pandemic and due to the recent volatility in oil prices, we have added flexibility with respect to our planned
capital expenditures by limiting our contractual exposure and commitments to the drilling of only a limited number of wells at a time
throughout our Kruh Block drilling program in order to reduce liquidity risks and risks related to our ability to continue as a going
concern in the event that oil prices remain volatile or become depressed for the foreseeable future.
Cash
flows
The
following table sets forth certain historical information with respect to our statements of cash flows for the years ended December 31,
2020 and 2019:
| |
For The Years Ended |
| |
December 31, | | |
December 31, | |
| |
2020 | | |
2019 | |
Net cash (used in) provided by operating activities | |
$ | (5,186,048 | ) | |
$ | (439,794 | ) |
Net cash used in investing activities | |
| (357,333 | ) | |
| (1,045,579 | ) |
Net cash (used in) provided by financing activities | |
| (1,125,289 | ) | |
| 13,124,250 | |
Effect of exchange rate changes on cash and cash equivalents, and restricted cash | |
| - | | |
| - | |
Net change in cash and cash equivalents, and restricted cash | |
$ | (6,668,670 | ) | |
$ | 11,638,877 | |
Cash and cash equivalents, and restricted cash at beginning of year | |
| 16,072,169 | | |
| 4,433,292 | |
Cash and cash equivalents, and restricted cash at end of year | |
$ | 9,403,499 | | |
$ | 16,072,169 | |
Year
ended December 31, 2020 compared with year ended December 31, 2019
Operating
activities
Operating
activities used $5.19 million in cash for the year ended December 31, 2020, as compared to $0.44 million for 2019. The increase of approximately
$4.75 million in the amount of net cash used in operating activities is primarily due to an increase of net loss after adjusting non-cash
items of approximately $3.21 million for the year ended December 31, 2020 compared to $0.49 million for 2019. Furthermore, other contributions
for the increase net cash used in operating activities for the year ended December 31, 2020 comparing to 2019 included approximately
$1.05 million of cash outflow from account receivables and approximately $0.91 million cash outflow from other assets-current, accounts
payable and accrued expenses.
Investing
activities
Net
cash used in investing activities for the year ended December 31, 2020 was approximately $0.36 million, as compared to approximately
$1.05 million for the year ended December 31, 2019. The decrease of approximately $0.69 million of net cash used in investing activities
was primarily a result of a decrease of cash paid for deferred charges of $0.50 million and cash paid for oil and gas property of $0.19
million.
Financing
activities
Cash
used in financing activities for the year ended December 31, 2020 amounted to $1.13 million and primarily consisted of the repayment
of long-term loan to a third party and repayment of bank loan of about $0.13 million. Cash provided by financing activities for the year
ended December 31, 2019 amounted to $13.12 million and primarily consisted of the proceeds from our IPO offering of $13.65 million, partially
offset by payment for IPO cost of $0.53 million.
Contractual
Obligations
The
following table summarizes future commitments amounts on an undiscounted basis as of the date of this prospectus for all the planned
expenditures to be carried out at Kruh Block and Citarum Block:
| |
| | |
Future commitments | |
| |
Nature of commitments | | |
2022 | | |
2023 | | |
2024 and beyond | |
Citarum Block PSC | |
| | | |
| | | |
| | | |
| | |
Environmental study | |
| | | |
| 3,879 | | |
| - | | |
| - | |
Geological and geophysical (G&G) studies | |
| (a) | | |
$ | | | |
$ | 150,000 | | |
$ | 200,000 | |
2D seismic | |
| (a) | | |
| - | | |
| 3,300,000 | | |
| - | |
Drilling | |
| (b)(c) | | |
| - | | |
| - | | |
| 25,000,000 | |
Total commitments -Citarum PSC | |
| | | |
$ | 3,879 | | |
$ | 3,450,000 | | |
$ | 25,200,000 | |
Kruh Block KSO | |
| | | |
| | | |
| | | |
| - | |
Operating lease commitments | |
| (d) | | |
$ | 1,839,693 | | |
$ | 3,047,551 | | |
$ | 23,449,870 | |
Production facility | |
| | | |
| | | |
| 980,000 | | |
| 1,300,000 | |
G&G studies | |
| (a) | | |
| - | | |
| 200,000 | | |
| 800,000 | |
Sand fracturing | |
| | | |
| | | |
| - | | |
| - | |
2D seismic | |
| (a) | | |
| 1,227,634 | | |
| | | |
| - | |
3D seismic | |
| (a) | | |
| - | | |
| 1,227,634 | | |
| - | |
Drilling | |
| (a)(c) | | |
| 6,000,000 | | |
| 9,000,000 | | |
| 9,000,000 | |
Re-opening (2 wells) | |
| (a) | | |
| - | | |
| 50,000 | | |
| 50,000 | |
Total commitments -Kruh KSO | |
| | | |
$ | 9,067,327 | | |
$ | 14,505,185 | | |
$ | 34,599,870 | |
Total Commitments | |
| | | |
$ | 9,071,206 | | |
$ | 17,955,185 | | |
$ | 59,799,870 | |
Nature
of commitments:
|
(a) |
Both
firm commitments and 5 years work program according to the economic model are included in the estimate. Firm capital commitments
represent legally binding obligations with respect to the KSO of Kruh Block or the PSC of the Citarum Block in which the contract
specifies the minimum exploration or development work to be performed by us within the first three years of the contract. In certain
cases where we execute contracts requiring commitments to a work scope, those commitments have been included to the extent that the
amounts and timing of payments can be reliably estimated. |
|
|
|
|
(b) |
Include
one exploration and two delineation wells. |
|
|
|
|
(c) |
Abandonment
and site restoration are primarily upstream asset removal costs at the drilling completion of a field life related to or associated
with site clearance, site restoration, and site remediation, based on Indonesian government rules. |
|
|
|
|
(d) |
Operating
lease commitments are contracts that allow for the use of an asset but does not convey rights of ownership of the asset. An operating
lease presents an off-balance sheet financing of assets, where a leased asset and associated liabilities of future rent payments
are not included on the balance sheet of a company. An operating lease represents a rental agreement for an asset from a lessor under
the terms. Most of our operating leases are related with the equipment and machinery used in oil production. All of our operating
lease agreements with third parties can be cancelled or terminated at any time by us. |
Off-Balance
Sheet Arrangements
We
do not have any off-balance sheet arrangements that have or are reasonably likely to have a current or future effect on its financial
condition, changes in financial condition, and results of operations, liquidity or capital resources.
Internal
Control over Financial Reporting
In
connection with the audit of our consolidated financial statements for the year ended December 31, 2020, we and our independent registered
public accounting firm identified one material weaknesses in our internal control over financial reporting as of December 31, 2020. As
defined in the standards established by the U.S. Public Company Accounting Oversight Board, or PCAOB, a “material weakness”
is a deficiency, or combination of deficiencies, in internal control over financial reporting, such that there is a reasonable possibility
that a material misstatement of the annual or interim financial statements will not be prevented or detected on a timely basis.
The
material weakness identified related to the lack of sufficient financial reporting and accounting personnel with appropriate knowledge
of U.S. GAAP and SEC reporting requirements to properly address complex U.S. GAAP accounting issues and to prepare and review our consolidated
financial statements and related disclosures to fulfill U.S. GAAP and SEC financial reporting requirements.
We
have implemented and planned to implement a number of measures to address the material weakness by implementing the following measures:
|
● |
We
are in the process of hiring additional qualified finance and accounting staff with working experience in U.S. GAAP and SEC reporting
requirements. |
|
|
|
|
● |
We
have also established clear roles and responsibilities for accounting and financial reporting staff to address accounting and financial
reporting issues. |
|
|
|
|
● |
We
intend to establish an ongoing program to provide sufficient and appropriate training for financial reporting and accounting personnel,
especially training related to U.S. GAAP and SEC reporting requirements. |
|
|
|
|
● |
We
intend to engage professional financial advisory firms if necessary to provide ongoing training to our finance and accounting personnel
as well as to strengthen our financial reporting expertise and system. |
We
expect to complete the measures discussed above as soon as practicable and will continue to implement measures to remediate our internal
control deficiencies to comply with Section 404 of the Sarbanes Oxley Act. We expect that we will incur significant costs in the implementation
of such measures. However, we cannot assure you that all these measures will be sufficient to remediate our material weakness in time,
or at all. If we fail to implement and maintain an effective system of internal controls to remediate our material weakness over financial
reporting, we may be unable to accurately report our results of operations, meet our reporting obligations or prevent fraud, and investor
confidence and the market price of our ordinary shares may be materially and adversely affected.
As
a company with less than US$1.07 billion in revenue for our last fiscal year, we qualify as an “emerging growth company”
pursuant to the JOBS Act. An emerging growth company may take advantage of specified reduced reporting and other requirements that are
otherwise applicable generally to public companies. These provisions include exemption from the auditor attestation requirement under
Section 404 of the Sarbanes-Oxley Act of 2002 in the assessment of the emerging growth company’s internal control over financial
reporting for 5 years.
New
Accounting Standards
We
are an “emerging growth company,” as defined in the Jumpstart Our Business Startups Act of 2012 (the “JOBS Act”).
Under the JOBS Act, emerging growth companies (“EGCs”) can delay adopting new or revised accounting standards issued subsequent
to the enactment of the JOBS Act until such time as those standards apply to private companies.
In
February 2016, the Financial Accounting Standards Board (“FASB”) issued ASU No. 2016-02, Leases (Topic 842). The guidance
supersedes existing guidance on accounting for leases, with the main difference being that operating leases are to be recorded in the
statement of financial position as right-of-use assets and lease liabilities, initially measured at the present value of the lease payments.
For operating leases with a term of 12 months or less, a lessee is permitted to make an accounting policy election not to recognize lease
assets and liabilities. In July 2018, ASU 2016-02 was updated with ASU 2018-11, Targeted Improvements to ASC Topic 842, which provides
entities with relief from the costs of implementing certain aspects of the new leasing standard. Specifically, under the amendments in
ASU 2018-11, (1) entities may elect not to recast the comparative periods presented when transitioning to ASC 842 and (2) lessors may
elect not to separate lease and non-lease components when certain conditions are met. In November 2019, ASU 2019-10, Codification Improvements
to ASC 842 modified the effective dates of all other entities. In June 2020, ASU 2020-05 defer the effective date for one year for entities
in the “all other” category. For all other entities, the amendments in ASU 2020-05 are effective for fiscal years beginning
after December 15, 2021, and interim periods within fiscal years beginning after December 15, 2022. Early application of the guidance
continues to be permitted. We will adopt ASU 2016-02 from January 1, 2022. The Company expects material changes to its consolidated balance
sheet to recognize right-of-use lease assets and related lease liabilities for operating leases. We are in the process of evaluating
the impact on our consolidated financial statements upon adoption.
In
June 2016, the FASB issued ASU No. 2016-13, “Financial Instruments – Credit Losses”, which will require the measurement
of all expected credit losses for financial assets held at the reporting date based on historical experience, current conditions, and
reasonable and supportable forecasts. Subsequently, the FASB issued ASU No. 2018-19, Codification Improvements to Topic 326, to clarify
that receivables arising from operating leases are within the scope of lease accounting standards. Further, the FASB issued ASU No. 2019-04,
ASU 2019-05, ASU 2019-10, ASU 2019-11 and ASU 2020-02 to provide additional guidance on the credit losses standard. For all other entities,
the amendments for ASU 2016-13 are effective for fiscal years beginning after December 15, 2022, including interim periods within those
fiscal years, with early adoption permitted. Adoption of the ASUs is on a modified retrospective basis. We will adopt ASU 2016-13 from
January 1, 2023. The adoption is not expected to have a material impact on our condensed consolidated financial statements.
In
August 2018, the FASB issued ASU No. 2018-13, Fair Value Measurement (Topic 820) - Disclosure Framework—Changes to the Disclosure
Requirements for Fair Value Measurement. The amendments in this Update modify the disclosure requirements on fair value measurements
in Topic 820, Fair Value Measurement, based on the concepts in the Concepts Statement, including the consideration of costs and benefits.
The amendments in this Update are effective for all entities for fiscal years, and interim periods within those fiscal years, beginning
after December 15, 2019. We are in the process of evaluating the impact that this guidance will have on our consolidated financial statements.
In
December 2019, the FASB issued ASU No. 2019-12, Income Taxes (Topic 740): Simplifying the Accounting for Income Taxes. ASU 2019-12
removes certain exceptions related to the approach for intra-period tax allocation, the methodology for calculating income taxes in an
interim period and the recognition of deferred tax liabilities for outside basis differences. ASU 2019-12 also amends other aspects of
the guidance to help simplify and promote consistent application of GAAP. The guidance is effective for us for our fiscal year beginning
after December 15, 2021, to the extent we remain an emerging growth company, and early adoption is permitted. We are currently assessing
the impact that the adoption of ASU 2019-12 will have on our consolidated financial statements.
Other
accounting pronouncements that have been issued or proposed by the FASB or other standards-setting bodies that do not require adoption
until a future date are not expected to have a material impact on our consolidated financial statements upon adoption.
BUSINESS
Overview
We
are an oil and gas exploration and production company focused on Indonesia. Alongside operational excellence, we believe we have set
the highest standards for ethics, safety and corporate social responsibility practices to ensure that we add value to society. Led by
a professional management team with extensive oil and gas experience, we seek to bring forth the best of our expertise to ensure the
sustainable development of a profitable and integrated energy exploration and production business model. Our mission is to efficiently
manage targeted profitable energy resources in Indonesia. Our vision is to be a leading company in the Indonesian oil and gas industry
for maximizing hydrocarbon recovery with the minimum environmental and social impact possible. We were incorporated on April 24, 2018
as an exempted company with limited liability under the laws of the Cayman Islands and are a holding company for WJ Energy Group Limited
(or WJ Energy), which in turn owns our Indonesian holding and operating subsidiaries.
Indonesia’s
Oil and Gas Industry and Economic Information
The
largest economy in Southeast Asia, Indonesia (located between the Indian and Pacific oceans and bordered by Malaysia, Singapore, East
Timor and Papua New Guinea) has charted impressive economic growth since overcoming the Asian financial crisis of the late 1990s. The
Indonesian economy continued to recover in 2021 despite moderating due to the COVID-19 Delta variant wave mid-year. The Indonesian economy
is estimated to have expanded 3.7 percent during 2021 and is forecast to accelerate to 5.2 percent in 2022, according to the World Bank.
Today, Indonesia is the world’s 10th largest economy, a member of the G-20 and the world’s fourth most populous
nation with a population, according to the Central Intelligence Agency’s World Factbook, as of July 2021 of over 275 million. Indonesia
also has a prominent presence in other commodities markets such as thermal coal, copper, gold and tin, with Indonesia being the world’s
second largest tin producer and largest tin exporter, as well as in the agriculture industry as a producer of rice, palm oil, coffee,
medicinal plants, spices and rubber according to the Indonesia Commodity & Derivatives Exchange and the World Factbook.
The
Indonesian oil and gas industry is among the oldest in the world. Indonesia has been active in the oil and gas sector for over 130 years
after its first oil discovery in North Sumatra in 1885. The major international energy companies began their significant exploration
and development operations in the mid-20th century. According to the Special Taskforce for Upstream Oil and Gas Business Activities
(SKK Migas - Satuan Kerja Khusus Pelaksana Kegiatan Usaha Hulu Minyak dan Gas Bumi) Annual Report 2020 and the BP Statistical Review
of World Energy 2021, Indonesia held proven oil reserves of 2.44 billion barrels at the end of 2020. According to its public filings,
Chevron has been very active in Indonesia for over 50 years. Chevron has produced a very large amount of oil — 12 billion barrels
— over this period with billions of those barrels having been produced in Sumatra (the location of our Kruh Block, as described
below. The following map shows the area in which international major companies operate within Indonesia:
Source:
Indonesia Energy Corporation Limited
Indonesia’s
early entry into the energy industry helped the country become a global pioneer in developing a legal, commercial and financial framework
to support a very stable, growing industry that encouraged the hundreds of billions of dollars made in investment. The Indonesian energy
industry was the model of the global industry, having been the founder of the model form of production sharing contract which is still
used around the world as a preferred contract form; and this is the form of contract under which we operate our Citarum Block, as described
below.
Indonesia’s
oil and gas sector is governed by Law No. 22 of 2001 regarding Oil and Gas (November 22, 2001) (or the Oil and Gas Law). The Government
retains mineral rights throughout Indonesian territory and the government controls the state mining authority. The oil and gas sector
is comprised of upstream (namely exploration and production) and downstream activities (namely refining and processing), which are separately
regulated and organized. The upstream sector is managed and supervised by SKK Migas. Private companies earn the right to explore and
exploit oil and gas resources by entering into cooperation contracts, mainly based upon a production sharing scheme, with the government
through SKK Migas, thus acting as a contractor to SKK Migas. One entity can hold only one PSC, and a PSC is normally granted for 30 years,
typically comprising six plus four years of exploration and 20 years of exploitation.
The
oil and gas industry, however, both in Indonesia and globally, has experienced significant volatility in the last four years. Global
geopolitical and economic considerations play a significant role in driving the sensitivity of oil prices. From its peak in mid-2014
(US$105.72 per barrel), the Indonesia Crude Price (the “ICP”) for the type of crude oil we produce collapsed by more than
75% and began 2016 at US$25.83 per barrel. Since 2016, political and economic factors forced the global crude oil supply and demand to
a balance and ICP rose again to reach the average of US$61.89 for the year ended December 31, 2019. According to Forbes, in the first
quarter of 2020, the Covid-19 outbreak had a large impact on oil prices worldwide. As Saudi Arabia increased oil production and lowered
prices beginning of March, despite a lack in demand in the wake of the virus outbreak, benchmark oil prices collapsed by 25%. The ICP
was depressed to an average price of US$ 37.58 per barrel for the year ending December 31, 2020 which, compared to the year ending December
31, 2019, is a decline of 39.28% (although in 2021, the average ICP price has risen with an average December 2021 price of US$72.62 per
barrel).
The
problem of a lack of new reserve discoveries and reserve depletion still remains, resulting in a decline in the contribution to state
revenue from the Indonesian oil and gas sector. According to the PWC 2020 Guide, investment in the oil and gas industry was around US$12.1
billion in 2019, the highest since 2016 due to the rise in oil and gas prices triggering some investment interest. On a gas reserve basis,
as stated in the BP Statistical Review of World Energy 2021 (or the BP 2021 Report), Indonesia ranks 20th in the world and
the 4th in the Asia-Pacific region, following China, Australia and India.
According
to the DGOG, in 2020, investment of US$10.47 billion has been realized in upstream activities in Indonesia. The SKK Migas Annual Report
recorded that at the end of 2020, Indonesia had a total of 184 Contract Areas, comprising 95 Contract Areas in exploitation stage and
the remaining 89 in the exploration stage. SKK Migas also reported that total investment in 2020 was US$ 10.5 billion. Roughly 75% of
oil upstream activities are focused in Western Indonesia, where our blocks are located. SKK MIGAS also recorded that there are 42 main
projects in the upstream sector until 2027 with the total investment amount of US$ 43.3 billion. SKK Migas stated in their 2020 Annual
Report that the spirit to continue production has increased investment in 2018 up to 2019, but decreased in 2020. If compared in 2019,
investment in 2020 decreased by 9.5% due to various challenges from a technical point of view as well as the upstream oil and gas business
climate as the decline in oil prices and the conditions of the Covid-19 pandemic. In order to boost oil and gas investment and production,
the Indonesian government changed the PSC system in March 2018 from cost recovery to gross split, and further revoked 18 regulations
and 23 requirements for certifications, recommendations and permits, each in an attempt to reduce duplication in certification, shorten
bureaucracy and simplify the regulatory regime. The gross split scheme allocates oil and gas production to contracting parties based
on gross production, whereas in cost recovery, oil and gas production was shared between the government and contractors after deducting
the production costs. The government remains keen to attract more foreign investment into the domestic oil and gas industry due to insufficient
production against rising demand.
In
order to boost oil and gas investment and production, the Indonesian government changed the PSC system in March 2018 from cost recovery
to gross split, and further revoked 18 regulations and 23 requirements for certifications, recommendations and permits, each in an attempt
to reduce duplication in certification, shorten bureaucracy and simplify the regulatory regime. The
gross split scheme allocates oil and gas production to contracting parties based on gross production, whereas in cost recovery, oil and
gas production was shared between the government and contractors after deducting the production costs. The government remains
keen to attract more foreign investment into the domestic oil and gas industry due to insufficient production against rising demand.
According
to the BP 2021 Report, Indonesia’s oil consumption in 2020 reached 1.45 million barrels per day, 51% of which was met by domestic
production. The MEMR specified that Indonesia exported 31.45 million barrels of oil and imported 79.69 million barrels of oil in 2020.
SKK Migas recorded Thailand and Singapore as the top two countries Indonesia exported oil and condensate to in 2020, respectively at
10.18 million barrels and 4.13 million barrels.
Further,
we believe that Indonesia’s expanding economy, in combination with the government’s intention to lower reliance on coal as
a source for energy supply in industries, power generation and transportation, will cause Indonesian domestic demand for gas to rise
in the future. Indonesia’s power infrastructure needs substantial investment if it is not to inhibit Indonesia’s economic
growth. According to the MEMR 2020 Report, generating capacity at the end of 2020 was standing at around 72.8 gigawatts or an increase
of 4.5% compared to 69.7 gigawatts generating capacity in 2019. According to the 2017 Indonesian General National Energy Plan, the Government
has targeted an increase in power generation capacity to 190 gigawatts in 2030 and 443 gigawatts in 2050 to keep up with the electricity
demand from Indonesia’s growing middle class population and its manufacturing sector. The Indonesian Secretariat General of National
Energy Council has reported that Indonesia’s gas demand is estimated to rise from 1.67 TCF in 2015 to 2.45 TCF in 2025 with the
bulk of demand originating from Java and Bali, particularly for power stations and fertilizer plants.
According
to Indonesia Energy Outlook 2020, a report published by the Indonesian Agency for the Assessment and Application of Technology, from
2018 to 2050, Indonesia’s total energy demand is expected to grow at an average rate of 3.9% per year. For the same period, natural
gas demand average growth rate is estimated at 3.8% per year, industrial sector energy demand average growth rate is expected at 4.4%
per year and total electricity demand is expected to increase 630% by 2050, with 24% of it will be generated by gas.
In
terms of gas distribution, Indonesia still lacks an extensive gas pipeline network because the major gas reserves are located away from
the demand centers due to the particular territorial composition of the archipelagic state of Indonesia. Indonesian gas pipeline networks
have been developed based on business projects; thus, they are composed of a number of fragmented systems. The developed gas networks
are located mostly near consumer centers. Total gas transmission and distribution pipeline infrastructure in 2020 was 15.725,06 km which
is 6.51% higher compared to 2019 but still 46% lower compared to 2019 additional pipeline length. By
2024 Indonesia is expected to have a total of 17,300 km of gas pipeline network according to Oil and Gas Downstream Regulatory Agency
(BPH MIGAS) 2020 Performance Report.
In
West Java, where the Citarum Block is located, the total natural gas demand is expected to increase significantly from 2,521 MMSCFD in
2020 to 3,032 MMSCFD by 2035 according to Petromindo, an Indonesian petroleum, mining and energy news outlet. This will require
additional gas supply of 603 MMSCFD in 2020 and 1,836 MMSCFD in 2028 including import. Being relatively low-carbon compared to coal,
as well as being medium-cost, gas is likely to remain a favored fuel for at least the next decade, especially given Indonesia’s
extensive gas reserves. Moreover, energy demand in Indonesia is expected to increase as Indonesia’s economy and population grow.
Our
Opportunity
Beginning
in 2014, our management team identified a significant opportunity in the Indonesian oil and gas industry through the acquisition of medium-sized
producing and exploration blocks. In general terms, our goal was to identify assets with the highest potential for profitable oil and
gas operations. As described further below, we believe that our two current assets — Kruh and Citarum — represent just these
types of assets.
We
believe these medium-sized blocks were available for two main reasons: (i) a general lack of investment in the industry by smaller companies
such as ours and (ii) the fact that these blocks are overlooked by the major oil and gas exploration companies; many of which operate
within Indonesia.
The
fundamentals for the lack of investment in our target sector are the industry’s intensive capital requirements and high barriers
to entry, including high startup costs, high fixed operating costs, technology, expertise and strict government regulations. We have
and will continue to seek to overcome this through the careful deployment of investor capital as well as cash from our producing operations.
In
addition, the medium-sized blocks we target are overlooked by the larger competitors because their asset selection is subject to a higher
threshold criterion in terms of reserve size and upside potential to justify the deployment of their human resources and capital. This
means that a very small company is not capable of operating these blocks, a new investor is unlikely to enter this sector and the major
producers are competing for the larger assets.
This
scenario creates our corporate opportunity: the availability of overlooked assets including producing and exploration projects with untapped
potential resources in Indonesia that creates the potential to both generate economic profit and expand our operations in the years to
come.
An
important fact is that, since we started our operations in 2014, the natural resources industry has gone through a dramatic change due
to oil price volatility. The challenges imposed by low oil prices during this period created an incentive for us to operate efficiently
by driving our business to make the most use of the resources available within our organization to lower costs and improve operational
productivity. More recently, with an improvement in oil prices, we believe are in a good position to take advantage of our lower producing
costs.
Asset
Portfolio Management
Our
asset portfolio target is to establish an optimum mix between medium-sized producing blocks and exploration blocks with significant potential
resources. We believe that the implementation of this diversification technique provides our company the ability to invest in exploration
assets with substantial upside potential, while also protecting our investments via cash flow producing assets.
We
consider a producing block an oil and gas asset that produces cash flow or has the potential to produce positive cash flows in a short-term
period. An exploration block refers to an oil and gas block that requires a discovery to prove the resources and, once these resources
are proven, such project can generate multiple returns on capital.
Our
portfolio management approach requires us to acquire assets with different contracting structures and maturity stage plays. Another key
factor is that we believe the diversification provided by our asset portfolio gives us the ability to better face the challenges posed
by the industry, such as uncertainties in macroeconomic factors, commodity price volatility and the overall future state of the oil and
gas industry.
We
believe this strategy also allows us to maintain a sustainable oil and gas production business (a so-called “upstream” business)
by holding a portfolio of production, development and exploration licenses supported by a targeted production level. We believe that,
in the long-term, this should allow us to generate excess returns on investment along with reducing risk exposure.
Our
Assets
We
currently hold two oil and gas assets through our operating subsidiaries in Indonesia: one producing block (the Kruh Block) and one exploration
block (the Citarum Block). We also have identified a potential third exploration block (the Rangkas Area).
Kruh
Block
We
acquired rights to the Kruh Block in 2014 and started its operations in November 2014 through our Indonesian subsidiary PT Green World
Nusantara (or GWN). Kruh Block operated under a Technical Assistance Contract (or TAC) with Pertamina, Indonesia’s state-owned
oil and natural gas corporation, until May 2020 and the operatorship of Kruh Block shall continue as a Joint Operation Partnership (or
KSO) from May 2020 until May 2030. This block covers an area of 258 km2 (63,753 acres) and is located 16 miles northwest of
Pendopo, Pali, South Sumatra. This block produced an average of about 6,044 barrels of oil per month in 2020 and about 5,053 barrels
oil per month in 2021. Out of the total eight proved and potentially oil bearing structures in the block, three structures (North Kruh,
Kruh and West Kruh fields) have combined proved developed and undeveloped gross crude oil reserves of 4.39 million barrels (net crude
oil proved reserves of 2.63 million barrels) and probable undeveloped gross crude oil reserves of 2.15 million barrels as of December
31, 2020 determined on a May 2030 contract expiration date. Due to the production in 2021 and late start of development drilling program
caused by the Government permitting process and the COVID-19 pandemic, the proved reserves is likely to decrease in 2021 while the probable
reserves will increase. Probable reserves are those additional reserves that are less certain to be recovered than proved reserves but
which, together with proved reserves, are as likely as not to be recovered. While proved undeveloped reserves include locations directly
offsetting development spacing areas, probable reserves are locations directly offsetting proved reserves areas and where data control
or interpretations of available data are less certain. There should be at least a 50% probability that the actual quantities recovered
will equal or exceed the proved plus probable reserves estimates. The estimate of probable reserves is more uncertain than proved reserves
and has not been adjusted for risk due to the uncertainty. Therefore, estimates of proved and probable reserves may not be comparable
with each other and should not be summed arithmetically.
The
estimate of the proved reserves for the Kruh Block was prepared by representatives of our company (a team consisting of engineering,
geological and geophysical staff) based on the definitions and disclosure guidelines of the SEC contained in Title 17, Code of Federal
Regulations, Modernization of Oil and Gas Reporting, Final Rule released January 14, 2009 in the Federal Register. Our proved oil reserves
have not been estimated or reviewed by independent petroleum engineers.
The
following map shows the Kruh Block and its producing fields:
Our
two main objectives in acquiring Kruh Block was to initiate our operations with a cash producing asset and for our legal entity to earn
the required experience to participate in bids and direct tenders with the Government.
We
selected Kruh based on certain criteria according to our strategy: (i) selecting an area with proven hydrocarbons; (ii) finding a currently
producing structure which is not overdeveloped; and (iii) operating an asset located in the western part of Indonesia.
Pursuant
to the Kruh TAC, our subsidiary GWN is a contractor with the rights to operate in the Kruh area with an economic interest in the development
of the petroleum deposits within the block until May 2020. The contract is based on a “cost recovery” system, meaning that
all operating costs (expenditures made and obligations incurred in the exploration, development, extraction, production, transportation,
marketing, abandonment and site restoration) are advanced by GWN and later repaid to GWN by Pertamina. Pursuant to the Kruh TAC, all
the oil produced in Kruh Block is delivered to Pertamina and, subsequently, GWN recovers the operating costs through the proceeds of
the sale of the crude oil produced in the block in a monthly basis, but capped at 65% of such monthly proceeds. GWN is also entitled
to an additional 26.7857% of the remaining proceeds from the sale of the crude oil after monthly cost recovery repayment as part of the
profit sharing. Together with our share split, our net revenue income is around 74% of the total production times the ICP. On a monthly
basis, we submit to Pertamina an Entitlement Calculation Statement (ECS) stating the amount of money that we are entitled to base on
the oil lifting, ICP, cost recovery and profit sharing of the respective month. In connection with our acquisition (by which we mean
our entry into the TAC) of Kruh Block, approximately $15 million of the acquisition costs were carried to our financial statements from
the previous contractor. The cost recovery scheme is illustrated and described in “—Legal Framework for the Oil and Gas Industry
in Indonesia” below. Since our recoverable cost balance will not be fully recovered up to the expiry of the contract, our net income
is not subject to any tax whatsoever.
Historically,
the cooperation agreement between Pertamina and its contractors were established via a TAC, but after the regulatory reform in the early
2000’s and the reorganization of Pertamina, the contractual relationship between Pertamina and its partners was changed into KSO.
As
of May 22, 2020, we commenced the continuation of our operatorship of Kruh Block under a KSO contract that has a term until May 2030.
In essence, the TAC and KSO are very similar in nature due to its “cost recovery” system, with a few important differences
to note. The main differences between both contracts are that: (1) in the TAC, all oil produced is shareable between Pertamina and its
contractor, while in the KSO, a Non-Shareable Oil (NSO) production is determined and agreed between Pertamina and its partners so that
the baseline production, with an established decline rate, belongs entirely to Pertamina, so that the partners’ revenue and production
sharing portion shall be determined only from the production above the NSO baseline; (2) in the TAC, the cost recovery was capped at
65% (sixty-five percent) of the proceeds from the sale of the oil produced in the block, while in the KSO, the cost recovery is capped
at 80% of the proceeds from the sale of the oil produced within Kruh Block for the cost incurred during the term under the KSO plus 80%
of the operating cost per bbl multiplying non-shareable oil (NSO). Also, under the KSO terms, we have committed to a 3 years’ work
program to drill additional wells and perform exploration activities such as 2D and 3D seismic within the Kruh Block. If we fail to fulfill
our obligations, including the performance of the work program commitment, Pertamina will have the right to terminate our KSO contract
and our bank guarantee shall be deemed forfeited. As of December 2021, we have fulfilled the obligation of drilling commitment specified
in the KSO contract.
In
March 2021, we mobilized the drilling rig to drill 3 back-to-back producing wells at our 63,000 acre Kruh Block. Each of the 3 wells
are expected to average production of 173 barrels of oil per day over the first year of production. We anticipate that each well will
cost approximately $1.5 million to drill and complete. Based on the terms of our contract with the Indonesian government and an assumed
oil price of $63.50/barrel, each well is expected to generate $3.33 million in net revenue in its first year, which is more than double
the cost to drill each well. Also in March 2021, we received necessary permits that will allow us to move forward to commence our previously
announced drilling plans in 2021 for Kruh Block. In April 2021, we announced that new drilling for these 3 wells had commenced. Due to
delays in the government permitting process and COVID-19-related delays experienced during 2021, our overall drilling program for Kruh
Block has similarly been somewhat delayed. We still plan on drilling 18 new wells, but now through 2024 rather than 2023. We completed
the drilling of 2 of those wells in 2021, with the additional 16 more wells during the course of 2022 to 2024. No assurances can be given
that these new wells will generate the amounts of oil we estimate, if any at all.
When
we acquired the Kruh Block in 2014, it had seven producing wells in 2014 and produced 200 barrels of oil per day (BOPD) with an average
cost of production per barrel of US$60.25, while 90% of the production relied on only one well, Kruh-20.
Our
development plan for the Kruh Block was to increase the production by drilling proved undeveloped (PUD) wells which we considered a low
risk investment due to the higher probability of these wells to produce commercial levels of oil compared to drilling wells with unproved
reserves. Finding ways to increase the production is particularly important in maturing fields as producing volumes inevitably decline
due to the normal decline rate of production in these fields. In financial terms, our target was to produce the highest cash inflow within
the remaining period of the contract.
With
this target in mind, following execution of Kruh TAC we started to collect data through a passive seismic survey in 80 locations and
by reactivating an old well (Kruh-19) to obtain additional geological information. After seismic data re-interpretation and modelling,
we initiated our drilling campaign for 2 wells, Kruh-21 (K-21) and Kruh-22 (K-22).
In
October 2015, we started drilling K-21 with a targeted depth of 3,418 feet that resulted in a daily production of only 45 BOPD due to
a permeability and tortuosity (a measure of how convoluted a well is) issues.
In
November 2015, we started drilling K-22 with a targeted depth of 4,600 feet which resulted in a 30 BOPD due to the same permeability
and tortuosity issue discovered in K-21.
In
the beginning of 2016, we focused on finding solutions to increase the production in K-21 and K-22. From February to May, we performed
an acidizing and sand fracturing operation to bypass the challenges in production efficiency that affected the wells K-21 and K-22. This
resulted in a multiple production gain in both K-21 and K-22, increasing the production of these wells to 95 BOPD and 98 BOPD, respectively.
During
2016, oil price crisis hit its bottom with an ICP of only $25.83 in the month of January. As a result of this low price, our operations
went through a cost analysis procedure in order to determine the economic limit of each of our producing wells by identifying their respective
direct production cost. Accordingly, we closed a total of 6 wells that were producing less than 10 BOPD that year. We were required to
find solutions to enhance our operating margins in a tough oil price environment, so we discontinued operations of 6 out of the 9 wells
we had at that time.
As
such, 2016 represented our effort to consolidate our operations in terms of efficiency that resulted in the reduction of operating costs,
allowing our company to go through the crude oil price turmoil. The cost reduction and efficiency measures taken include (i) setting
an economic limit for each operating well and closing wells that has exceeded $40 per barrel production cost; (ii) increased production
from the remaining wells through stimulation activities; (iii) renegotiating contracts with service providers; (iv) establishing a fuel
utilization plan that allowed us to use the gas produced from our wells as engine fuel and (v) optimized surface facilities equipment
and system.
In
May 2017, we drilled our third development well (K-23) with a cost of approximately US$ 1.5 million in Kruh Block with total depth of
3,315 feet that resulted in a production of 30 BOPD due to same issues encountered in K-21 and K-22, permeability and tortuosity issues.
In
October 2017, a stimulation operation of sand fracturing by Halliburton was performed in two wells, K-21 and K-23, in order to improve
the flow of hydrocarbons into these wells. Following completion, the production of K-23 was increased from 30 BOPD to 170 BOPD and in
K-21 from 20 BOPD (production in K-21 declined back to 20 BOPD due to increase in the water cut from 2016 to 2017) to 95 BOPD. This stimulation
resulted in an increase of 3,844 barrels oil per month, resulting on our peak total production of more than 11,000 barrels oil per month
or 380 BOPD during the subsequent month.
One
well service was completed in June 2018 for K-21 to restore the production by cleaning the well from the sand material that filled the
borehole carried by the formation fluid. No development wells were drilled in 2016 and 2018 and no exploratory wells were drilled by
our company up to date.
Other
major activities in the Kruh field during 2018 were well services and necessary work for maintaining production. The work included well
cleaning and production string replacement.
In
December 2018, we initiated a pilot project with the application of electrical stimulation oil recovery method (ESOR) for an attempt
of increasing the oil production in the Kruh field. The basic function of the ESOR process is to increase the mobility of the oil by
reducing its viscosity which in turn helps move the oil toward producing wells. By inducing direct current power through existing oil
wells, the electric field drives the oil from the anode to the cathode, a process commonly referred to as electrokinetics. During the
trial period in 2019, we did not observe significant increases of production rate from the 4 producing wells. Therefore, we terminated
the pilot project in February 2020. In 2022, an improved method from ESOR called EEOR (Electrical Enhanced Oil Recovery) system is available
to be tried in the field. We plan to install this new EEOR system to help improve our oil recovery including possibly remove the reservoir
damage in K-25.
During
the period of our operatorship, we have incurred total expenditures of at least $15 million, including drilling costs of three wells.
We were able to produce oil from all three wells drilled during our operatorship, which represents a 100% drilling success ratio. We
also improved our water treatment system, installed a thermal oil heater to increase the speed in which the water is separated from the
oil, as Pertamina allows a maximum of 0.5% of water content in the oil transferred to them, and upgraded our power generating facilities
to gas fueled engines.
Since
2014, we have increased the gross production from 250 BOPD (gross) in early 2014 and reached a peak of 400 BOPD in 2018, which we achieved
by the drilling of three new wells and upgrade of the production facilities. Our production is our primary source of revenue. At a per
barrel crude price of US$61.89 (historical 12-month average price calculated as the average ICP for each month in 2019) and a production
of 7,582 barrels of oil per month, we were able to generate approximately US$470,000 per month of gross revenue from Kruh. We intend
to gradually increase production on the block over the next few years, with an anticipated nominal amount of additional capital expenditures
required.
During
2019, Kruh Block produced an average of about 7,582 barrels per month (gross). This represented an average of 26.9% decline from the
4 producing wells. The two major producing wells K-22 and K-23 wells, however, only declined at 14.9% rate. During the period of December
2014 to December 2019, we have produced a total of 497,398 barrels of oil from the Kruh structure.
During
2020, Kruh Block produced an average of about 6,044 barrels per month (gross), slightly less than in 2019 due to an anticipated decline
of 20.3%. As of December 2020, we have produced a total of 72,524 barrels of oil from the Kruh structure. The production rate is expected
to increase given the commencement of new drilling at Kruh Block in April 2021.
Historically,
the average gross initial production of the 29 oil wells drilled in Kruh Block is 191 BOPD, with an average gross production of 173 BOPD
throughout the wells’ first year of production, considering an exponential decline rate per year of 21%. The decline rate of 21%
was estimated based on the decline curve analysis of field-wide production history from 2017 to December 2019. Based on this data, a
well in Kruh Block would be expected to produce, on average, a total gross amount of approximately 63,112 bbls of crude oil in its first
year. Also, due to the successful stimulation and maintenance, wells K-22 and K-23 have significantly lower decline rate than 21%. Based
on the data above, the KSO cost recovery terms and using an average oil price of US$61.89 (the previous 12-months average monthly ICP
as of December 31, 2019), on average, a well would generate US$ 3.24 million net revenue in its first year (US$ 1.70 million in its first
6 months).
In
October 2017, we formally started negotiations with Pertamina to obtain an extension for the operatorship of the Kruh Block after the
expiry of our term in May 2020 through a KSO contract with Pertamina. Through a performance appraisal, we successfully qualified to continue
the operatorship of Kruh Block. In October 2018, Pertamina has sent us the Direct Offering Invitation of Kruh Block attached with the
contract draft for 10 years continuing operatorship period. In July 2019, we received the award by Pertamina to operate the Kruh Block
for an additional 10 years under an extended KSO. The KSO contract was signed on July 26, 2019. Thus, the reserve estimation and economic
models assumptions, as of December 31, 2019 and 2018, consider that we have the operatorship of the Kruh Block until May 2030, as evidence
indicates that renewal is reasonably certain, based on SEC Regulation S-X §210.4-10(a)(22) that defines proved oil and gas reserves.
As
of December 31, 2020 and December 31, 2019, considering the operatorship of Kruh Block ending in May 2030, net proved reserves have a
net ratio of approximately 61.13% and 43.55% of total reserves, respectively. This net ratio calculation is based on our revenue entitlement
taking into consideration the cost recovery balance estimations and profit sharing portions throughout the Kruh Block operatorship period.
As of December 31, 2017, with the Kruh Block operatorship ending in May 2020, the unrecovered expenditures on TAC operations of $20,258,361
would remain unrecovered up to the end of the TAC, hence our entitlement to 74.37% of the revenue from the sales of the crude oil produced
until the expiry of the TAC in May 2020 (65% of the proceeds from the sale of the crude oil produced as cost recovery plus 26.7857% profit
sharing portion of the remaining 35% of the proceeds from the sale of the crude oil), which results in a net proved reserves ratio of
74.37% of total reserves at that point in time. In contrast, as of December 31, 2018, with an assumed extension of the Kruh Block operatorship
to May 2030 and with the cost recovery balance reset to zero in May 2020, we estimate that we will be entitled to approximately 42.72%
of the revenues from the sales of the crude oil produced throughout the operatorship in Kruh Block until May 2030, considering the cost
recovery balance estimations and profit sharing portions throughout the Kruh Block operatorship period, resulting on a net proved reserves
ratio of 42.72% of total reserves.
Following
the confirmation of the Kruh Block extension, in 2020 our board of directors approved a development plan for a drilling program of 18
Proved Undeveloped Reserves (or PUD) wells at Kruh Block. As conditions have warranted (as described below), the drilling program
schedule has been updated and is currently contemplated to be as follows (taking into account the 2 wells that were drilled in 2021):
| |
UnitYear | |
2022 | | |
2023 | | |
2024 | | |
Total | |
Planned PUD wells | |
Gross well | |
| 4 | | |
| 6 | | |
| 6 | | |
| 16 | |
Future wells costs (1) | |
US$ | |
| 6,000,000 | | |
| 9,000,000 | | |
| 10,500,000 | | |
| 24,000,000 | |
Total gross PUD added | |
Bbls | |
| 785,935 | | |
| 1,119,503 | | |
| 1,036,969 | | |
| 2,942,406 | |
Total net PUD added | |
Bbls | |
| 366,645 | | |
| 522,257 | | |
| 483,775 | | |
| 1,372,657 | |
(1) |
Future
wells costs are the capital expenditures associated with the new wells costs and do not include other capital expenditures such as
production facilities. |
Due
to the delay of the drilling plan caused by the Government permitting process and the COVID-19 pandemic, the gross and net proved reserves
added each year were reduced.
We
commenced new drilling operations in Kruh Block in March 2021, and new drilling of 3 wells commenced in April 2021. In March 2021 we
announced our plan to drill a total of 5 wells in 2021, 6 wells in 2022 and 7 wells in 2023, for a total of 18 new wells on Kruh Block.
Due to delays in the Government permitting process and COVID-19-related delays experienced during 2021, our overall drilling program
for Kruh Block has similarly been somewhat delayed. We still plan on drilling 18 new wells, but now through 2024 rather than 2023 as
shown in the table above. We completed the drilling of 2 of those wells in 2021, with the additional 16 more wells during the course
of 2022 to 2024.
We
commenced the drilling of a well named “Kruh-25” at Kruh Block on April 21, 2021 and another well named “Kruh-26”
at Kruh Block on August 22, 2021. As a result of our successful drilling program at Kruh-26, our production rate increased by over 50%
from approximately 160 barrels of oil per day during the first 10 months of 2021 to approximately 245 barrels of oil per day as of late
December 2021. Kruh 25 has not reached its optimal production rate as a result
of significant damage due to flooding during an extended period of heavy monsoon rain in 2021, leading to extremely difficult working
conditions caused by a deteriorated drill site and inadequate equipment performance. We are currently conducting remedial workover activities
at Kruh 25 so that it can attempt to match the results of the Kruh-26 well. We will use Electrical Enhanced Oil Recovery (or EEOR), an
electro kinetic process to improve oil recovery, to help remedy the damage in K-25 reservoirs. Such technique improves viscosity of fluids
by electrochemical reactions such as oxidation and reduction (REDOX reactions). Our other existing producing wells at Kruh Block could
also potentially benefit from this technique.
Our
2022 drilling plans include the commencement of drilling of our next 2 new wells at Kruh Block by the end of the first quarter of 2022.
Additionally; we plan to commence drilling of a third new well at Kruh Block before the end of the second quarter of 2022. Drilling operations
for these three new wells (named “Kruh-27”, “Kruh-28” and “Kruh-29”) are being funded from the net
proceeds of our January 2002 institutional investor financing from L1 Capital. We may seek to start an additional well in 2022 according
to the plan shown in the table above if conditions permit.
For
Proved Developed (or PDP) reserves, as a result of more effective reservoir management, we produced 72,524 bbls for the year ended December
2020, an increase of 2,687 bbls from our June 2020 estimate, and a decrease of 135 bbls from our December 2019 estimate. Effective oil
field maintenance ensures our realization meets production forecast.
The
gross oil reserves were reduced from 4,619,992 bbls as of December 31, 2019 to 4,393,408 bbls as of December 31, 2020 mostly due to the
production and rescheduling of our drilling plan. As of December 31, 2020, the net reserves were estimated as 2,631,512 bbls using a
per barrel crude price of US$37.58 (historical 12-month average price calculated as the average ICP for each month in 2020). In a “cost
recovery” system such as the Kruh KSO contract, the production share and net reserves entitlement to our company increases in periods
of lower oil prices (61.13% net share for ICP, US$37.58 in year 2020) and decreases in periods of higher oil prices (43.55% net share
for ICP, US$66.12 in year 2019). This means that the estimated net proved reserves quantities are subject to oil price related volatility
due to the method in which the revenue is derived throughout the contract period. Therefore, the net proved reserves are estimated based
on the revenue generated by our company according to the KSO economic models.
The
tables below summarize the gross and net crude oil proved reserves as of December 31, 2020 in Kruh Block:
| |
| Crude Oil
Proved Reserves at Kruh
Block | |
Gross Crude Oil Reserves | |
| | | |
| | |
Gross Crude Oil Proved Developed Producing Reserves (PDP) | |
| Bbl | | |
| 322,887 | |
Gross Crude Oil Proved Undeveloped Reserves (PUD) | |
| | | |
| 4,070,521 | |
Total Gross Crude Oil Reserves | |
| Bbl | | |
| 4,393,408 | |
| |
| | | |
| | |
Net Crude Oil Reserves | |
| | | |
| | |
Net Crude Oil Proved Developed Producing Reserves (PDP) | |
| Bbl | | |
| 143,120 | |
Net Crude Oil Proved Undeveloped Reserves (PUD) | |
| | | |
| 2,488,392 | |
Total Net Crude Oil Reserves | |
| Bbl | | |
| 2,631,512 | |
Our
estimates of the proved reserves are made using available geological and reservoir data as well as production performance data. These
estimates are reviewed annually by internal reservoir engineers, and Pertamina, and revised as warranted by additional data. The results
of infill drilling are treated as positive revisions due to increases to expected recovery. Other revisions are due to changes in, among
other things, development plans, reservoir performance and governmental restrictions.
Our
proved oil reserves have not been estimated or reviewed by independent petroleum engineers. The estimate of the proved reserves for the
Kruh Block was prepared by IEC representatives, a team consisting of engineering, geological and geophysical staff based on the definitions
and disclosure guidelines of the SEC contained in Title 17, Code of Federal Regulations, Modernization of Oil and Gas Reporting, Final
Rule released January 14, 2009 in the Federal Register.
Kruh
Block’s general manager and our Chief Operating Officer have reviewed the reserves estimate to ensure compliance to SEC guidelines
for (1) the appropriateness of the methodologies employed; (2) the adequacy and quality of the data relied upon; (3) the depth and thoroughness
of the reserves estimation process; (4) the classification of reserves appropriate to the relevant definitions used; and (5) the reasonableness
of the estimated reserve quantities.”
Net
reserves were estimated using a per barrel crude price of US$37.58 (historical 12-month average price calculated as the average ICP for
each month in 2020). In a “cost recovery” system, such as the TAC or KSO, in which Kruh Block operates or will operate, the
production share and net reserves entitlement to our company reduces in periods of higher oil price and increases in periods of lower
oil price. This means that the estimated net proved reserves quantities are subject to oil price related volatility due to the method
in which the revenue is derived throughout the contract period. Therefore, the net proved reserves are estimated based on the revenue
generated by our company according to the TAC and KSO economic models.
As
of December 31, 2020, Kruh Block had 4 oil producing wells (K-20, K-21, K-22 and K-23 in Kruh field) covering 47 acres. There were 18
proved undeveloped oil locations in Kruh (6), North Kruh (7) and West Kruh (5) field covering 491 acres. In the West Kruh field, there
are additional 9 probable locations covering 279 acres. See details on table below.
PDP, PUD and Probable Locations and Acreage for the Kruh Block as of December 31, 2020 |
Reserves Category | |
Kruh Field | | |
North Kruh Field | | |
West Kruh Field | | |
Total | |
| |
Locations | | |
Acreage | | |
Locations | | |
Acreage | | |
Locations | | |
Acreage | | |
Locations | | |
Acreage | |
Proved Dev Producing (PDP) | |
| 4 | | |
| 58 | | |
| - | | |
| - | | |
| - | | |
| - | | |
| 4 | | |
| 58 | |
Proved Undeveloped (PUD) | |
| 6 | | |
| 73 | | |
| 7 | | |
| 263 | | |
| 5 | | |
| 155 | | |
| 18 | | |
| 491 | |
Total Proved | |
| 10 | | |
| 131 | | |
| 7 | | |
| 263 | | |
| 5 | | |
| 155 | | |
| 22 | | |
| 549 | |
Probable | |
| - | | |
| - | | |
| - | | |
| - | | |
| 9 | | |
| 279 | | |
| 9 | | |
| 279 | |
Total Proved & Probable | |
| 10 | | |
| 131 | | |
| 7 | | |
| 263 | | |
| 14 | | |
| 434 | | |
| 31 | | |
| 828 | |
The
following table summarizes the gross and net developed and undeveloped acreage of Kruh Block based on our TAC and KSO terms, as well
as our economic model as of December 31, 2020:
Gross and Net Developed and Undeveloped Acreage of Kruh Block as of December 31, 2020 |
| |
| Developed Acreage | | |
| Undeveloped Acreage | | |
| Total Acreage | |
Kruh Block | |
| Gross | | |
| Net | | |
| Gross | | |
| Net | | |
| Gross | | |
| Net | |
Kruh Field | |
| 58 | | |
| 35 | | |
| 73 | | |
| 45 | | |
| 131 | | |
| 80 | |
North Kruh Field | |
| - | | |
| - | | |
| 263 | | |
| 161 | | |
| 263 | | |
| 161 | |
West Kruh Field | |
| - | | |
| - | | |
| 155 | | |
| 95 | | |
| 155 | | |
| 95 | |
Other | |
| - | | |
| - | | |
| 63,204 | | |
| 38,638 | | |
| 63,204 | | |
| 38,638 | |
Total | |
| 58 | | |
| 35 | | |
| 63,695 | | |
| 38,939 | | |
| 63,753 | | |
| 38,974 | |
Citarum
Block
Citarum
Block is an exploration block covering an area of 3,924.67 km2 (969,807 acres). The block is located onshore in West Java with a population
of 48.7 million people and only 16 miles south of the capital city of Indonesia, Jakarta, thus placing it within a short distance to
the major gas consumption area in Indonesia – the Greater Jakarta region in West Java. We believe this significantly mitigates
the logistical and geographical challenges posed by Indonesia’s composition and infrastructure, significantly reducing the commercial
risks of our project.
Citarum
Block is located in onshore Northwest Java basin. In terms of geology, a very effective petroleum system has been proved in the region
from the long history of exploration and production efforts since the 1960’s. According to the United States Geological Survey
(USGS) assessment (Bishop, Michele G. “Petroleum Systems of The Northwest Java Province, Java and Offshore Southeast Sumatra, Indonesia”,
Open-File Report 99-50R, 2000), “Northwest Java province may contain more than 2 billion barrels of oil equivalent in addition
to the 10 billion barrels of oil equivalent already identified”. However, little new reserves have been added to the region during
the last 15 years due to the lack of investments in exploration programs. We have not engaged independent oil and gas reserve engineers
to audit and evaluate the accuracy of the reserve data from the USGS research.
Citarum
Block also shares its border with the producing gas fields of Subang, Pasirjadi, Jatirarangon and Jatinegara. The combined oil and gas
production from more than 150 oil and gas fields in the onshore and offshore Northwest Java basin, operated by Pertamina, is 45,000 BOPD
and 450 million standard cubic feet gas per day (MMSCFD). The following graphics show the Citarum Block together with the producing oil
and gas fields in the region, as well as the block’s proximity to the West Java gas transmission network:
Source:
Indonesia Energy Corporation Limited
Source:
Indonesia Energy Corporation Limited
We
started collecting data regarding the Citarum Block in 2016, when we decided it was time to expand our asset base by adding an exploration
block to our portfolio. Given our strategy, we had to find a cost efficient method to acquire a block with the potential to add hydrocarbons
reserves to our company as part of the process to maximize our company’s value. With the necessary technical knowledge and regulatory
experience from our professionals, we agreed that the best method for us to acquire an exploration block was via a Joint Study proposal
to the Government in a “work area” that had not yet been reserved for the bidding process by the Government. The Joint Study
objective is to determine oil and gas potential within a proposed working area by conducting geological and geophysical work such as
field surveys, magnetic surveys and the reprocessing of existing seismic lines. Upon completion of the Joint Study, if the Government
further decided to conduct a bidding process for the working area, we would have the right to change our offer (right to match) in the
bidding process if the other bidders gave higher offers.
Therefore,
following our plans, our team identified Citarum, an open onshore area in West Java that was available for a Joint Study. In September
2016, after we formally expressed our interest to the government to conduct the Joint Study in Citarum and fulfilled all requirements,
we obtained the approval to initiate our Joint Study program in conjunction with DGOG and LAPI ITB (a third-party consultancy service
provided by Bandung Institute of Technology (or ITB)). The study target was to integrate field geological survey, subsurface mapping,
identify stratigraphy and structural geology, perform a basin analysis and petroleum system assessment. As part of our proposal, we engaged
a surveyor to perform a passive seismic as an alternative method to fill the gap of the existing two-dimensional seismic survey due to
the absence of data on some area on the block. With 111 survey points, the work was completed in two months and covered approximately
one third of the area, as shown in the illustration below. The data produced from the passive seismic together with the existing two-dimensional
seismic data we acquired from the Indonesian National Data Management Company were the base for the Joint Study.
Between
2009 and 2016, Citarum Block had been operated by Pan Orient Energy Corp. (or POE), a Canadian oil and natural gas company whose shares
are listed on the TSX Venture Exchange. POE carried out various exploration work on the Citarum block, including the drilling of 4 wells
in different locations across the block: Pasundan-1, Geulis-1, Cataka-1 and Jatayu-1. Providentially, all 4 wells discovered natural
gas and gas flow was recorded for the Pasundan-1 and Jatayu-1 wells. The total investment made by POE on Citarum Block was $40,630,824.
Pasundan-1
encountered gas at a depth between 6,000 feet and 9,000 feet, while the mud log and sidewall cores displayed oil and gas shows. Cataka-1
well had gas indication from approximately 1,000 feet depth to 2,737 feet when the well was abandoned due to drilling problems as a result
of inexperience operating in the region. Jatayu-1 well flowed high-pressured gas from approximately 6,000 feet depth and had a strong
indication of gas-bearing between 5,800 feet and 6,700 feet depth. Geulis-1 well had gas indication from 1,000 feet to 4,300 feet depth.
All 4 wells were suspended and plugged as the equipment and consumables used were not compatible to the drilling conditions, formation
or strong gas flow. Also, the gas indication/flowing from the wells would have been much more significant had the formations had not
been damaged by high mud weight during drilling. Proper preparation to avoid drilling issues encountered by the previous operator for
the up-coming drilling program should lead to an efficient delineation of gas discoveries.
The
results from the 4 wells drilled in Citarum and the amount of data available regarding the block are the key factors for us in selecting
Citarum as the block’s risk profile was significantly reduced with the discovery of gas across the block. Likewise, the fact that
gas zones exist at different depths between 1,000 feet and 6,000 feet contributes to the potential of commercially developing these gas
discoveries. As a result of this plus the significant amount of capital expenditures incurred by the previous operator, who discovered
natural gas and gas flows from the 4 drilled wells. We believe this provides us with a unique de-risked asset to continue exploration
on.
In
the region, oil and gas have been producing from sandstone and carbonate reservoirs within 5 geologic formations (from old to young,
Jatibarang, Talangakar, Baturaja, Upper Cibulakan and Parigi). The carbonate buildups in the Baturaja, Upper Cibulakan and Parigi formations
are particularly gas rich. Within the Citarum Block, both sandstone and carbonate reservoirs have been encountered during drilling. Because
of the gas-prone type II Kerogen domination in the Talangakar source rock of deltaic origin in the hydrocarbon generating “kitchens”
(Ciputat, Kepuh, Pasirbungur and Cipunegara), prospects within the Citarum Block are mostly gas-bearing if discovered. The following
illustration shows the northwest java stratigraphy:
The
Joint Study was completed within a 12 month period (8 months plus a 4 month extension period) and the findings summarized in a report
with the following information regarding the area: synopsis of regional geology and petroleum system, play concept, lead and prospect,
volumetric of hydrocarbon prospect and economic prospect valuation. The following diagram illustrates the full Joint Study process:
In
February 2018, Citarum Block was tendered through a direct offer by the MEMR. Following the tender process, we were awarded the rights
to explore the Citarum Block in May 2018. The exploration period for Citarum block is comprised of a 6 years period that could be extended
for an additional 4 years up to 2028.
In
July 2018, a Production Sharing Contracts (or PSC) was signed with respect to Citarum between MEMR and two of our wholly-owned subsidiaries,
PT Cogen Nusantara Energi (or CNE) and PT Hutama Wiranusa Energi (or HWE), marking the official commencement of our 30 years operatorship
term for the Citarum Block.
The
following timeline illustrates the Citarum Block acquisition process:
As
part of our commitment of conducting a 300 km of seismic survey, we have recently submitted our work program and budget to the Indonesian
Interim Taskforce for Upstream Oil and Gas Business Activities (Satuan Kerja Khusus Pelaksana Kegiatan Usaha Hulu Minyak dan Gas Bumi,
or SKK Migas). Upon its approval, we will start an Environmental Base Assessment for the region in conjunction with a local university
and use the result as a base for any exploration activity in the area. This is part of our exploration activity in Citarum. When the
exploration program is initiated, we plan to conduct more G&G studies and a 300km2 2D seismic within the first year of
the exploration program and drill our first exploration well in the Jonggol area in its second year. If the drilling is successful, we
plan on conducting a 100km2 3D seismic within the second year and drill additional 2 delineation wells in the third year in order to
propose a phase 1 development plan for the Citarum Block. If no petroleum in commercial quantities is discovered in Citarum during the
exploration period, our PSC would be automatically terminated.
The
upcoming exploration program for Citarum will begin with the 8 prospects with the lowest risk (38%-48%), 5 in the Jonggol region and
3 in the Purwakarta region, out of the 28 exploration prospects previously identified and evaluated by the Joint Study. Based on data
published by SKK Migas, the table below shows the number of exploration wells drilled in Indonesia from 2012 to 2020 and the number of
wells that results in oil and gas recovery.
Description Year | |
2012 | | |
2013 | | |
2014 | | |
2015 | | |
2016 | | |
2017 | | |
2018 | | |
2019 | | |
2020 | | |
Total | |
Total Exploration Wells | |
| 96 | | |
| 75 | | |
| 64 | | |
| 33 | | |
| 33 | | |
| 15 | | |
| 22 | | |
| 26 | | |
| 28 | | |
| 392 | |
Total Discovery Wells | |
| 65 | | |
| 53 | | |
| 47 | | |
| 27 | | |
| 23 | | |
| 10 | | |
| 13 | | |
| 8 | | |
| 12 | | |
| 258 | |
Success Ratio | |
| 68 | % | |
| 71 | % | |
| 73 | % | |
| 82 | % | |
| 70 | % | |
| 67 | % | |
| 59 | % | |
| 31 | % | |
| 43 | % | |
| 66 | % |
Source:
SKK Migas
Considering
the closeness to the oil and gas generating “kitchens”, multiple reservoir horizons, moderate risked faulted anticlinal traps,
and proved hydrocarbons in previous drilling and nearby producing fields, we believe that 23 of the 28 prospects have geological chance
factors of success in the range of 30%-50%. Geological chance factors for the remaining 11 prospects are between 20% and 30%.
In
2020, further technical work in the Citarum block resulted additional 9 prospects and 9 exploration leads (T series prospects and leads
on the maps below). The 28 prospects identified in 2019 (J and P series prospects) remain to be the primary prospects for further evaluation
by the upcoming new seismic data. The acreage of primary prospects, potential reservoir thickness and net reservoir volume remain no
change at this time.
Prospect | | |
Drilling sequence | | |
Acreage (acres) | | |
Reservoir thickness (feet) | | |
Net reservoir volume (acres-feet) | |
| 1 | | |
| J-1 | | |
| | | |
| 438 | | |
| 192 | | |
| 83,867 | |
| 2 | | |
| J-2 | | |
| | | |
| 1,299 | | |
| 301 | | |
| 390,848 | |
| 3 | | |
| J-3 | | |
| | | |
| 96 | | |
| 28 | | |
| 2,704 | |
| 4 | | |
| J-4 | | |
| | | |
| 229 | | |
| 115 | | |
| 26,374 | |
| 5 | | |
| J-5 | | |
| 3rd | | |
| 2,141 | | |
| 153 | | |
| 327,861 | |
| 6 | | |
| J-6 | | |
| 5th | | |
| 1,130 | | |
| 373 | | |
| 421,131 | |
| 7 | | |
| J-7 | | |
| | | |
| 119 | | |
| 61 | | |
| 7,263 | |
| 8 | | |
| J-8 | | |
| | | |
| 269 | | |
| 379 | | |
| 102,026 | |
| 9 | | |
| J-9 | | |
| 7th | | |
| 1,686 | | |
| 1,479 | | |
| 2,492,477 | |
| 10 | | |
| J-10 | | |
| | | |
| 1,060 | | |
| 353 | | |
| 374,265 | |
| 11 | | |
| J-11 | | |
| | | |
| 89 | | |
| 95 | | |
| 8,418 | |
| 12 | | |
| J-12 | | |
| | | |
| 730 | | |
| 386 | | |
| 282,175 | |
| 13 | | |
| J-13 | | |
| | | |
| 177 | | |
| 235 | | |
| 41,486 | |
| 14 | | |
| J-14 | | |
| | | |
| 262 | | |
| 75 | | |
| 19,701 | |
| 15 | | |
| J-15 | | |
| 4th | | |
| 1,546 | | |
| 798 | | |
| 1,233,162 | |
| 16 | | |
| J-16 | | |
| 2nd | | |
| 1,757 | | |
| 396 | | |
| 695,267 | |
| 17 | | |
| J-18 | | |
| | | |
| 173 | | |
| 17 | | |
| 2,943 | |
| 18 | | |
| J-20 | | |
| | | |
| 1,044 | | |
| 339 | | |
| 353,835 | |
| 19 | | |
| J-21 | | |
| | | |
| 238 | | |
| 59 | | |
| 14,083 | |
| 20 | | |
| P-1 | | |
| | | |
| 707 | | |
| 383 | | |
| 271,013 | |
| 21 | | |
| P-2 | | |
| | | |
| 798 | | |
| 314 | | |
| 250,600 | |
| 22 | | |
| P-3 | | |
| 1st | | |
| 2,274 | | |
| 725 | | |
| 1,648,940 | |
| 23 | | |
| P-4 | | |
| | | |
| 1,567 | | |
| 386 | | |
| 604,920 | |
| 24 | | |
| P-5 | | |
| 6th | | |
| 2,680 | | |
| 405 | | |
| 1,085,879 | |
| 25 | | |
| P-6 | | |
| | | |
| 1,259 | | |
| 665 | | |
| 837,121 | |
| 26 | | |
| P-7 | | |
| | | |
| 1,272 | | |
| 181 | | |
| 230,161 | |
| 27 | | |
| P-8 | | |
| 8th | | |
| 1,079 | | |
| 762 | | |
| 821,361 | |
| 28 | | |
| P-9 | | |
| | | |
| 517 | | |
| 790 | | |
| 408,314 | |
| | | |
| Total | | |
| | | |
| 26,636 | | |
| 10,445 | | |
| 13,038,195 | |
The
following depicts our development plan for Citarum, with the first priority being to confirm the value of the block by proving reserves
and later to monetize the asset through the production and sale of gas:
During
2020, a new geological, geophysical and biostratigraphic study was performed on the Citarum Block. Eighteen additional exploration prospects
were identified. This provides additional opportunities for oil and gas exploration in the future.
In
2021, we continued to evaluate the resource size and risk for the prospects. Design of the 2D seismic acquisition and processing program
is underway. The 2D seismic program will be used to further evaluate the prospects before we begin the drilling program.
Our
Citarum PSC contract is based on the “gross split” regime, in which the production of oil and gas is to be divided between
the contractor and the Indonesian Government based on certain percentages in respect of (a) the crude oil production and (b) the natural
gas production. Our share will be the Base Split share plus a Variable and Progressive component. Our Crude Oil Base Split share is 43%
and our Natural Gas Base Split share is 48%. Our share percentage is determined based on both variable (such as carbon dioxide and hydrogen
sulfide content) and progressive (such as crude oil and refined gas prices) components.
Thus,
pursuant to our Citarum PSC contract, once Citarum commences production, we are entitled to at least 65% of the natural gas produced,
calculated as 48% from the Base Split plus a Variable Component of 5% from the first Plan of Development (POD I) in Citarum, a Variable
Component of 2% from the use of Local Content, as the oil and gas onshore services are mostly closed or restricted for foreign companies
(as described below under “—Legal Framework for the Oil and Gas Industry in Indonesia), and a 10% increase for the first
180 BSCF produced or 30 million barrels of oil equivalent which according to our economic model, the cumulative production of 180 BSCF
will only be achieved in 2025.
The
following table summarizes the gross and net developed and undeveloped acreage of Citarum Block based on our PSC terms and economic model
as of December 31, 2020:
Gross and Net Developed and Undeveloped Acreage of Citarum Block as of December 31, 2020. |
| |
| Developed Acreage | | |
| Undeveloped Acreage | | |
| Total Acreage | |
| |
| Gross | | |
| Net | | |
| Gross | | |
| Net | | |
| Gross | | |
| Net | |
Citarum Block | |
| - | | |
| - | | |
| 969,807 | | |
| 550,317 | | |
| 969,807 | | |
| 550,317 | |
Total | |
| - | | |
| - | | |
| 969,807 | | |
| 550,317 | | |
| 969,807 | | |
| 550,317 | |
Pursuant
to our PSC for Citarum Block, in order to incentivize and optimize our exploration activities at Citarum, there are circumstances under
which we are required or may be required to relinquish portions of the contract area back to the Government, with such portions being
subject to be agreed to between us and the Government. For example:
|
(i) |
on
or before the end of the initial three (3) contract years beginning with the date the PSC was approved by the Government, we
are required to relinquish twenty percent (20%) of the original total contract area in Citarum. |
|
|
|
|
(ii) |
if
at the end of the third (3rd) contract year, certain agreed to work programs have not been completed, upon consideration
and evaluation of SKK Migas, we would be obliged to relinquish an additional fifteen
percent (15%) of the original total contract area at the end of the third contract year. |
|
|
|
|
(iii) |
on
or before the end of the sixth (6th) contract year, we are required relinquish additional portions of contract area so
that the area retained thereafter shall not be in excess of twenty percent (20%) of the original total contract area; provided, however,
that on or before the end of the sixth (6th) contract year, if any part of the contract area corresponding to the surface
area in which petroleum has been discovered, is greater than twenty percent (20%) of the original contract area, then we
will not be obliged to relinquish such excess area. |
In
advance of the date of any relinquishment, we will advise SKK Migas of the portion to be relinquished. For the purpose of such relinquishment,
we will consult with SKK Migas regarding the shape and size of each individual portion of the areas being relinquished, provided, however,
that so far as reasonably possible, such portion shall each be of sufficient size and convenient shape to enable petroleum operations
to be conducted thereon.
Potential
Additional Block (Rangkas Area)
In
mid-2018, we identified an onshore open area in the province of West Java, adjacent to our Citarum block. We believe that this area,
also known as the Rangkas Area, holds large amounts of crude oil due to its proven petroleum system. To confirm the potential of Rangkas
Area, in July 2018, we formally expressed our interest to the DGOG of MEMR to conduct a Joint Study in the Rangkas Area and we attained
the approval to initiate our Joint Study program in this area on November 5, 2018. The Rangkas Joint Study covered an area of 3,970 km2
(or 981,008 acres) and was completed in November 2019. The DGOG accepted the completion of the joint study and inquired IEC’s interest
for further process to tender the block. The study result suggested an effective petroleum system for oil and gas accumulations. Furthermore,
with the opportunity to integrate the operation of Citarum and Rangkas together efficiently, we decided to issue a Statement of Interest
Letter in December 2020 to the Ministry of Energy (DGOG) as we intend to enter into a PSC contract for the Rangkas through a direct tender
process. We will have the right to change our offer in order to match the best offer following the results of the bidding process. The
timeline for the tender is contingent upon the DGOG’s plans and schedule
Source:
Indonesia Energy Corporation Limited
The
Rangkas Joint Study includes field geological surveys, geochemical and passive seismic surveys and the reprocessing of existing seismic
lines was completed in November 2019. The Joint Study evaluated stratigraphy and structural geology of the area, conducted geochemical
techniques to evaluate source rock and oils, performed passive seismic data analysis for identifying hydrocarbon occurrence, and performed
basin analyses for assessing the petroleum system of the area with the objective of determining its oil and gas potential. Results of
the study suggested (1) data from four wells drilled pre-World War II and two wells drilled in 1991 indicated the presence of hydrocarbon
in the area with the discovery of several oil seeps and one gas seep, (2) the petroleum system in the area is proven with the occurrence
of Eocene-Oligocene-Miocene source, reservoir and seal rocks similar to adjacent major producing hydrocarbon areas in West Java, and
(3) twenty-one petroleum prospects and leads with potentially stacked reservoirs were identified.
Since
the study of Rangkas block suggests high potential of finding hydrocarbons, we plan to continue pursue the PSC contract of the block
which would be available through a direct tender process in which we will have the right to change our offer in order to match the best
offer following the results of the bidding process, which has not taken place as of the date of this prospectus. The timeline for the
tender is contingent upon the DGOG’s plans and schedule.
Our
Competitive Strengths
We
believe we have the following competitive strengths:
|
● |
Experienced
management. |
|
○ |
Our
management and technical team are comprised of some of the brightest and most passionate people in the industry, including with expertise
in exploration technology. |
|
|
|
|
○ |
Our
professional team consistently adopts innovative concepts and technologies to reduce risks in exploring oil and gas, and continually
looks for better ways to effectively manage our exploration and production operations. |
|
○ |
Our
management team members (Chief Executive Officer, Chief Operating Officer, Chief Business Development Officer and General Manager)
collectively have many years of experience in petroleum exploration, development and production operations. Together they have successfully
operated more than 17 oil and gas blocks and found and developed more than 10 oil and gas fields over the last 16 years. Our recently
added management team located in the United States consists of our President and Chief Financial Officer. Our President brings 41
years of public energy company experience and was the founder of two energy companies that are or were listed on the NYSE American.
Our Chief Financial Officer brings 38 years of financial business experience, mostly as either a chief financial officer or controller,
including over 16 years working in public companies. |
|
|
|
|
○ |
Our
top management team members have certification in “Kepala Teknik Tambang” from the Indonesian government, qualifying
them for the implementation and compliance of occupational safety and health legislation in mining and petroleum operations. We are
fully committed to conducting our operations according to the best industry practices to ensure the health, safety and security of
all our stakeholders as well as the protection of the environment and surrounding communities. |
|
● |
Established
relationships. Through our management team’s experience in operating blocks in Indonesia, we have established close relationships
with central and local governments, service providers and other petroleum companies in Indonesia. The excellent relationship between
management members and government agencies provides us extraordinary opportunities of accessing low risk and high potential blocks.
In addition, our U.S. management team likewise has established relationships with key participants in the U.S. capital and energy
markets that we believe will be an asset to us as a U.S.-listed public company. |
|
|
|
|
● |
Significant
network. Our company has built solid alliances and a vast knowledge network within the Indonesian oil and gas industry, which
gives us the ability to execute complex projects and traverse Indonesian regulatory and institutional risk. |
|
|
|
|
● |
Niche
market. We look to acquire the rights to operate small to “medium sized blocks” onshore that are most likely overseen
by the larger competitors. Being an independent and efficient oil and gas company in Indonesia, we have the flexibility and speed
necessary to seize opportunities as they arise. |
|
|
|
|
● |
Strategically
located assets. Our company has a proven track record in acquiring assets located close to major infrastructure and populous
cities. We believe that being strategically located to major infrastructure will enable higher margins as we scale our business. |
Our
Business Strategies
We
are an active independent Indonesian exploration and production company with an ultimate goal to generate value for our shareholders.
Our overall growth strategy is to actively develop our current blocks and to acquire new assets to boost our growth. We will also evaluate
available opportunities to expand our business into the oil and gas downstream industry in Indonesia.
The
key elements for achieving our goal are set out below.
|
● |
Strategic
investment allocation in existing blocks. We are focused on validating the reserves of our blocks by continuing to develop high
impact exploration activities to add reserves, combined with a plan of development in order to increase production. |
|
|
|
|
● |
Commercialization
and monetization of oil and gas discoveries. We are a revenue driven company and we strategically adjust our operations and development
programs in our blocks by evaluating the market and the Indonesian energy demand. |
|
|
|
|
● |
Develop
our “de-risked” 969.807 acres Citarum Block. $40.6 million was invested by the block’s prior owner, Pan Orient
Energy Corp. (TSXV.POE) who drilled 4 wells and successfully discovered natural gas and gas flow from each of the 4 wells. We believe
this contribution provides us with a unique de-risked asset to continue exploration on. |
|
● |
Expansion
of our company’s asset portfolio. We actively seek to acquire blocks to increase our company’s value. The energy
demand growth and increase of manufacturing activities in the region could lead us to invest into the downstream oil and gas sector. |
|
|
|
|
● |
Maintain
balance sheet strength to offset commodity cyclicality. We intend to fund our exploration and production activities with equity,
free cash flow and a moderate use of debt. With the uncertainty within our sector, we believe that maintaining a strong balance sheet
will be critical to our growth. |
Competition
We
face competition from other oil and gas companies in the acquisition of new oil blocks through the Indonesian government’s tender
process. Our competitors for these tenders include Pertamina, the Indonesian state-owned national oil company (who can tender for blocks
on its own), and other well-established large international oil and gas companies. Such companies have substantially greater capital
resources and are able to offer more attractive terms when bidding for concessions. Therefore, to mitigate the risk of competition, our
corporate strategy is to focus on small to “medium sized blocks” onshore that are most likely overseen by the larger competitor.
Facilities,
Distribution and Logistics
We
do not own any property or facilities. We lease our corporate headquarters in Jakarta, Indonesia, as well as a field office for our operations
in Kruh Block. In Kruh Block, due to the cost recovery fiscal terms, the facilities, vehicles, machinery and equipment required for the
production of oil and gas are leased by us. The diagram below depicts our current storage, distribution and logistics of the oil from
our wells at Kruh to the delivery point to Pertamina:
Legal
Framework for the Oil and Gas Industry in Indonesia
Background
Under
Article 33(3) of the Constitution of the Republic of Indonesia, all natural resources, including all oil and gas resources, in Indonesia
belong to the state and should be used for the greatest benefit of the citizens of Indonesia. As a result, while the Government controls
and manages oil and gas resources by, among other things, granting licenses or concessions to third party contractors such as our company,
it retains ultimate control over all oil and gas activities in Indonesia.
Prior
to the Law No. 22 of 2001 on Oil and Gas (which we refer to herein as the Oil and Gas Law), the Government controlled all oil and gas
undertakings in Indonesia and granted Perusahaan Pertambangan Minyak dan Gas Bumi Negara (the predecessor to Pertamina, as described
below) the exclusive right to manage and carry out all operations within the territory of Indonesia. Any other enterprise seeking to
invest in the Indonesian oil and gas sector required the appointment or approval of the MEMR, and any actual investment would be done
through a contractual arrangement with Pertamina. Most of these arrangements took the form of production sharing arrangements such as
PSCs, TACs, and KSOs entered into between Pertamina and the contractors.
Beginning
with the Oil and Gas Law in 2001, the Government adopted a series of measures to introduce market reform into Indonesia’s oil and
gas sector. The Oil and Gas Law remains the primary umbrella legislation governing all oil and gas activities in Indonesia. It places
control over the oil and gas industry in the hands of the MEMR and the DGOG. It also established two new governmental bodies –
the Oil and Gas Upstream Regulatory Body (Badan Pelaksana Minyak dan Gas Bumi, or BP Migas) and the Oil and Gas Downstream Regulatory
Body (Badan Pengatur Hilir Minyak dan Gas Bumi, or BPH Migas) – to regulate activities in their respective sectoral areas.
The Oil and Gas Law also divides and for the first time distinguishes between upstream and downstream activities. Further regulations
elaborate and implement important aspects of the Oil and Gas Law.
Following
the transfer of Pertamina’s control over exploration and production activities in the territory of Indonesia to BP Migas, Pertamina
was converted under Government Regulation No. 31 of 2003 converted Perusahaan Pertambangan Minyak dan Gas Bumi Negara into a for-profit,
state-owned company in the form of a limited liability company (known as a Perseroan). Further, Government
Regulation No. 35 of 2004 on Upstream Oil and Gas Business as amended several times, most recently by Government Regulation No. 55 of
2009 on Second Amendment to the Upstream Oil and Gas Business (or GR 35/2004), transferred Pertamina’s responsibility for managing
all production sharing arrangements (except TACs) to BP Migas. These changes have left the reformed Pertamina free to tender for contracts
on an equal basis with other companies. Pertamina also split its upstream and downstream operations by incorporating subsidiaries which
specifically engage in either upstream or downstream activities. Pertamina’s subsidiary in charge of the upstream activities is
PT Pertamina EP (or Pertamina EP) while there are several Pertamina’s subsidiaries established for the downstream activities.
On
November 13, 2012, the Constitutional Court of the Republic of Indonesia (Mahkamah Konstitusi Republic Indonesia, or MK) issued
Decision 36/PUU-X/2012 (which we refer to as MK Decision 36/2012), which found the transfer of authority to BP Migas under the Oil and
Gas Law unconstitutional, ordering the regulatory body be dissolved and all its authority and responsibilities be transferred to the
Government through the MEMR. Following a series of Presidential and Ministerial regulations, the duties and functions of BP Migas ultimately
were transferred to the Interim Taskforce for Upstream Oil and Gas Business Activities (Satuan Kerja Khusus Pelaksana Kegiatan Usaha
Hulu Minyak dan Gas Bumi, or SKK Migas) in 2013. As a consequence, production sharing contracts (except TACs) that had previously
been transferred to BP Migas from Pertamina were then transferred to SKK Migas. As for TACs, they remain with Pertamina.
Executing
Agency for Upstream Activities
Indonesian
law currently distinguishes between upstream activities (encompassing the exploration and exploitation of oil and gas resources) and
downstream activities (comprising the processing, transporting, storing, and trading of oil and gas). As described above, the distinction
between the two types of activities was introduced in the Oil and Gas Law in 2001. Prior to this, Indonesian law did not recognize any
market segmentation, and Pertamina was responsible for all aspects of oil and gas operation activities.
The
Oil and Gas Law extends this sectoral division to the regulatory bodies established under such law, with BP Migas assuming responsibility
for regulating upstream activities and BPH Migas assuming responsibility for downstream activities and both reporting to the DGOG. Furthermore,
the Oil and Gas Law and Government Regulation No. 42 of 2002 on Executing Agency for upstream Oil and Gas Business Activities together
required that, once established, BP Migas take over Pertamina’s existing production sharing arrangements and that BP Migas become
the Government party to subsequent arrangements.
MK
Decision 36/2012 dissolved BP Migas and transferred its authority and responsibility back to the MEMR until a new oil and gas law is
adopted. In reaching its decision, the MK found that Article 33(3) of the Indonesian Constitution required the Government to manage oil
and gas resources directly and that the supervisory duties given to BP Migas fell short of that requirement. It also found that the Government’s
monitoring and regulatory activities under BP Migas had deteriorated to the point where it no longer met its constitutional obligations.
On
the same day as the MK’s decision, both the President and the MEMR responded to MK Decision 36/2012 by issuing, in order, Presidential
Regulation No. 95 of 2012 on the Transfer of Duties and Functions of Upstream Oil and Gas Activities (or PR 95/2012), which transfers
BP Migas’ authority and responsibilities to the MEMR. In addition, PR 95/2012 upholds existing arrangements by confirming that
all PSCs signed by BP Migas would remain valid until their respective expiration dates. MEMR Regulation No. 3135 K/08/MEM/2012 on Transfer
of Duties, Functions and Organizations in Execution of Oil and Gas Business (or MEMR Regulation 3135/2012), which transfers those duties
to the Interim Task Force for Upstream Oil and Gas Business Activities (Satuan Kerja Sementara Pelaksana Kegiatan Usaha Hulu Minyak
dan Gas Bumi) as the implementation regulation of PR 95/2012. The Interim Task Force for Upstream Oil and Gas Business Activities
is accountable to the MEMR.
Following
the enactment of PR 95/2012 and MEMR Regulation 3135/2012, on January 10, 2013 the President issued Presidential Regulation No. 9 of
2013 on the Implementation of Management of Natural oil and Gas Upstream Business Activities, as amended by the Presidential Regulation
No. 36 of 2018 (or PR 9/2013), which established SKK Migas and transferred the authorities to manage upstream oil and gas activities
which are based on cooperation contracts to the new regulatory body. PR 9/2013 also establishes a Supervisory Commission, whose membership
consists of the MEMR as Chairman, the Vice Minister of Finance, who manages the State Budget as the Vice Chairman, the Chairman of the
Capital Investment Coordinating Board, Minister of Environment and Forestry, Chief of National Police and the Vice Minister of the MEMR,
so that SKK Migas can control, supervise, and evaluate the management of the upstream oil and gas business activities under its authority.
The Supervisory Commission is required to submit a report to the President at least once every six months.
Foreign
Direct Investment in the Oil and Gas Industry
Private
investment in upstream interests in Indonesia can be made through either a “business entity” or a “permanent establishment”.
The Oil and Gas Law defines “business entity” as a legal entity which is established under the law of and domiciled in the
Republic of Indonesia, which operates in Indonesia, and which undertakes business permanently and continuously in Indonesia. Such business
entities usually take the form of a limited liability company (Perseroan Terbatas). The Oil and Gas Law defines “permanent
establishment” as a legal entity which is established outside of Indonesia which undertakes activities within the Indonesian territory
and complies with the prevailing Indonesian laws. The permanent establishment allows foreign investors to conduct upstream activities
through a branch of a foreign incorporated enterprise.
The
Omnibus Law amended several provisions of the Oil and Gas Law. However, the changes were relatively limited pending the enactment of
the proposed amendments the Oil and Gas Law. The Government has since issued Government Regulation No. 5 of 2021 on Implementation of
Risk-based Licensing, which serves as an implementing regulation to the Omnibus Law and which, among others, extends the requirement
to obtain a Business Registration Number (Nomor Induk Berusaha or NIB) to oil and gas contractors which operate as “permanent
establishments”.
Business
entities and permanent establishments carry out upstream activities as contractors under a cooperation agreement with the representative
of the Government. The Oil and Gas Law stipulates that a contractor may only be awarded one cooperation agreement for one working area
as an implementation of the “ring-fencing” principle where revenues and costs in respect of one working area under one cooperation
agreement cannot be consolidated with and used to relieve the tax obligations of another working area under a different cooperation agreement.
As
our operating subsidiaries are each a Perseroan domiciled in Indonesia, we operate under the “business entity” regime of
the Oil and Gas Law.
Upstream
Regulations
Upstream
activities are conducted in working areas whose boundaries are determined by the MEMR. Each contractor may only be granted one working
area; as a result, upstream oil and gas companies operating in Indonesia, such as ours, incorporate separate legal entities for each
asset in which they have an interest. Upstream activities are performed through cooperation contracts between either SKK Migas or Pertamina
and contractors. Unlike any other industry in Indonesia, upstream oil and gas activities are open to participation by foreign business
entities that are established and incorporated outside Indonesia.
MEMR
Regulation No. 35 of 2008 on Procedures of Determining and Bidding Oil and Gas Working Areas (or MEMR Regulation 35/2008) regulates the
awards of work areas, which may be granted on the basis of either a competitive tender process or a direct offer. The Director General
of the DGOG may put a working area out to tender and invite bids for an interest in the area after considering the opinion and inputs
of SKK Migas. Direct offers shall be performed based on a contractor’s written proposal for a working area that has not been reserved
for the bidding process; if the Director General of the DGOG approves such proposal, the contractor must conduct a survey together with
the DGOG to locate potential oil and gas fields (which we refer to as a Joint Study).
Joint
Study Agreement
Pursuant
to MEMR Regulation 35/2008, where an area has not already been reserved for the bidding process, a contractor may bid for such
working area directly by providing the Director General of the DGOG with a written proposal. If the Director General approves the proposal,
the contractor must conduct a Joint Study of the proposed area with the DGOG or any other party appointed by the DGOG. The Joint Study
is conducted for the purposes of upgrading the data quality of geological and geophysical work such as field surveys, magnetic surveys,
or the reprocessing of existing seismic lines, and is conducted over an eight-month period with a single possible extension of up to
four months. Contractors are required to deliver a performance bond in the amount of US$1,000,000 from a well-known bank domiciled in
Jakarta during the Joint Study, to be submitted 14 days from the date the Director General approves the direct offer; to bear all the
costs, which generally range from US$500,000 to US$700,000, and risks in implementing the Joint Study; and to maintain the confidentiality
of data used and produced in the Joint Study. Upon completion of the Joint Study, the Director General may choose to announce a bidding
process for the working area, in which case the contractors who conducted the Joint Study will have the right to change their offer (right
to match) in the bidding process if the other bidders give higher offers, but otherwise receive no preferential treatment.
In
May 2018, we were awarded the rights to explore the Citarum Block by the MEMR through a direct tender process after a Joint Study in
the Citarum area was completed.
Cooperation
Contracts
“Cooperation
contract” is a general term used under the Oil & Gas Law to describe the contract between the contractor and the representative
of the Government which can be entered into by the parties in various forms, such as PSCs
(Production Sharing Contracts), TACs (Technical Assistance Contracts), and KSOs (Joint Operation Partnership).
Regardless of the form, the cooperation contracts essentially provide for production sharing arrangements. For example, title over resources
in the ground remains with the Government (and title to the oil and gas lifted for the contractor’s share passes at the point of
transfer, usually the point of export), ultimate management control is with SKK Migas, and capital requirements and risks are to be assumed
by the contractors. These cooperation contracts are to be entered into with SKK Migas and thereafter notified in writing to the Indonesian
Parliament. Only one working area will be given to any legal entity. Cooperation contracts can be made for a maximum term of 30 years
and can be extended for a maximum of 20 years. Cooperation contracts are divided into exploration and exploitation stages. The exploration
stage is for a term of six years, subject to only one extension for a maximum of four years.
The
implementation regulations for the upstream sectors, such as GR35/2004, reiterate the obligation by a contractor to offer a certain minimum
participating interest to domestic parties, such as regional government-owned enterprises, although the procedure for, and timing of,
offering such an interest has been modified. The MEMR has a right to request that a contractor who wishes to sell its participating interest
under a production sharing arrangement grants a right of first offer to national enterprises such as regional government-owned companies,
central government-owned companies, cooperatives, small scale businesses and Indonesian companies wholly-owned by Indonesians. Under
the existing upstream regulations, such an offer must be made on an “arms-length” basis. These modifications are applicable
only to the cooperation contracts entered into after the issuance of the Oil and Gas Law in 2001.
The
following principles provide the basis for all types of production sharing arrangements between the Government and private contractors:
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the
contractors are responsible for all investments and production costs (exploration, development, and production), including provision
of capital to implement the agreed work program; |
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the
operational risk in performing upstream activities under the contracts is borne by contractors; |
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the
profits are split between the Government and contractors based on production (the split depends on the fiscal terms adopted by the
PSCs, namely the cost-recovery model or the gross-split model); |
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the
ownership of all tangible and intangible assets remains with the Government; and |
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the
overall management and control remain with SKK Migas (previously BP Migas) on behalf of the Government. |
PSCs
(Production Sharing Contracts)
The
PSC is the most common type of production sharing arrangement. PSCs have been granted in respect of exploration properties and are awarded
for the exploration for oil and gas reserves and the establishment of commercial production of those resources.
Under
a PSC, the Government, through SKK Migas, allows one or more contractors to explore, develop, and produce oil and gas reserves and resources
in a designated working area. Accordingly, PSCs are entered into with SKK Migas and approved by the co-signature of the MEMR on behalf
of the Government. Each PSC is based on a standard form contract and typically contains provisions such as:
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the
requirement for the contractor to pay to the Government certain signature bonuses, yearly administrative fees, royalty payments,
production-level payments, and the payment of certain bonuses upon the achievement of certain production milestones for the working
area; |
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the
term of the initial exploration and development period, with an option for the parties to agree to extend this period; |
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the
obligations of the contractor to bear the risk and costs of exploration and development activities and/or production operations; |
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the
scope and schedule for the contractor (and any other operators of the working area) to undertake exploration and production activities; |
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save
for the gross-split PSCs (as discussed below), the ability of the contractor, if commercial production is successful, to recover
its exploration, development and production costs out of the oil and gas produced after deduction of the First Tranche Petroleum,
or FTP). The percentage of FTP portion is 10 percent of the oil and gas produced if the FTP is allocated entirely to the Government
or 20 percent if it is shared between the Government and the contractor in the same proportion as the percentage for profit sharing; |
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the
percentage allocation of total oil and gas production between BP Migas (now SKK Migas) and the contractor out of FTP and the following
recovery by the contractor of their costs; |
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the
requirement for the contractor to supply the Indonesian domestic market at a discounted price with a certain percentage, usually
25 percent, of the contractor’s share of total oil and gas produced (this is referred to as the domestic market obligation,
or DMO); |
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the
requirement that the title to petroleum at all times lies with the Government, except where the title to crude oil or gas has passed
in accordance with the provisions of the PSC; |
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the
obligation of the contractor to pay the Indonesian corporate taxes on its share of profits, including FTP; |
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the
requirements for the contractor to provide financial and performance guarantees to BP Migas (now SKK Migas) to secure the contractor’s
firm commitments; |
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the
requirements for the contractor to market the oil and gas produced; and |
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the
requirement (such as exists in our PSC for Citarum Block) for the contractor to relinquish specified percentages of the working area,
which are not required for production and/or in which hydrocarbons have not been discovered by specified times. |
Pursuant
to GR 35/2004, once the approval of the field development plan for first production from a working area has been received, contractors
are required to offer up to a 10 percent participating interest to a regional government-owned enterprise (Badan Usaha Milik Daerah).
In the event the regional government-owned enterprise does not accept such offer within 60 days after the offer, the contractor must
offer such participating interest to national enterprises such as regional government-owned companies, central government-owned companies,
cooperatives, small scale businesses, and Indonesian companies wholly-owned by Indonesians. If no such enterprise accepts the offer within
60 days of the offer being made, then the offering is closed.
The
MEMR issued MEMR Regulation No. 37 of 2016 on Terms of Bidding Participating Interest 10.0% in Oil and Gas Working Areas (known as the
MEMR Regulation 37/2016) which operates as the implementation regulations for the offering by the contractors of the 10 percent participating
interest in the oil and gas working areas to regional government-owned enterprises. MEMR Regulation 37/2016 restricts the right to bid
to regional government-owned enterprises which meet the following requirements (i) the entities must be incorporated either as a regional
company (commonly known as BUMD) with the shares wholly owned by the regional government, or as a limited liability company where at
least 99% of its shares are owned by regional government; (ii) their status of the regional government-owned enterprise was established
through the enactment of a local regulation; and (iii) their businesses are limited only to engage in participating interest management
business. Each regional government-owned enterprise can only hold participating interest management in one working area.
Where
a PSC involves more than one contractor, the contractors may enter into a joint operating agreement (or JOA) with the other holders of
participating interests under the PSC. Pursuant to this JOA, each participant agrees to participate in proportion to its respective equity
interest in all costs, expenses, and liabilities incurred in conjunction with petroleum operations in the working area and each participant
will own, in the same proportion, the contractual and operating rights in the PSC. One participant is appointed operator and, subject
to the terms of the operating agreement and supervision by the operating committee, which consists of one representative appointed by
each party, the operator is vested with the discretion to manage all petroleum operations in the working area. In doing so, the operator
is obliged to use its best efforts to conduct the petroleum operations in accordance with generally accepted practices in the petroleum
industry and receives an indemnity from the other contractors for acting in the capacity of operator. An operating agreement generally
continues in effect for the term of the PSC.
Extension
of PSCs
Pursuant
to the Oil and Gas Law and GR 35/2004, PSCs may be extended for a period of not more than 20 years for each extension. A contractor who
intends to extend its PSC must submit a request to the MEMR through SKK Migas. Then, SKK Migas evaluates the request and submits it to
the MEMR for consideration. A request for an extension of a PSC may be submitted no sooner than ten years and no later than two years
before the expiry date of the PSC. However, if the contractor has entered into a natural gas sales/purchase contract, such contractor
may request an extension of the PSC earlier than ten years prior to the expiry date of the PSC.
In
granting approval, the MEMR shall consider, among other things, the potential reserves of oil and/or gas from the work area concerned,
the potential or certainty of market/needs, and the technical/economic feasibility of the activities. Based on its consideration, the
MEMR may reject or approve such request.
PSC
Financial Terms
In
January 2017, a new production sharing regime of PSC, called “gross-split”, was introduced, while the previously introduced
“cost recovery” PSCs remain in place until the expiry of the relevant PSCs. Under the gross-split PSCs, the Government and
the contractor are allocated a “base split” of oil or gas production, where the split percentage will be adjusted by certain
components set out in the PSC. In contrast with the gross-split PSCs where production sharing is done at the beginning, without production
being allocated towards recovery of the contractor’s operating costs first, the cost recovery PSCs provide for production to be
shared between the Government and the contractor through a “cost recovery” mechanism. After the production is reduced by
certain costs and deductibles, the remaining oil or gas will then be split between the Government and the contractor based on the agreed
percentage set forth in the PSC.
We
are a party to the gross-split PSC with respect to our operations in Citarum Block. Financial terms of our PSC are described above under
“—Our Assets—Citarum Block.” Further details on the gross-split and cost recovery
PSCs are set out below.
Gross-Split
PSCs
In
January 2017, a new fiscal regime was introduced by MEMR where gross production of oil and gas is to be divided between the contractor
and the Government based on certain percentages in respect of (a) the crude oil production and (b) the natural gas production. This mechanism
is known as “gross split”. Under the gross split sharing concept, the starting point for determining the relevant percentage
of the contractor’s share is the “base split” percentage, which will then be adjusted upon the plan
of development approval according to the “variable components” and “progressive components”.
In short, the contractor’s share equals to the “base split” plus or minus the “variable components” plus
or minus “progressive components”.
The
base split, pursuant to the MEMR Regulation No. 08 of 2017 (MEMR 08/2017) as amended by the MEMR Regulation No. 52 of 2017 and lastly
by the MEMR Regulation No. 20 of 2019 (MEMR 20/2019), is currently set at, for gas, 52% for the Government and 48% for the contractor
and for oil, 57% for the Government and 43% for the contractor. The percentage of variable components is determined based on, among others,
the status of the work area, the field location, reservoir, supporting infrastructure, carbon dioxide and hydrogen sulfide content and
compliance with local content requirements. The latest percentage of each variable component is detailed in the schedule to the MEMR
20/2019. For the progressive components, the adjustment is made by taking into account oil price, gas price and the cumulative oil and
gas production. Current details on the split adjustment based on the progressive components are provided for in the MEMR 20/2019.
The
concerns over the new Gross Split PSC introduced in 2017 may be relieved with issuance of Ministry of Energy and Mineral Resources (or
MoEMR) Regulation No. 12/2020 in July 2020 which opens the door to oil and gas investors to elect to use the previous conventional cost
recovery scheme, that is perceived to provide better investment returns. However, the oil and gas landscape both in Indonesia and globally
has only worsened due to the COVID-19 pandemic which has significantly reduced energy demand and consequently hydrocarbon prices. With
all those negative conditions, SKK Migas in June 2020 launched a comprehensive reforms initiative with a goal to achieve production of
one million barrels of oil per day (BOPD) and 12 billion standard cubic feet per day (Bscfd) of gas production by 2030.
Depending
upon the particular oil and gas field and related economic considerations, the MEMR may adjust the split in favor of either the contractor
or the Government. The gross split is calculated based on gross production split, without regard to the cost recovery approach. Contractors
who have entered into the PSCs prior to the issuance of MEMR No. 08/2017 may propose to amend the sharing mechanism under their existing
PSCs to the gross split mechanism. The latest iteration of the gross-split PSCs fiscal terms are provided for in Government Regulation
No. 53 of 2017, promulgated on 28 December 2017, regarding the Tax Treatment for the Upstream Oil and Gas Activities with Gross-Split
Production Sharing Contracts (GR 53/2017). Key points of GR 53/2017 include:
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“taxable
income” is to be the contractor’s “gross income” less “operating costs” but with a 10 year tax
loss carry forward entitlement; |
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the
gross split taxing point begins at the “point of transfer” of the relevant hydrocarbon to the contractor; |
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the
value of oil is to be determined using the Indonesian Crude Price and that the value of gas is to be determined via the price agreed
under the relevant gas sales contract; |
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income
separately arising from “uplifts” is subject to tax at a final rate of 20% of the uplift amount; |
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certain
tax facilities or incentives may be given to the contractors from the exploration and exploitation stages up to the commencement
of commercial production. Such incentives are, amongst other things, the exemption of import duties on the import of goods used in
petroleum activities and the deduction of land and building tax amounting to 100 percent of the land and building tax payable amount.
Further provisions regarding the
granting of facilities will be regulated by a ministerial regulation, which, to date, has not been issued. |
Cost
Recovery PSCs. Until 2017, all Indonesian PSCs adopted the “cost-recovery” concept and their fiscal terms reflects such
a concept, the “cost recovery” approach requires the contractor to, among other things, prepare work program and budget which
needs to be approved by SKK Migas and submit a request for approval for expenditure (or AFE) prior to performing a certain activity.
Under this scheme, a waterfall mechanism is used in the sharing of the oil/gas production between the contractor and the Government –
the oil/gas production will be deducted by, first, the FTP and then tax and subsequently, the (approved) cost recovery amount. The remaining
oil/gas will then be split between the Government and the contractor based on the agreed percentage set forth in the PSC.
The
following flow chart of the cost-recovery PSC illustrates the sharing of oil and gas production between the Government and the contractor.
The
latest iteration of the cost-recovery PSCs fiscal terms is found in Government Regulation No. 27 of 2017 on the Amendment of Government
Regulation No. 79 of 2010 on the Operating Costs that May Be Recovered and Income Tax Treatment for Upstream Oil and Gas Activities (or
GR 27/2017, which amended GR 79/2010). GR 27/2017, which came into effect on June 19, 2017, regulates the costs that cannot be
recovered in the calculation of profit sharing and income tax. Such costs include costs incurred for the personal interests of the participating
interest holders, penalties imposed due to violations of any laws by the contractor, depreciation costs, legal consultant (which is not
directly related to the oil and gas operation activities) and tax consultant fees, and bonuses payable to the Government. GR 27/2017
also regulates the income tax applicable to the transfer of participating interests and any other activities conducted by PSCs, and requires
the contractor to have its own tax identification number.
The
provisions of GR 27/2017 only apply to contracts entered into and extensions of contracts after the issuance of GR 27/2017. Additionally,
for contracts in existence up to the issuance of GR 79/2010 to remain in force until their expiration date, they must be adjusted to
comply with GR 27/2017 in areas not previously or not sufficiently clearly regulated. Such provisions include provisions related to:
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the
Government’s interest in the PSC; |
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the
terms for operating costs which can be recovered and the standard norms for operating costs; |
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non-recoverable
operating costs; |
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third-party
appointments to conduct financial and technical verification; |
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the
issuance of income tax assessments; |
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import
duties and import tax exemptions on the importation of goods for exploration and exploitation activities; |
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contractors’
income taxes in the form of oil and/or gas volume from contractor entitlement; and |
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income
from outside the contract in the form of uplift and/or participating interest transfer, must be adjusted to comply with GR 27/2017. |
The
implementing regulations for GR 79/2010 and GR 27/2017 cover various subjects, from the method for determining the Indonesian Crude Price
issued by the MEMR, the terms and conditions for indirect head office cost recovery, procedures for withholding and remitting income
tax arising from other income in the form of uplift or other similar compensation and contractor’s income from participating interest
transfer, to subjects such as the maximum remuneration that can be cost recovered by the contractor issued by the Indonesian Minister
of Finance (or MoF).
GR
79/2010, the provisions of which are maintained in GR 27/2017, also stipulates that income arising from a direct or indirect transfer
of a participating interest is subject to a final income tax at 5.0 percent or 7.0 percent of the gross proceeds for the exploration
stage or exploitation stage, respectively. Subject to satisfying certain requirements, a transfer of a risk-sharing participating interest
during the exploration stage is not included as a taxable participating interest transfer.
MoF
Regulation No. 257/PMK.011/2011 dated December 28, 2011 (or MoF 257/2011) further stipulates that taxable income, after deduction of
final income tax on uplift and/or participating interest transfer, is subject to branch profit tax in accordance with the income tax
law. GR 27/2017 has introduced tax facilities that exempt such taxable income, after deduction of final income tax on uplift and/or participating
interest transfer, from branch profit tax. However, it remains unclear whether these tax facilities can be applied to the participating
interest transfer in relation to PSCs entered into or extended prior to the enactment of GR 27/2017. In addition, although technically
GR 27/2017 should override the contents of MoF 257/2011, it is uncertain whether another implementing regulation is needed to revoke
MoF 257/2011.
With
regards to land and building tax, under the Regulation of Director General of Tax No. PER-45/PJ/2013, effective as of January 1, 2014
(or DGT Regulation 45/2013), the land and/or buildings located within and outside (i.e., the supporting area for the oil and gas mining
activity that physically forms an inseparable part of the onshore and offshore area) the working area utilized for oil and gas mining
activities and geothermal was subject to land and building tax. DGT Regulation 45/2013 defines “land” as both the onshore
and offshore areas, including depth measurements. The onshore area which was subject to land and building tax included the productive,
not yet productive, not productive, and emplacement areas while the offshore area which was subject to land and building tax was defined
as offshore waters within and outside (i.e., the supporting area for the oil and gas mining activity that physically forms an inseparable
part of the onshore and offshore area) the working area utilized for upstream oil and gas business activities, whereby the taxpayer had
rights and/or received benefits over such area. Not all onshore and offshore areas were subject to land and building tax as the regulation
exempted land, inland waters, and offshore waters within the working area which, among other things, did not create a benefit for the
taxpayer in respect of its oil and gas activities. DGT Regulation 45/2013 also provided the formula for calculating the amount of tax
to be paid during the exploration and exploitation periods.
However,
on November 27, 2020, the Directorate General of Tax issued Regulation of Directorate General of Tax No. PER-22/PJ/2020 of 2020 (or DGT
Regulation 22/2020), which revokes 10 regulations, including DGT Regulation 45/2013, in an attempt to simplify the regulations. However,
it is not entirely clear how the revocation of DGT Regulation 45 of 2013 would affect the obligations to pay land and building tax in
the oil and gas sectors, including on how the tax is to be assessed.
On
December 31, 2014, the MoF issued Regulation Number 267/PMK.011/2014 on Land and Building Tax Reduction for Oil and Gas Mining at the
Exploration. This regulation, which became applicable in 2015, grants land and building tax incentives for the subsurface at the exploration
stage. The tax reduction incentive can be granted on a yearly basis for a maximum of six years from the signing of the PSC and can be
extended by up to four years and can be obtained if the PSC with the Government is signed after the enactment of GR 79/2010 (i.e., after
December 20, 2010), the Tax Object Notification Form (Surat Pemberitahuan Objek Pajak, or SPOP) has been submitted to the relevant
tax office, and there is a recommendation letter from the MEMR attached to the SPOP stating that the land and building tax object is
still at the exploration stage.
GR
27/2017 also provides for complete exemptions of land and building tax during the exploitation and exploration period. Exemptions for
the land and building tax during exploitation period for the subsurface part can be granted by the MoF upon consideration of economics
of the project. The provisions of GR 27/2017 on tax facilities related to land and building tax are subject to further regulation by
the MoF. GR 27/2017 extended the benefits of the facilities under the regulation to parties to PSCs signed or extended prior to the application
of the regulation if they chose to adjust the existing contract to fully comply with the regulation within six months after the effective
date (i.e., by December 19, 2017).
TACs
(Technical Assistance Contracts)
TACs
are another form of production sharing arrangement created under the regulatory framework that preceded the Oil and Gas Law of 2001.
TACs were awarded for fields having prior or existing production and are valid for a specified term. The oil or gas production is divided
into non-shareable and shareable portions. The non-shareable portion represents the production which is expected from the field (based
on historic production) at the time the TAC is signed. Under a TAC, the non-shareable portion declines annually. The shareable portion
corresponds to the additional production resulting from the operator’s investment in the field and is further split in the same
way as a PSC. Pursuant to the Oil and Gas Law of 2001 and GR35/2004, existing TACs shall remain with Pertamina and are not renewable
after the expiry of the initial term. In practice, the contractors may “renew” their TAC contracts with Pertamina by entering
into the KSOs with Pertamina EP.
Our
Kruh Block operatorship was under a TAC until May 2020, under which we were entitled to recover our share of past exploration and development
costs and ongoing production costs of maximum 65% per annum and if those costs exceed the stated 65%, then the unrecovered surplus would
be recovered in the succeeding years. Together with our share split, our monthly revenue was around 74% of the total production times
Indonesian Crude Price during the TAC term. In May 2020, our Kruh Block operatorship was “renewed” under a KSO for an additional
10 years.
JOBs
(Joint Operating Bodies)
JOBs
are another form of production sharing arrangement created under the regulatory framework that preceded the Oil and Gas Law of 2001.
In a JOB, operations are conducted by a JOB headed by Pertamina and assisted by one or more private sector energy companies through their
respective secondees to the JOB. In a JOB, Pertamina is entitled to a specified percentage of the working interest in the project. The
balance, after production is applied towards cost recovery and cost bearing as between Pertamina and the private sector participants,
is the shareable portion which is generally split in the same way as for an ordinary PSC. Unlike TACs, GR35/2004 transferred the rights
to operations under existing JOBs from Pertamina to SKK MIGAS by law. JOBs are not renewable after the expiry of their initial term.
We
are not currently a party to any JOBs.
KSOs
(Kerja Sama Operasi or Joint Operation Partnership)
KSOs
are contractual arrangement between Pertamina EP and the contractor on the provision of technical assistance by the contractor to Pertamina
EP for a certain work area. Unlike the cooperation contracts, the KSO does not create a contractual relationship between the contractor
and the authority, i.e. BP Migas or SKK Migas. The contractors will have a contractual relationship with Pertamina EP instead. Pertamina
EP’s authorization to award the KSOs to contractors is stated in the PSC which Pertamina EP entered into with BP Migas (now SKK
Migas) in 2005. The terms of such PSC specify, among other things, that:
|
● |
the
KSO must first be reviewed by SKK Migas; |
|
|
|
|
● |
the KSO contractor will receive compensation from a portion of the oil and gas entitlement of Pertamina EP under its PSC with BP Migas (now SKK Migas); |
|
|
|
|
● |
the
compensation given to the KSO contractor shall not exceed the production sharing entitlement of other parties who enter into a cooperation
contract with BP Migas (now SKK Migas) in the surrounding area; and |
|
|
|
|
● |
the
compensation given to the KSO contractor may be sourced from the proceeds of Pertamina EP’s entitlement which is calculated
at the delivery point pursuant to the terms of the
KSO. |
Environmental
Regulations
Indonesian
law requires companies whose operations have a significant environmental or social impact to create and maintain one of two documents.
Where a company’s operations meet or exceed a specified threshold, that company must obtain an Environmental Impact Assessment
Report (Analisis Mengenai Dampak Lingkungan, or AMDAL). Minister of Environment and Forestry Regulation No. P.38/MENLHK/SETJEN/KUM.1/7/2019
of 2019 on Types of Business Plan and/or Activities Requiring an Environmental Impact Assessment requires companies whose operations
involve the exploitation of oil and gas; pipelines of oil and gas under the sea; the construction of oil refineries, LPG refineries,
or LNG refineries; the regasification of LNG; lubricating oil refineries; and coal bed methane field development, and whose operations
meet the environmental or social impact threshold, to create and maintain an AMDAL. Where operations do not reach the threshold required
for an AMDAL but still have an appreciable environmental or social impact the company must prepare an Environmental Management Effort-Environmental
Monitoring Effort (Upaya Pengelolaan Lingkungan Hidup dan Upaya Pemantauan Lingkungan Hidup, or UKL-UPL).
There
are a number of other key obligations that companies involved in upstream oil and gas may be required to fulfill in order to monitor
their environmental impact and ensure adequate resources are allocated to cleanup activities. GR 22/2021 requires business actors to
submit reports detailing their disposal of wastewater and compliance with applicable regulations to the Environmental Information System,
a newly established system to support environmental protection operations and management. Government Regulation 101 of 2014 on Management
of Hazardous and Toxic Waste Materials and Government Regulation No. 74 of 2001 on Management of Hazardous or Toxic Materials (Bahan
Berbahaya dan Beracun), require companies using or producing specified hazardous materials such as flammable, poisonous, or infectious
waste to obtain a revocable permit in relation to their activities and subjects mining operations to controls on the disposal of such
materials. Law No. 32 of 2009 on Environment requires the environmental license holder to create an environmental deposit fund for the
restoration of the environment in a state-owned bank appointed by the MEF, Governor, Regent, or Mayor in accordance with their authority,
who also has the authority to appoint a third party to conduct the restoration of the environment using the environmental deposit fund
(this is to be detailed in an implementing regulation, which to date has not been issued). GR 35/2004 also requires contractors to allocate
environmental deposit funds for the restoration of the environment after decommissioning, the amount of which is to be determined each
year in conjunction with the budgets for operating costs and included in the work program and annual budget.
In
addition to the environmental deposit funds allocated for environmental restoration, on February 23, 2018 the MEMR issued MEMR Regulation
No. 15 of 2018 on the Post-Operation Activities in Upstream Oil and Gas Business Activities (or MEMR Regulation 15/2018), which requires
all contractors who are parties to an unexpired PSC to set aside certain amounts in an abandonment and site restoration (ASR) fund deposited
in a bank account held jointly with SKK Migas from the start of commercial operations until the expiry of the PSC. Moreover, on September
12, 2018, SKK Migas issued the Guidance of Abandonment and Restoration No.KEP-0087/SKKMA0000/2018/S0 of 2018 and Working Procedure Guidelines
No. PTK-040/SKKMA0000/2018/S0 (or the Restoration Guidance) as guidance for the implementation of abandonment and site restoration (or
ASR) activities for upstream oil and gas business activities. Under the Restoration Guidance, the contractor must prepare an ASR report
in relation to existing assets, assets being constructed, and assets that will be constructed in accordance with the development plan
that must contain estimates of ASR costs, and the total amount to be reserved as an ASR fund which is to be established with a reputable
Indonesian bank as a joint account with SKK Migas. The contractor must also submit a report on the results of the implementation plan
as well as the use of the ASR fund after completing its ASR activities to SKK Migas, which will evaluate the report submitted and issue
a statement letter confirming completion of the ASR if the evaluation result is satisfactory.
We
believe we are in compliance in all material respects with all applicable environmental laws, rules and regulations in Indonesia.
Labor
Regulations Applicable to the Indonesian Oil and Gas Sectors
Save
for certain limited exceptions, such as the working hours for the oil and gas sector discussed below, there are currently very few manpower
regulations enacted specifically for the oil and gas industry. While certain operational guidelines, commonly known as “PTK”,
issued by SKK Migas may establish additional requirements, such as age limitation for certain key positions, the oil and gas industry
is subject to the labor regulations that are applicable generally in Indonesia.
Employment
of Expatriates
Indonesian
law generally requires contractors to give preference to local workers, but companies may use foreign manpower to bring in expertise
not available in the local market. While several ministries are involved legally with manpower decisions, in practice SKK Migas often
coordinates these issues, including controls on the number of expatriate positions. It reviews these positions, as well as contractor
training programs for Indonesian workers, annually with a view to assessing the costs and benefits together with plans to localize expatriate
positions. SKK Migas also requires contractors to submit organization charts for both nationals (known as RPTKs) and expatriates (known
as RPTKAs) annually for review and approval.
Until
recently, the employment of foreign manpower in the upstream and downstream sectors of the oil and gas industry was subject to additional
requirements under MEMR Decree No. 31 of 2013 on Expatriate Utilization and the Development of Indonesian Employees in the Oil and Gas
Business (or MEMR Decree 31/2013). MEMR Decree 31/2013 provided stringent regulations on the employment of expatriates, including a general
obligation to prioritize the employment of Indonesian workers and specific prohibitions on hiring foreign manpower for certain roles
such as human resources, legal, quality control, and exploration and exploitation functions below the level of superintendent. MEMR Decree
31/2013 also permitted the use of foreign manpower in limited circumstances based on a stringent set of requirements such as age, relevant
work experience, and willingness to transfer knowledge to the local workforce.
However,
on February 8, 2018 the MEMR issued MEMR Regulation No. 6 of 2018 on the Revocation of the Regulations of the Minister of Energy and
Mineral Resources, the Regulations of the Minister of Mining and Energy Regulations, and the Decisions of the Minister of Energy and
Mineral Resources (or MEMR 6/2018). MEMR Regulation 6/2018 revokes 11 regulations which were deemed onerous in an attempt to, among other
things, simplify the regulations in order to promote foreign investment in the energy and natural resources sectors. Among other things,
MEMR Regulation 6/2018 revokes MEMR Decree 31/2013 and the Regulation of the Minister of Mining and Energy No. 02/P/M/Pertamb/1975 regarding
the Work Safety on Distribution Pipes and other Facilities for the Transportation of Oil and Gas Outside of the Oil and Gas Working Area.
As a result, expatriates are now subject to the Ministry of Manpower’s more relaxed requirements and certain positions that were
previously restricted for expatriates have been opened for expatriates unless restricted under the general manpower regulations.
Contract
Period
Law
No. 13 of 2003 on Manpower, as amended by the Omnibus Law (or the Manpower Law), and Government Regulation No. 35 of 2021 on Temporary
Employment Contract, Outsourcing, Working and Resting Time, and Termination of Employment Relationship (or GR 35/2021) stipulate that
an employee can be hired under 2 schemes, either on a contract basis (temporary) or a permanent basis. For temporary employment contracts,
the maximum period for the temporary employment contract is 5 years. Under the Manpower Law, temporary employment contracts are permitted
only for works that are “temporary” in nature, such as seasonal works (e.g. crop harvesters) and project-based employments,
such as construction works. Save for these types of works, workers are required to be employed on a permanent basis.
Statutory
Benefits
Under
Law No. 24 of 2011 on Social Security Administrative Bodies (or BPJS Law), a company is obligated to enroll its employees (including
expatriates with an employment period of 6 months or more) for manpower social security programs with the Manpower Social Security Administrative
Body (or BPJS Ketenagakerjaan) and Health Social Security Administrative Body (or BPJS Kesehatan). The coverage of BPJS Ketenagakerjaan
includes, among other things, insurance for work-related accidents and pension/retirement. The premium payment arrangement for these
programs vary from one program to the other. The insurance premiums for the work-related accidents, for example, is borne and paid by
the employer while the premium payment for retirement insurance is shared between the employers and the employees.
Working
Hours
The
Manpower Law and the Minister of Manpower and Transmigration Regulation No. 4 of 2014 on Working and Resting Hours for the Oil and Gas
Sector and GR 35/2021 regulate that the maximum working hours for 1 week is 40 hours, which can be divided for 5 or 6 days of work. If
the working days in a week is 6, the maximum working hours per day is 7 and if the working days in a week is 5, the maximum working hours
per day is 8.
Outsourcing
Pursuant
to the Regulation of the Minister of Manpower and Transmigration No. 19 of 2012 on Requirements for Assignment of Parts of the Works
to be Performed by Other Companies (or MoMT 19/2012), in general, a company may outsource a third party to perform certain work if such
work is not the core activity of the company’s business. MoMT 19/2012 provides for two type of outsourcing schemes, namely “labor
supply” scheme or “sub contract” scheme.
Under
the “labor supply” scheme, works that may be outsourced are limited to menial activities or functions that are supportive
in nature to the company’s operation and businesses or are indirectly related to the company’s production process. These
activities are limited to (i) cleaning services, (ii) catering services, (iii) security services, (iv) supporting services in the mining
and oil sectors, and (v) transportation service for employees (i.e. drivers for company’s cars only for picking up and delivering
employees).
Under
the “sub-contract” scheme or “cooperation” scheme, the outsourced functions must not be the “core”
or the “main” business activities of the company. In addition, to be able to adopt the “cooperation scheme”,
the company is required to prepare and register its business “flow-chart” with the relevant manpower office. Please note
that to register such “flow-chart”, the company must apply and become a member at one of the business associations (whose
members have identical business activities with the company) as the registration would need to be processed through such business association.
Failure to meet any of these requirements will usually result in the issuance an order issued by the Ministry of Manpower to the violating
company instructing such company to employ the “outsourced” personnel as a permanent employee with a retroactive effect.
Other
Labor Compliance Obligations
Under
Law No. 8 of 1981 on Mandatory Manpower Report, an employer is obligated to submit a mandatory manpower report consisting of among others
the number of employees and the lowest to highest salary. In addition, the Manpower Law also requires a company that employs at least
10 employees to put in place a company regulation (or an employee handbook), which typically set forth general terms and conditions of
employment such as number of leaves, procedure to take leave, working hours and disciplinary measure. Such company regulation must be
registered with and ratified by the local manpower office. If there is a labor union in the company, the employer and the labor union
may enter into a “collective labor agreement” which contents are often similar with the company regulation, and register
the collective labor agreement with the local Manpower Office. If the employer and the labor union enter into a collective labor agreement,
the preparation of company regulation by the company is not mandatory. We are not a party to any collective labor agreement.
History
and Corporate Structure
We
were incorporated on April 24, 2018 as a holding company for WJ Energy, which in turn owns our Indonesian holding and operating subsidiaries.
We presently have two major shareholders, Maderic and HFO, which own 68.29% and 8.47%, respectively, of our
issued and outstanding ordinary shares. Certain of our officers and directors or their family members own and control Maderic or HFO
(see “Principal Shareholders”).
WJ
Energy was incorporated in Hong Kong on June 3, 2014. The initial shareholders of WJ Energy were Maderic and HFO, with each owning 50%
of WJ Energy’s shares. On October 20, 2014, HFO received HKD 4,000 from Maderic as consideration for 4,000 shares in WJ Energy,
which resulted in Maderic owning 90% of WJ Energy and HFO owning 10%.
On
February 27, 2015, WJ Energy formed GWN as a vehicle to acquire and thereafter operate the Kruh Block. On March 20, 2017, PT Harvel Nusantara
Energi, an Indonesian limited liability company (or HNE), was formed by WJ Energy as a required vehicle for oil and gas block acquisitions
in compliance with Indonesian law.
On
June 26, 2017, Maderic sold 500 shares of WJ Energy to HFO in consideration of HKD 500. Concurrently, Maderic sold 1,500 shares of WJ
Energy to Opera Cove International Limited, an unaffiliated third party (or Opera), in consideration of HKD 1,500. At the end of such
transactions, the outstanding shares of WJ Energy were owned 70% by Maderic, 15% by HFO and 15% by Opera. On June 25, 2017, Maderic and
Opera executed an entrustment agreement giving Maderic legal and beneficial ownership of the shares held by Opera.
On
December 7, 2017, PT Cogen Nusantara Energi, an Indonesian limited liability company, was formed under HNE as a required vehicle for
the prospective acquisition of a new oil and gas block through a Joint Study program in consortium with GWN. On May 14, 2018, PT Hutama
Wiranusa Energi, was formed under GWN as a requirement to sign the contract for the acquisition of Citarum Block as part of the consortium
that conducted the Joint Study for the Citarum Block.
On
June 30, 2018, we entered into two agreements with Maderic and HFO (the two then shareholders of WJ Energy): a Sale and Purchase of Shares
and Receivables Agreement and a Debt Conversion Agreement (which we refer to collectively as the Restructuring Agreements). The intention
of the Restructuring Agreements was to restructure our capitalization in anticipation of our initial public offering which was concluded
in December 2019. As a result of the transactions contemplated by the Restructuring Agreements: (i) WJ Energy (including its assets and
liabilities) became a wholly-owned subsidiary of our company, (ii) loans amounting to $21,150,000 and $3,150,000 that were owed by WJ
Energy to Maderic and HFO, respectively, were converted for nominal value into ordinary shares of our company and (iii) we issued an
aggregate of 15,999,000 ordinary shares to Maderic and HFO. The above mentioned transaction is accounted for as a nominal share issuance
(which we refer to as the Nominal Share Issuance). All number of shares and per share data presented in this prospectus have been retroactively
restated to reflect the Nominal Share Issuance.
This
series of transactions resulted in the then ownership of our company prior to our initial public offering to be set at 87.04% owned by
Maderic (13,925,926 ordinary shares), and 12.96% owned by HFO (2,074,074 ordinary shares), out of a total of 16,000,000 issued ordinary
shares.
On
November 8, 2019, we implemented a one-for-zero point three seven five (1 for 0.375) reverse stock split of our ordinary shares by way
of share consolidation under Cayman Islands law (which we refer to herein as the Reverse Stock Split). As a result of the Reverse Stock
Split, the total of 16,000,000 issued and outstanding ordinary shares prior to the Reverse Stock Split was reduced to a total of 6,000,000
issued and outstanding ordinary shares. The purpose of the Reverse Stock Split was for us to be able to achieve a share price for our
ordinary shares consistent with the listing requirements of the NYSE American. Any fractional ordinary share that would have otherwise
resulted from the Reverse Stock Split was rounded up to the nearest full share. The Reverse Stock Split maintained our founding shareholders’
then percentage ownership interests in our company at 87.04% owned by Maderic (5,222,222 ordinary shares) and 12.96% owned by HFO (777,778
ordinary shares), out of a total of 6,000,000 issued ordinary shares. The Reverse Stock Split also increased the par value of our ordinary
shares from $0.001 to $0.00267 and decreased the number of authorized ordinary shares of our company from 100,000,000 to 37,500,000 and
authorized preferred shares from 10,000,000 to 3,750,000.
As
of the date of this prospectus, Maderic owns 68.29% of our issued and outstanding shares, while HFO owns approximately 8.47%
of our issued and outstanding shares. As of the date of this prospectus, we have 7,647,214 ordinary shares issued and outstanding.
The
following diagram illustrates our corporate structure, including our consolidated holding and operating subsidiaries, as of the date
of this prospectus:
Not
reflected in the above is that, for purposes of compliance with Indonesian law related to ownership of Indonesian companies: (i) WJ Energy
owns 99.90% of the outstanding shares of GWN and HNE, and (ii) GWN and HNE each own 0.1% of the outstanding shares of the other; and
(iii) GWN owns 99.50% of the outstanding shares of HWE, and the remaining 0.50% is owned by HNE; and (iv) HNE owns 99.90% of the outstanding
shares of CNE, and the remaining 0.10% is owned by GWN.
Recent
Developments -- Drilling and Production at the Kruh Block
With
respect to our drilling program at Kruh Block, in March 2021 we announced our plan to drill a total of 5 wells in 2021, 6 wells in 2022
and 7 wells in 2023, for a total of 18 new wells on Kruh Block. Due to delays in the Government permitting process and COVID-19-related
delays experienced during 2021, our overall drilling program for Kruh Block has similarly been somewhat delayed. We still plan on drilling
18 new wells through 2024, we completed the drilling of 2 of those wells in 2021 (with the additional 16 more wells during the course
of 2022 to 2024.
We
commenced the drilling of a well named “Kruh 25” on Sumatra Island on April 21, 2021 and another one named “Kruh 26”
on the same island on August 22, 2021. We discovered oil in both wells and our production rate increased by over 50% from approximately
160 barrels of oil per day during the first 10 months of 2021 to approximately 245 barrels of oil per day as of late December 2021, as
a result of the recently completed Kruh 26 well on its 63,000-acre Kruh Block.
We
recently provided an update on our 2022 drilling plans by announcing that we expected to commence drilling of our next 2 new wells at
our 63,000-acre Kruh Block in the first quarter of 2022. Additionally; we plan to commence drilling of a third new well at Kruh Block
before the end of the second quarter of 2022. Drilling operations for these three new wells (named “Kruh 27”, “Kruh
28” and “Kruh 29”) are being funded from the net proceeds of our January 2022 institutional investor financing.
L1
Capital Financing
On
January 21, 2022 (the “Initial Closing Date”), we closed an initial $5.0 million tranche (the “First Tranche”)
of a total anticipated $7.0 million private placement with L1 Capital Global Opportunities Master Fund, Ltd. ( “L1 Capital”)
pursuant to the terms of Securities Purchase Agreement, dated January 21, 2022, between L1 Capital and us (the “Purchase Agreement”).
In
connection with the closing of the First Tranche, we issued to L1 Capital (i) a 6% Original Issuance Discount Senior Convertible Note
in a principal amount of up to $7,000,000 (as described further below, the “Note”) and (ii) a five year Ordinary Share
Purchase Warrant (the “Initial Warrant”) to purchase up to 383,620 of our ordinary shares at an exercise price of $6.00 per
share, subject to adjustment.
Within
two (2) trading days of the declaration of effectiveness of the Registration Statement of which this prospectus forms a part, and subject
to the satisfaction of certain conditions precedent, a second tranche of funding under the Note (the “Second Tranche”) shall
be provided by L1 Capital in the principal amount of $2,000,000. Such principal amount, if funded, will be added to the principal amount
of the Note, and L1 Capital will be entitled to receive an additional Ordinary Share Purchase Warrant (carrying the same terms as the
Initial Warrant) (the “Second Warrant” and collectively with the Initial Warrant, the “Warrants”) to purchase
up to 153,450 ordinary shares, if the full amount of the Second Tranche is funded, at an exercise price of $6.00 per share, subject to
adjustment.
The
amount of the Second Tranche, and the corresponding number of ordinary shares underlying the Second Warrant, is subject to reduction
if the principal amount of the Note (after funding the Second Tranche) would be less than 25% of our then current market capitalization
at that time.
EF
Hutton, division of Benchmark Investment, LLC, acted as exclusive placement agent for the offering and received customary fees.
Amendments
to Employment Agreements
On
January 21, 2022, we entered into a Second Amendment to Employment Agreement (the “Ingriselli Second Amendment”) with Frank
C. Ingriselli, our President. The effective date of the Ingriselli Second Amendment is January 1, 2022. The Ingriselli Second
Amendment amends that certain Employment Agreement between Mr. Ingriselli and us, effective February 1, 2019, as amended by that certain
First Amendment to Employment Agreement, effective as of February 1, 2020 (the “Ingriselli Agreement”).
Pursuant
to the Ingriselli Second Amendment: (i) the term of the Ingriselli Agreement was extended to December 31, 2023, unless terminated earlier
pursuant to the terms of the Ingriselli Agreement; and (ii) Mr. Ingriselli was granted an award of 60,000 ordinary shares, with 30,000
shares vesting on July 1, 2022 and 30,000 vesting on January 1, 2023, with a lock-up period of 180 days from each vesting date.
On
January 21, 2022, we entered into a Second Amendment to Employment Agreement (the “Overholtzer Second Amendment”) with Gregory
Overholtzer, our Chief Financial Officer. The effective date of the Overholtzer Second Amendment is January 1, 2022. The Overholtzer
Second Amendment amends that certain Employment Agreement between Mr. Overholtzer and us, effective February 1, 2019, as amended by that
certain First Amendment to Employment Agreement, effective as of February 1, 2020 (the “Overholtzer Agreement”).
Pursuant
to the Overholtzer Second Amendment, the term of the Overholtzer Agreement was extended to December 31, 2023, unless terminated earlier
pursuant to the terms of the Overholtzer Agreement.
No
further changes were made to either the Ingriselli Agreement or the Overholtzer Agreement.
The
foregoing description of the Ingriselli Second Amendment and the Overholtzer Second Amendment is a summary only and does not purport
to be complete and, is qualified in its entirety by reference to the full text of such documents, the forms of which is attached as Exhibit
10.5 and 10.6 tour Current Report on Form 6-K, filed with the SEC on January 25, 2022, respectively, and incorporated herein by reference.
Corporate
Information
Our
principal executive offices are located at GIESMART PLAZA 7th Floor, Jl. Raya Pasar Minggu No. 17A, Pancoran – Jakarta 12780 Indonesia.
Our telephone number at this address is +62 21 2696 2888. Our registered office in the Cayman Islands is located at Ogier Global (Cayman)
Limited, 89 Nexus Way, Camana Bay, Grand Cayman, Cayman Islands. Our web site is located at www.indo-energy.com. The information
contained on our website is not incorporated by reference into this prospectus, and the reference to our website in this prospectus is
an inactive textual reference only.
MANAGEMENT
Directors
and Executive Officers
The
following table sets forth information regarding our executive officers and directors as of the date of this prospectus.
Name |
|
Age |
|
Position/Title |
Dr.
Wirawan Jusuf |
|
36 |
|
Director,
Chairman of the Board and Chief Executive Officer |
Frank
C. Ingriselli |
|
67 |
|
President |
Chia
Hsin “Charlie” Wu |
|
69 |
|
Chief
Operating Officer |
Mirza
F. Said |
|
56 |
|
Chief
Business Development Officer and Director |
James
J. Huang |
|
34 |
|
Chief
Investment Officer and Director |
Gregory
L. Overholtzer |
|
65 |
|
Chief
Financial Officer |
Mochtar
Hussein |
|
63 |
|
Independent
Director |
Benny
Dharmawan |
|
39 |
|
Independent
Director |
Tamba
P. Hutapea |
|
63 |
|
Independent
Director |
Michael
L. Peterson |
|
60 |
|
Independent
Director |
Dr.
Wirawan Jusuf is a co-founder, Chief Executive Officer and Chairman of the board of directors of our company, and has served
as the Chief Executive Officer of WJ Energy since 2014. Since 2015, Dr. Jusuf has also served as a co-founder and Commissioner of Pt.
Asiabeef Biofarm Indonesia, a fully integrated and sustainable cattle business company in Indonesia. Dr. Jusuf also serves as the Director
of Maderic Holding Limited, a private investment firm and our majority shareholder, which he founded in 2014. Dr. Jusuf began his professional
career when he co-founded and served as the Director of Pt. Wican Indonesia Energi, an oil and gas services company, from 2012 to 2014.
Dr. Jusuf earned his Master’s in Public Health at the Gajah Mada University-Jogjakarta in Central Java, Indonesia, and his medical
degree at the University of Tarumanegara in Jakarta, Indonesia beforehand. We believe Dr. Jusuf is qualified to serve in his positions
with our company due to his strong qualifications in business development, government relations and strategic planning.
Frank
C. Ingriselli has served as our President since February 2019. With over 40 years of experience in the energy industry, Mr. Ingriselli
is a seasoned leader and entrepreneur with wide-ranging exploration and production experience in diverse geographies, business climates
and political environments. From 2005 to 2018, Mr. Ingriselli was the founder, President, CEO and Chairman of PEDEVCO Corp. and Pacific
Asia Petroleum, Inc., both energy companies which are or were listed on NYSE American. Prior to founding these two companies, from 1979
to 2001, Mr. Ingriselli worked at Texaco in diverse senior executive positions involving exploration and production, power and gas operations,
merger and acquisition activities, pipeline operations and corporate development. The positions Mr. Ingriselli held at Texaco included
President of Texaco Technology Ventures, President and CEO of the Timan Pechora Company (owned by affiliates of Texaco, Exxon, Amoco,
Norsk Hydro and Lukoil), and President of Texaco International Operations, where he directed Texaco’s global initiatives in exploration
and development. While at Texaco, Mr. Ingriselli, among other activities, led Texaco’s initiatives in exploration and development
in China, Russia, Australia, India, Venezuela and many other countries. Mr. Ingriselli has served as an independent member of the Board
of Directors of NXT Energy Solutions Inc. (TSX:SFD; OTC QB:NSFDF) since 2019 and is also on the Board of Trustees of the Eurasia Foundation,
and is the founder and Chairman of Brightening Lives Foundation, Inc., a charitable public foundation. From 2016 through 2018, Mr. Ingriselli
founded and was the President and CEO of Blackhawk Energy Ventures Inc. which endeavored to acquire oil and gas assets in the United
States for development purposes. Mr. Ingriselli graduated from Boston University in 1975 with a B.S. in business administration. He also
earned an M.B.A. from New York University in both finance and international finance in 1977 and a J.D. from Fordham University School
of Law in 1979.
Dr.
Chia Hsin (Charlie) Wu has served as our Chief Operating Officer since 2018. Dr. Wu is a highly qualified and recognized oil
and gas industry veteran with over 40 years of experience. Dr. Wu has been responsible for building and leading the upstream exploration
and production teams for 3 independent oil and gas companies in Indonesia over the last 15 years. Prior to joining our company, since
2017 Dr. Wu has been acting as the Chief Technology Officer for Pt. Pandawa Prima Lestari, an oil and gas company operating a PSC block
in Kalimantan, as well as an independent oil and gas consultant. Dr. Wu previously served as the Director of Operations and Chief Operating
Officer of Pt. Sugih Energy TBK, an oil and gas exploration and production company with 4 PSC blocks in Central and South Sumatera from
2013 to 2016. From 2010 to 2013, Dr. Wu was the President Director of Pacific Oil & Gas Indonesia, an oil and gas company operating
2 PSC blocks in North Sumatra and one KSO block in Aceh. Prior to 2010, Dr. Wu had transitioned into the senior role of Vice-President
and General Manager with Petroselat Ltd., operator of an exploration and production PSC block in Central Sumatra which he started in
2000, and International Mineral Resources from 2003. From 1999 to 2000, Dr. Wu served as an Exploration Consultant with EMP Kondur Petroleum,
an oil company which operated a production PSC in Central Sumatra. From 1981 to 1999, Dr. Wu worked in a variety of roles internationally
with Atlantic Richfield Company (ARCO, now recognized as BP Plc). Dr. Wu worked in the position of Geological Specialist from 1996 to
1999 in Jakarta, Indonesia. From 1990 to 1995, Dr. Wu worked as a New Venture Geologist with the ARCO organization in Plano, Texas, and
from 1985 to 1990, Dr. Wu worked as an Exploration Coordinator of the for ARCO in Jakarta, Indonesia. Dr. Wu began his work with ARCO
from 1983 to 1985 as an explorationist in Plano, Texas, during which time he earned ARCO’s “Exploration Excellence Award”
on the Vice-President Level for providing training to worldwide staff in geohistory and basin modelling with subsequent exploration successes.
From 1979 to 1981, Dr. Wu worked as a Petrophysical Supervisor with Core Laboratories Inc. Dr. Wu began his career as a Research Specialist
with the US Department of Energy at the University of Oklahoma in 1979. Dr. Wu completed his Postgraduate Diploma in Business Administration
at DeMontfort University in 2000 and earned his Ph.D. in Geosciences in 1991 at the University of Texas. He also completed his Masters
of Science in Geology at the University of Toledo in 1979. Prior to his graduate studies, Dr. Wu earned his Bachelors of Science degree
in Geology at National Taiwan University in 1975. Dr. Wu has also served as Adjunct Professor at the University of Texas at Dallas and
University of Indonesia where he has taught 8 regular and industrial courses.
Mirza
F. Said has served as Chief Business Development Officer and a Director of our company since 2018 and has served as Chief Executive
Officer of our subsidiary Pt. Green World Nusantara since 2014. From 2012 to 2014, Mr. Said had served as President Director and Commissioner
of Pt. Humpuss Patragas, Pt. Humpuss Trading and Pt. Humpuss Wajo Energi simultaneously. All of these companies are the subsidiaries
of PT. Humpuss, an Indonesian holding company focusing on energy business, including in upstream, transportation and refining activities.
From 2010 to 2012, Mr. Said acted as the Senior Business Development & External Relations Manager for Pacific Oil & Gas. From
2007 to 2010, Mr. Said Co-Founded Pt. Corpora Hydrocarbon Asian, a private oil and gas investment company, and served as that organization’s
Operational Specialist. Prior to serving as Chief Operating Officer of Pt. Indelberg Indonesia from 2006 to 2007, Mr. Said served as
the Corporate Operations Controller for Akar Golindo Group from 2004 to 2006. From 2001 to 2004, Mr. Said was the Project Cost Controller
& Analyst for the Kangean Asset for BP Indonesia, during which time, as a result of his achievements he was awarded the “Spot
Recognition Award of Significant Contribution in Managing & Placing”. From 1997 to 1999, he served as Operations Manager for
JOB Pertamina Western Madura Pty Ltd., a joint operation company between Citiview Corporation Ltd (an Australian based oil and gas company)
and Pertamina (the Indonesian state owned oil and gas company) that operated a block in Madura, East Java. Mr. Said began his professional
career as Senior Drilling Engineer with Pt. Humpuss Patragas, an Indonesian private oil and gas company a subsidiary of PT. Humpuss,
which operated Cepu Block, East Java from 1991 to 1997 (he would later return to that organization in 2012 and serve in two senior executive
positions concurrently). Mr. Said earned his Master of Engineering Management at the Curtin University of Technology in Perth, Australia,
and had completed his Bachelor’s degree in Engineering at the Chemical Engineering Institute Technology of Indonesia. Mr. Said
holds professional memberships with the Indonesian Petroleum Association (IPA) and Society of Indonesian Petroleum Engineers (IATMI)
and is fluent in English and Indonesian. We believe Mr. Said is qualified to serve in his positions with our company as a result of his
education and professional experiences, including achievements and expertise within the energy and infrastructure sector.
James
J. Huang is co-founder and has served as Chief Investment Officer and Director of our company since inception, and has served
as the Chief Investment Officer of WJ Energy since 2014. Mr. Huang co-founded and has served as Director of Asiabeef Group Limited, a
fully integrated and sustainable cattle business company and holding company of Pt. Asiabeef Biofarm Indonesia, since 2015. Mr. Huang
founded and is a Director at Pt. HFI International Consulting, an Indonesian based business consulting company, since 2014. Mr. Huang
was previously the Director of Pt. Biofarm Plantation, a cattle trading company, from 2013 until 2015. From 2010 to 2013, Mr. Huang founded
and served as a Director at HFI Ind. Imp. e Exp. Ltd., an information technology company providing integrated security and surveillance
solutions in Brazil. Mr. Huang began his professional career in 2008 as an intern practicing corporate law and tax consulting with Barbosa,
Müssnich & Aragão in São Paulo, Brazil. Mr. Huang holds the Chartered Financial Analyst® (CFA)
designation and maintains an Attorney at Law professional license from the Brazilian Bar Association (OAB/SP). Mr. Huang earned his Bachelor’s
degree in law at the Escola de Direito de São Paulo in Brazil at Fundação Getúlio Vargas and previously participated
at a Double Degree Business Management Program at the Escola de Administração de Empresas de São Paulo also at Fundação
Getúlio Vargas. We believe Mr. Huang is qualified to serve in his positions with our company due to his expertise in finance,
legal matters, business management and strategic planning.
Gregory
L. Overholtzer has served as our Chief Financial Officer since February 2019. Mr. Overholtzer is a seasoned financial officer
for public companies, including in the energy space. Mr. Overholtzer had served as the Chief Financial Officer of PEDEVCO Corp. from
January 2012 to December 2018. From 2011 to 2012, Mr. Overholtzer served as Senior Director and Field Consultant for Accretive Solutions,
where he had consulted for various companies at the chief financial officer and controller levels. Mr. Overholtzer acted as the Chief
Financial Officer of Omni-ID USA Inc. from 2008 to 2011. Mr. Overholtzer was the Corporate Controller of Genitope Corporation from 2006
to 2008, and Stratex Inc. from 2005 to 2006. Mr. Overholtzer served as the Chief Financial Officer and Vice President of Finance for
Polymer Technology Group from 1998 to 2005. From 1997 to 1998, he was the Chief Financial Officer and Vice President of Finance at TeleSensory
Corporation. Mr. Overholtzer held roles of Chief Financial Officer, Vice President of Finance and Corporate Secretary with Giga-tronics
Inc. from 1994 to 1997. Mr. Overholtzer also held several positions with Airco Coating Tech., a division of BOC Group London from 1982
to 1994, which included Senior Financial Analyst, General Accounting Manager, Vice President of Finance and Administration. In the early
years of his career, Mr. Overholtzer also was as an MBA course Instructor in Managerial Accounting at Golden Gate University from 1984
to 1987 and 1989 to 1991. Mr. Overholtzer had received his MBA at the University of California, Berkeley, concentrating in Finance and
Accounting and graduating with Beta Sigma Honors. Prior to his graduate studies, Mr. Overholtzer earned his B.A. in Zoology at the University
of California, Berkeley, graduating with University Honors.
Mochtar
Hussein has served as a Director of our company since October 2018. From 2013 to 2018, Mr. Hussein acted as Inspector General
of Inspectorate General of the MEMR. From 2014 to 2018, Mr. Hussein also served as Commissioner of Pt. Timah (Persero) Tbk, an Indonesian
state owned enterprise engaged in tin mining and listed on Indonesia Stock Exchange. In 2012, Mr. Hussein served as Director of Indonesian
Government Institution Supervision of Public Welfare and Defence & Security, and from 2009 to 2012, he served as the Head of the
Representative Office of the Indonesian State Finance & Development Surveillance Committee (known as BPKP) in Central Java Province.
From 2005 to 2009, he served as Director of Fiscal and Investment Supervision in the BPKP, and during 2004, he served as the Head of
the Representative Office of BPKP in Lampung Province. From 2000 to 2004, Mr. Hussein served as Head of Indonesian State & Regionally
Owned Enterprises Supervision in Jakarta. From 1997 to 2000, Mr. Hussein concurrently served as Head of Indonesian State & Regionally
Owned Enterprises Supervision in East Nusa Tenggara Province and the Section Head of Fuel & Non-Fuel Distribution Supervision. Mr.
Hussein began his professional career in 1993 as Section Head of Services, Trading & Financial Institution Supervision in Bengkulu
Province and served in a range of senior positions with the BPKP until 2012. Mr. Hussein holds a Forensic Auditor Certification. He earned
his Bachelor’s degree in Economics at the Brawijaya University, Malang in East Java. We believe Mr. Hussein is qualified to serve
as a Director of our company his expertise in investigative auditing, compliance and corporate governance.
Benny
Dharmawan has served as a Director of our company since October 2018. Since 2006, following his previous international experiences
throughout Australia, United Kingdom and the United States, Mr. Dharmawan has served as Director of Pt. Panasia Indo Resources Tbk.,
a holding company that primarily engages in yarn manufacturing and synthetic fibres but through its subsidiaries, it also engages in
the mining sector. In addition, since 2015, Mr. Dharmawan has served as Controller of Pt. Sinar Tambang Arthalestari, a fully integrated
cement producer in Central Java, Indonesia. From 2007 and 2015, Mr. Dharmawan acted in several executive positions (including equity
capital markets, regional operations and compliance) with the Macquarie Group, a global provider of banking, advisory, trading, asset
management and retail financial services, in New York, London and Sydney, ultimately rising to the level of Associate Vice President.
Mr. Dharmawan earned his Graduate Certification in Applied Finance and Investments in Kaplan, Australia, and he completed his Bachelor’s
degree in Commerce at the Macquarie University in Australia. Mr. Dharmawan holds the Certified Anti Money Laundering Specialist (CAMS-ACAMS)
credential. We believe Mr. Dharmawan is qualified to serve as a Director of our company due to his previous international professional
accomplishments, particularly his expertise in risk management, compliance, financial markets, business management and strategic and
tactical planning.
Tamba
P. Hutapea has served as a Director of our company since October 2018. Since 2004, Mr. Hutapea has served in several Head and
Directorial roles within Indonesia Investment Coordinating Board (or BKPM). Mr. Hutapea’s enriched experiences within BKPM contributed
greatly to his core competency in investment planning and policy, investment licensing, investment compliance and corporate governance.
From 2011 to August 2018, Mr. Hutapea served as the BKPM’s Deputy Chairman of Investment Planning. Previously, Mr. Hutapea acted
as the Director of Investment Planning for Agriculture and Other Natural Resources from 2010 to 2011. Prior that role, he was the Director
of Investment Deregulation from 2007 to 2010. From 2006 to 2007, Mr. Hutapea served as the Head of Bureau of Planning and Information.
Between 2005 and 2006, he acted as the Director of Region III (Sulawesi, DI Jogyakarta & Central Java). From 2004 to 2005, Mr. Hutapea
was the Director of Investment Facility Services. Mr. Hutapea earned his Master of City Planning at the University of Pennsylvania his
Bachelor’s degree in Agronomy at the Bogor Agricultural University in Bogor, West Java. We believe Mr. Hutapea is qualified to
be a Director of our company because of his professional accomplishments within multiple senior investment management roles within BKPM,
as well as his enhanced knowledge and skills in investment planning and management.”
Michael
L. Peterson has served as a Director of our company since January 2021. Since December 2020, he has served as the Chief Executive
Officer of Nevo Motors, Inc., a company that is commercializing low carbon emission trucks. From 2011 to 2018, Mr. Peterson served in
several executive officer positions at PEDEVCO Corp. (NYSE American: PED), a public company engaged primarily in the acquisition, exploration,
development and production of oil and natural gas shale plays in the United States. These positions included as Chief Executive Officer,
President, Chief Financial Officer and Executive Vice President. Since August 2016, Mr. Peterson has served as an independent director
on the board of TrxAde Group, Inc. (NASDAQ: MEDS), a web-based pharmaceutical market platform headquartered in Florida. From 2006 and
2012, he served in several executive positions at Aemetis, Inc. (formerly AE Biofuels Inc.), a Cupertino, California-based global advanced
biofuels and renewable commodity chemicals company. These positions included as Interim President, Director and Executive Vice President.
From December 2008 to July 2012, Mr. Peterson also served as Chairman and Chief Executive Officer of Nevo Energy, Inc. (formerly Solargen
Energy, Inc.), a Cupertino, California-based developer of utility-scale solar farms which he helped form, which is currently operating
as Nevo Motors, Inc.). From 2005 to 2006, Mr. Peterson served as a managing partner of American Institutional Partners, a venture investment
fund based in Salt Lake City. From 2000 to 2004, he served as a First Vice President at Merrill Lynch, where he helped establish a new
private client services division to work exclusively with high-net-worth investors. From September 1989 to January 2000, Mr. Peterson
was employed by Goldman Sachs & Co. in a variety of positions and roles, including as a Vice President with the responsibility for
a team of professionals that advised and managed over $7 billion in assets. Since Mr. Peterson’s retirement from Pedevco in 2018,
he has served as the President of the Taipei Taiwan Mission of The Church of Jesus Christ of Latter-day Saints, in Taipei, Taiwan. Mr.
Peterson received his Master degree of Business Administration at the Marriott School of Management and a Bachelor’s degree in
statistics/computer science from Brigham Young University. Mr. Peterson is qualified to be a Director of our company due to his experience
in managing, operating and growing both public and private companies, especially those active in the energy industry.
Family
Relationships and Conflicts of Interests
There
are no family relationships between any of our officers and directors. We are not aware of any conflicts of interests related to our
officers and directors arising from the management and operations of our business.
Board
of Directors and Committees
General
Our
board of directors consists of seven (7) directors. A majority of our board of directors (namely, Mochtar Hussein, Benny Dharmawan, Tamba
P. Hutapea and Michael L. Peterson) are independent, as such term is defined by the NYSE American. The members of our board of directors
are elected annually at our annual general meeting of shareholders.
We
do not have a lead independent director, and we do not anticipate having a lead independent director. Our board of directors as a whole
play a key role in our risk oversight. Our board of directors makes all decisions relevant to our company. We believe it is appropriate
to have the involvement and input of all of our directors in risk oversight matters.
Board
Committees
Our
board of directors have three standing committees: the audit committee, the compensation committee and the nominating and corporate governance
committee. Each committee has three members, and each member is independent, as such term is defined by the NYSE American.
The
audit committee is responsible for overseeing the accounting and financial reporting processes of our company and audits of the financial
statements of our company, including the appointment, compensation and oversight of the work of our independent auditors.
The
compensation committee reviews and makes recommendations to the board regarding our compensation policies for our officers and all forms
of compensation, and also administers and has authority to make grants under our incentive compensation plans and equity-based plans.
The
nominating and corporate governance committee is responsible for the assessment of the performance of our board of directors, considering
and making recommendations to our board of directors with respect to the nominations or elections of directors and other governance issues.
The nominating and corporate governance committee will consider diversity of opinion and experience when nominating directors.
The
members of the audit committee, the compensation committee and the nominating and corporate governance committee are set forth below.
All such members will qualify as independent under the rules of NYSE American.
Director | |
Audit Committee | | |
Compensation
Committee | | |
Nominating and Corporate Governance Committee | |
Michael L. Peterson (3) | |
| (2) | | |
| — | | |
| — | |
Tamba P. Hutapea | |
| — | | |
| (1) | | |
| (2) | |
Benny Dharmawan | |
| (1) | | |
| (2) | | |
| (1) | |
Mochtar Hussein | |
| (1) | | |
| (1) | | |
| — | |
(1) |
Committee
member |
(2) |
Committee
chair |
(3) |
Audit
committee financial expert |
Duties
of Directors
As
a matter of Cayman Islands law, a director owes three types of duties to the company: (a) statutory duties, (b) fiduciary duties, and
(iii) common law duties. The Companies Act imposes a number of statutory duties on a director. A Cayman Islands director’s fiduciary
duties are not codified, however the courts of the Cayman Islands have held that a director owes the following fiduciary duties (a) a
duty to act in what the director bona fide considers to be in the best interests of the company, (b) a duty to exercise their powers
for the purposes they were conferred, (c) a duty to avoid fettering his or her discretion in the future and (d) a duty to avoid conflicts
of interest and of duty. The common law duties owed by a director are those to act with skill, care and diligence that may reasonably
be expected of a person carrying out the same functions as are carried out by that director in relation to the company and, also, to
act with the skill, care and diligence in keeping with a standard of care commensurate with any particular skill they have which enables
them to meet a higher standard than a director without those skills. In fulfilling their duty of care to us, our directors must ensure
compliance with our amended articles of association, as amended and restated from time to time (our “Articles of Association”).
We have the right to seek damages if a duty owed by any of our directors is breached. Our board of directors.
Interested
Transactions
A
director may vote, attend a board meeting or, presuming that the director is an officer and that it has been approved, sign a document
on our behalf with respect to any contract or transaction in which he or she is interested. We require directors to promptly disclose
the interest to all other directors after becoming aware of the fact that he or she is interested in a transaction we have entered into
or are to enter into. A general notice or disclosure to the board or otherwise contained in the minutes of a meeting or a written resolution
of the board or any committee of the board that a director is a shareholder, director, officer or trustee of any specified firm or company
and is to be regarded as interested in any transaction with such firm or company will be sufficient disclosure, and, after such general
notice, it will not be necessary to give special notice relating to any particular transaction.
Remuneration
and Borrowing
Our
directors may receive such remuneration as our board of directors may determine or change from time to time. The compensation committee
will assist the directors in reviewing and approving the compensation structure for the directors.
Our
board of directors may exercise all the powers of the company to borrow money and to mortgage or charge our undertakings and property
and assets both present and future and uncalled capital or any part thereof, to issue debentures and other securities whether outright
or as collateral security for any debt, liability or obligation of our company or its parent undertaking (if any) or any subsidiary undertaking
of our company or of any third party.
Qualification
A
majority of our board of directors is required to be independent. There are no membership qualifications for directors. The shareholding
qualification for directors may be fixed by our shareholders by ordinary resolution and unless and until so fixed no share qualification
shall be required.
Limitation
of Director and Officer Liability
Under
Cayman Islands law, each of our directors and officers, in performing his or her functions, is required to act honestly and in good faith
with a view to our best interests and exercise the care, diligence and skill that a reasonably prudent person would exercise in comparable
circumstances. Cayman Islands law does not limit the extent to which a company’s Articles of Association may provide for indemnification
of officers and directors and secretaries, except to the extent any such provision may be held by the Cayman Islands courts to be contrary
to public policy, such as to provide indemnification against civil fraud or the consequences of committing a crime.
The
Articles of Association provide, to the extent permitted by law, for the indemnification of each existing or former director (including
alternate director), secretary and any of our other officers (including an investment adviser or an administrator or liquidator) and
their personal representatives against:
|
(a) |
all
actions, proceedings, costs, charges, expenses, losses, damages or liabilities incurred or sustained by the existing or former director
(including alternate director), secretary or officer in or about the conduct of our business or affairs or in the execution or discharge
of the existing or former director’s (including alternate director’s), secretary’s or officer’s duties, powers,
authorities or discretions; and |
|
(b) |
without
limitation to paragraph (a) above, all costs, expenses, losses or liabilities incurred by the existing or former director (including
alternate director), secretary or officer in defending (whether successfully or otherwise) any civil, criminal, administrative or
investigative proceedings (whether threatened, pending or completed) concerning us or our affairs in any court or tribunal, whether
in the Cayman Islands or elsewhere. To be entitled to indemnification, these persons must have acted honestly and in good faith with
a view to the best interest of the company and, in the case of criminal proceedings, they must have had no reasonable cause to believe
their conduct was unlawful. Such limitation of liability does not affect the availability of equitable remedies such as injunctive
relief or rescission. These provisions will not limit the liability of directors under United States federal securities laws. |
The
decision of our board of directors as to whether the director acted honestly and in good faith with a view to our best interests and
as to whether the director had no reasonable cause to believe that his or her conduct was unlawful, is in the absence of fraud sufficient
for the purposes of indemnification, unless a question of law is involved. The termination of any proceedings by any judgment, order,
settlement, conviction or the entry of no plea does not, by itself, create a presumption that a director did not act honestly and in
good faith and with a view to our best interests or that the director had reasonable cause to believe that his or her conduct was unlawful.
If a director to be indemnified has been successful in defense of any proceedings referred to above, the director is entitled to be indemnified
against all expenses, including legal fees, and against all judgments, fines and amounts paid in settlement and reasonably incurred by
the director or officer in connection with the proceedings.
We
have purchased and currently maintain insurance in relation to any of our directors or officers against any liability asserted against
the directors or officers and incurred by the directors or officers in that capacity, whether or not we have or would have had the power
to indemnify the directors or officers against the liability as provided in our Articles of Association. Insofar as indemnification for
liabilities arising under the Securities Act may be permitted for our directors, officers or persons controlling our company under the
foregoing provisions, we have been informed that in the opinion of the SEC, such indemnification is against public policy as expressed
in the Securities Act and is therefore unenforceable.
Involvement
in Certain Legal Proceedings
To
our knowledge, none of our directors or officers has been convicted in a criminal proceeding, excluding traffic violations or similar
misdemeanors, nor has been a party to any judicial or administrative proceeding during the past five years that resulted in a judgment,
decree or final order enjoining the person from future violations of, or prohibiting activities subject to, federal or state securities
laws, or a finding of any violation of federal or state securities laws, except for matters that were dismissed without sanction or settlement.
Except as set forth in our discussion below in “Related Party Transactions,” our directors and officers have not been involved
in any transactions with us or any of our affiliates or associates which are required to be disclosed pursuant to the rules and regulations
of the SEC.
Code
of Business Conduct and Ethics
The
board adopted a code of ethics and business conduct applicable to our directors, officers and employees on June 21, 2019.
EXECUTIVE
COMPENSATION
Our
compensation committee, consisting of independent board members determined the compensation to be paid to our executive officers based
on our financial and operating performance and prospects, and contributions made by the officers’ to our success. Our compensation
committee measures each of our officers by a series of performance criteria by our board of directors, or the compensation committee
on a yearly basis. Such criteria is based on certain objective parameters such as job characteristics, required professionalism, management
skills, interpersonal skills, related experience, personal performance and overall corporate performance.
Our
board of directors has not adopted or established a formal policy or procedure for determining the amount of compensation paid to our
executive officers. Our board of directors will make an independent evaluation of appropriate compensation to key employees, with input
from management. Our board of directors has oversight of executive compensation plans, policies and programs.
Summary
Compensation Table
The
following table presents summary information regarding the total compensation awarded to, earned by, or paid to each of the named executive
officers for services rendered to us for the years ended December 31, 2021 and 2020.
Name
and principal position | |
Fiscal
Year | | |
Salary
($) | | |
Bonus
($) | | |
Stock awards
($) | | |
Option awards
($)(1) | | |
Non-equity incentive plan compensation ($) | | |
Nonqualified deferred compensation earnings
($) | | |
All
other compensation ($)(2) | | |
Total
($) | |
Dr. Wirawan Jusuf | |
| 2021 | | |
| 297,000 | | |
| - | | |
| - | | |
| - | | |
| - | | |
| - | | |
| - | | |
| 297,000 | |
Chief
Executive Officer | |
| 2020 | | |
| 297,000 | | |
| - | | |
| - | | |
| 21,069 | | |
| - | | |
| - | | |
| | | |
| 318,069 | |
| |
| | | |
| | | |
| | | |
| | | |
| | | |
| | | |
| | | |
| | | |
| | |
Frank C. Ingriselli | |
| 2021 | | |
| 150,000 | | |
| - | | |
| - | | |
| - | | |
| - | | |
| - | | |
| - | | |
| 150,000 | |
President | |
| 2020 | | |
| 150,000 | | |
| - | | |
| - | | |
| 155,885 | | |
| - | | |
| - | | |
| - | | |
| 305,885 | |
| |
| | | |
| | | |
| | | |
| | | |
| | | |
| | | |
| | | |
| | | |
| | |
Gregory L. Overholtzer | |
| 2021 | | |
| 80,000 | | |
| - | | |
| - | | |
| - | | |
| - | | |
| - | | |
| - | | |
| 80,000 | |
Chief
Financial Officer | |
| 2020 | | |
| 80,000 | | |
| - | | |
| - | | |
| - | | |
| - | | |
| - | | |
| - | | |
| 80,000 | |
| |
| | | |
| | | |
| | | |
| | | |
| | | |
| | | |
| | | |
| | | |
| | |
Mirza F. Said | |
| 2021 | | |
| 204,000 | | |
| - | | |
| - | | |
| - | | |
| - | | |
| - | | |
| - | | |
| 204,000 | |
Chief
Business Development Officer | |
| 2020 | | |
| 204,000 | | |
| | | |
| - | | |
| 24,843 | | |
| - | | |
| - | | |
| | | |
| 228,845 | |
| |
| | | |
| | | |
| | | |
| | | |
| | | |
| | | |
| | | |
| | | |
| | |
Chia Hsin “Charlie”
Wu | |
| 2021 | | |
| 204,000 | | |
| - | | |
| - | | |
| - | | |
| - | | |
| - | | |
| - | | |
| 204,000 | |
Chief
Operating Officer | |
| 2020 | | |
| 204,000 | | |
| - | | |
| - | | |
| 24,843 | | |
| - | | |
| - | | |
| - | | |
| 228,845 | |
| |
| | | |
| | | |
| | | |
| | | |
| | | |
| | | |
| | | |
| | | |
| | |
James J. Huang | |
| 2021 | | |
| 240,000 | | |
| - | | |
| - | | |
| - | | |
| - | | |
| - | | |
| - | | |
| 240,000 | |
Chief
Investment Officer | |
| 2020 | | |
| 240,000 | | |
| - | | |
| - | | |
| 24,843 | | |
| - | | |
| - | | |
| - | | |
| 264,843 | |
(1)
The options and bonus were granted pursuant to agreement between the executives and our company. The values of the option awards represent
grant-date fair values without regard to forfeitures.
(2)
All other compensation refers to income tax withholding under Indonesian law. Salaries in Indonesia are negotiated on a “take home
pay” basis. Therefore, we pay the income withholding tax on behalf of the employee, which is legally considered part of the employee’s
compensation.
Outstanding
Equity Awards at 2021 Year-End
The
following table provides information regarding each unexercised stock option held by the named executive officers as of December 31,
2021.
Name | |
Grant date | | |
Vesting Start date | | |
Number of securities underlying unexercised options vested (#) | | |
Number of securities underlying unexercised options unvested (#) | | |
Options exercise price ($) | | |
Option Expiration date | |
Dr. Wirawan Jusuf Chief Executive Officer | |
| December 19, 2019 | | |
| December 23, 2020 | | |
| 100,000 | | |
| 50,000 | | |
$ | 11.00 | | |
| December 19, 2024 | |
| |
| | | |
| | | |
| | | |
| | | |
| | | |
| | |
Frank C. Ingriselli President | |
| December 19, 2019 | | |
| December 19, 2019 | | |
| 37,500 | | |
| - | | |
$ | 11.00 | | |
| December 19, 2029 | |
| |
| | | |
| | | |
| | | |
| | | |
| | | |
| | |
Gregory L. Overholtzer Chief Financial Officer | |
| - | | |
| - | | |
| - | | |
| - | | |
| - | | |
| - | |
| |
| | | |
| | | |
| | | |
| | | |
| | | |
| | |
Chia Hsin “Charlie” Wu Chief Operating Officer | |
| December 19, 2019 | | |
| December 23, 2020 | | |
| 100,000 | | |
| 50,000 | | |
$ | 11.00 | | |
| December 19, 2029 | |
| |
| | | |
| | | |
| | | |
| | | |
| | | |
| | |
James J. Huang Chief Investment Officer | |
| December 19, 2019 | | |
| December 23, 2020 | | |
| 100,000 | | |
| 50,000 | | |
$ | 11.00 | | |
| December 19, 2029 | |
| |
| | | |
| | | |
| | | |
| | | |
| | | |
| | |
Mirza F. Said Chief Business Development Officer | |
| December 19, 2019 | | |
| December 23, 2020 | | |
| 100,000 | | |
| 50,000 | | |
$ | 11.00 | | |
| December 19, 2029 | |
On
March 3, 2022, with the approval of the Compensation Committee of our board of directors, certain of our executive officers exercised
vested options to purchase restricted ordinary shares on a “cashless exercise” basis. The following table shows the ordinary
shares issued to these officers upon such exercise:
Optionee | |
Vested Options Exercised | | |
Option
Exercise Price | | |
Closing Price on
March 3, 2022 | | |
Net Shares Received Upon Exercise | |
Wirawan Jusuf | |
| 100,000 | | |
$ | 11.00 | | |
$ | 20.20 | | |
| 45,545 | |
James J, Huang | |
| 100,000 | | |
$ | 11.00 | | |
$ | 20.20 | | |
| 45,545 | |
Mirza Said | |
| 100,000 | | |
$ | 11.00 | | |
$ | 20.20 | | |
| 45,545 | |
Chia Hsin “Charlie” Wu | |
| 100,000 | | |
$ | 11.00 | | |
$ | 20.20 | | |
| 45,545 | |
Frank Ingriselli | |
| 37,500 | | |
$ | 11.00 | | |
$ | 20.20 | | |
| 17,079 | |
Total | |
| 437,500 | | |
| | | |
| | | |
| 199,259 | |
Employment
Agreements
Except
as set forth below, we currently have no written employment agreements with any of our officers, directors, or key employees. While certain
of our officers hold positions with other entities, pursuant to their employment agreements with us, each officer is required to spend
substantially all of his working time, attention and skills to the performance of his duties to our company. Unless otherwise stated
below, all employment agreements listed below with auto-renewal provisions were not terminated by either us or the employee, and were
therefore automatically renewed.
Wirawan
Jusuf
On
February 27, 2019, our board of directors approved an employment agreement with Wirawan Jusuf and we entered into such agreement (which
we refer to as the Jusuf Agreement) with Mr. Jusuf effective February 1, 2019, under which he serves as our Chief Executive Officer.
We also entered into a share option agreement with Mr. Jusuf effective as of February 1, 2019.
The
Jusuf Agreement has an initial term beginning on February 1, 2019, and expiring one (1) year from such date. The Jusuf Agreement is subject
to automatic renewal on a year-to-year renewal basis unless either we or Mr. Jusuf provides written notice not to renew the Jusuf Agreement
no later than 30 days prior to the end of the then current or renewal term.
Pursuant
to the terms and provisions of the Jusuf Agreement, Mr. Jusuf is entitled to an annual base salary of $282,000, cash bonuses as determined
by our board of directors or its designated committee in its sole discretion, participation in our 2018 Omnibus Equity Incentive Plan
or similar equity incentive plans, and other employee benefits as approved by our board of directors.
We
may terminate the Jusuf Agreement without cause upon 30 days’ prior written notice and Mr. Jusuf may resign without cause upon
30 days’ prior written notice. We may also immediately terminate the Jusuf Agreement for cause (as set forth in the Jusuf Agreement).
Upon the termination of the Jusuf Agreement for any reason, Mr. Jusuf will be entitled to receive payment of any base salary earned but
unpaid through the date of termination and any other payment or benefit to which he is entitled under the applicable terms of any applicable
company arrangements. If Mr. Jusuf is terminated during the term of the employment agreement other than for cause, Mr. Jusuf is entitled
to, upon delivering to us a general release of our company and its affiliates in a form satisfactory to us, the amount of base salary
earned and not paid prior to termination and such severance payments as may be mandated by Indonesian law (presently one month of base
salary for every year worked with us) (the “Jusuf Severance Payment”). In the event that such termination is upon a Change
of Control (as defined in the Jusuf Agreement), Mr. Jusuf shall be entitled to the Jusuf Severance Payment. In addition, the Jusuf Agreement
will terminate prior to its scheduled expiration date in the event of Mr. Jusuf’s death or disability.
The
Jusuf Agreement also includes confidentiality and non-disclosure covenants as well as a twelve (12) month non-competition and non-solicitation
covenant. The Jusuf Agreement is governed by Cayman Islands law.
Under
Mr. Jusuf’s share option agreement, Mr. Jusuf was granted an option to purchase 150,000 ordinary shares under our 2018 Omnibus
Equity Incentive Plan at an exercise price equal to $11.00 per share. Mr. Jusuf’s option shall vest as follows (assuming, in each
case, that Mr. Jusuf remains employed with us): (a) 50,000 ordinary shares shall vest on the first anniversary of the closing of our
initial public offering, (b) 50,000 ordinary shares shall vest on the second anniversary of the closing of our initial public offering;
and (c) 50,000 ordinary shares shall vest on the third anniversary of the closing of our initial public offering. The share option agreement
is governed by Cayman Islands law.
Frank
Ingriselli
On
February 27, 2019, our board of directors approved an employment agreement with Frank Ingriselli and we entered into such agreement (which
we refer to as the Ingriselli Agreement) with Mr. Ingriselli effective February 1, 2019, under which he serves as our President. We also
entered into a share option agreement with Mr. Ingriselli effective as of February 1, 2019. On January 23, 2020, we entered into an amendment
to the Ingriselli Agreement (the “Ingriselli Amendment”). On January 21, 2022, we entered into a Second Amendment to Employment
Agreement (the “Ingriselli Second Amendment”).
The
Ingriselli Agreement had an initial term beginning on February 1, 2019, and expired one (1) year from such date. The Ingriselli Amendment
extends the term of Mr. Ingriselli’s employment as our President for a two-year term commencing on February 1, 2020 and terminating
on January 31, 2022, and the Ingriselli Second Amendment further extends the term of the Ingriselli Agreement to December 31, 2023, unless
terminated earlier pursuant to the terms of the Ingriselli Agreement. The Ingriselli Agreement is not subject to automatic renewal.
Pursuant
to the terms and provisions of the Ingriselli Agreement, as amended by the Ingriselli Amendment, Mr. Ingriselli is entitled to an annual
base salary of $150,000 and a $75,000 cash bonus for services rendered during the year ended December 31, 2019. Cash bonuses as determined
by our board of directors or its designated committee in its sole discretion. Pursuant to the Ingriselli Amendment, Mr. Ingriselli was
also granted 35,000 ordinary shares as an equity incentive award for his continued service as our President. The vesting schedule of
these shares is as follows: 18,750 vested on December 19, 2019, 9,375 vested on June 16, 2020, and 9,375 vested on December 19, 2020.
Pursuant to the Ingriselli Second Amendment, Mr. Ingriselli was granted an award of 60,000 Ordinary Shares, with 30,000 shares vesting
on July 1, 2022 and 30,000 vesting on January 1, 2023. The award also includes a 180-day lock-up period from the date of vesting. Participation
in our 2018 Omnibus Equity Incentive Plan or similar equity incentive plans, and other employee benefits as approved by our board of
directors.
We
may terminate the Ingriselli Agreement, as amended without cause upon 30 days’ prior written notice and Mr. Ingriselli may resign
with or without cause upon 30 days’ prior written notice. We may also immediately terminate Ingriselli Agreement, as amended for
cause (as set forth in the Ingriselli Agreement). Upon the termination of the Ingriselli Agreement for any reason, Mr. Ingriselli will
be entitled to receive payment of any base salary earned but unpaid through the date of termination and any other payment or benefit
to which he is entitled under the applicable terms of any applicable company arrangements. If Mr. Ingriselli is terminated during the
term of the employment agreement other than for cause, Mr. Ingriselli is entitled to, upon delivering to us a general release of our
company and its affiliates in a form satisfactory to us, the amount of base salary earned and not paid prior to termination. In addition,
the Ingriselli Agreement, as amended will terminate prior to its scheduled expiration date in the event of Mr. Ingriselli’s death
or disability.
The
Ingriselli Agreement also includes confidentiality and non-disclosure covenants as well as a twelve (12) month non-competition and non-solicitation
covenant. The Ingriselli Agreement is governed by Cayman Islands law.
Under
Mr. Ingriselli’s share option agreement, Mr. Ingriselli was granted an option to purchase 37,500 ordinary shares under our 2018
Omnibus Equity Incentive Plan at an exercise price equal to $11.00 per share. Mr. Ingriselli’s option vested as follows: (a) 18,750
ordinary shares vested on the date of effectiveness of our initial public offering registration statement, (b) 9,375 ordinary shares
vested on the 180th day following the closing of our initial public offering; and (c) 9,375 ordinary shares vested on the
first anniversary of the closing of our initial public offering. The share option agreement is governed by Cayman Islands law.
James
Jerry Huang
On
February 27, 2019, our board of directors approved an employment agreement and share option agreement with James Jerry Huang and we entered
into such agreements (which we refer to as the Huang Agreement) with Mr. Huang effective February 1, 2019, under which he serves as our
Chief Investment Officer. We also entered into a share option agreement with Mr. Huang effective as of February 1, 2019.
The
Huang Agreement has an initial term beginning on February 1, 2019, and expiring one (1) year from such date. The Huang Agreement is subject
to automatic renewal on a year-to-year renewal basis unless either we or Mr. Huang provides written notice not to renew the Huang Agreement
no later than 30 days prior to the end of the then current or renewal term.
Pursuant
to the terms and provisions of the Huang Agreement, Mr. Huang is entitled to an annual base salary of $240,000 (Mr. Huang’s annual
base salary prior to the completion of our initial public offering was $150,000), cash bonuses as determined by our board of directors
or its designated committee in its sole discretion, participation in our 2018 Omnibus Equity Incentive Plan or similar equity incentive
plans, and other employee benefits as approved by our board of directors.
We
may terminate the Huang Agreement without cause upon 30 days’ prior written notice and Mr. Huang may resign without cause upon
30 days’ prior written notice. We may also immediately terminate Huang Agreement for cause (as set forth in the Huang Agreement).
Upon the termination of the Huang Agreement for any reason, Mr. Huang will be entitled to receive payment of any base salary earned but
unpaid through the date of termination and any other payment or benefit to which he is entitled under the applicable terms of any applicable
company arrangements. If Mr. Huang is terminated during the term of the employment agreement other than for cause, Mr. Huang is entitled
to, upon delivering to us a general release of our company and its affiliates in a form satisfactory to us, the amount of base salary
earned and not paid prior to termination and such severance payments as may be mandated by Indonesian law (presently one month of base
salary for every year worked with us) (the “Huang Severance Payment”). In the event that such termination is upon a Change
of Control (as defined in the Huang Agreement), Mr. Huang shall be entitled to the Huang Severance Payment. In addition, the Huang Agreement
will terminate prior to its scheduled expiration date in the event of Mr. Huang’s death or disability.
The
Huang Agreement also includes confidentiality and non-disclosure covenants as well as a twelve (12) month non-competition and non-solicitation
covenants. The Huang Agreement is governed by Cayman Islands law.
Under
Mr. Huang’s share option agreement, Mr. Huang was granted an option to purchase 150,000 ordinary shares under our 2018 Omnibus
Equity Incentive Plan at an exercise price equal to $11.00 per share. Mr. Huang’s option shall vest as follows (assuming, in each
case, that Mr. Huang remains employed with us): (a) 50,000 ordinary shares shall vest on the first anniversary of the closing of our
initial public offering, (b) 50,000 ordinary shares shall vest on the second anniversary of the closing of our initial public offering;
and (c) 50,000 ordinary shares shall vest on the third anniversary of the closing of our initial public offering. The share option agreement
is governed by Cayman Islands law.
Gregory
Overholtzer
On
February 27, 2019, our board of directors approved an employment agreement with Gregory Overholtzer and we entered into such agreement
(which we refer to as the Overholtzer Agreement) with Mr. Overholtzer effective February 1, 2019, under which he serves as our Chief
Financial Officer. On January 29, 2020 we and Mr. Overholtzer entered into an amendment to the Overholtzer Agreement (the “Overholtzer
Amendment”). On January 21, 2022, we entered into a Second Amendment to Employment Agreement (the “Overholtzer Second Amendment”).
The
Overholtzer Agreement had an initial term beginning on February 1, 2019, which expired one (1) year from such date. Pursuant to the Overholtzer
Amendment, Mr. Overholtzer’s employment term was extended for a two-year term commencing on February 1, 2020 and terminating on
January 31, 2020, and the Overholtzer Second Amendment further extends the term of the Overholtzer Agreement to December 31, 2023, unless
terminated earlier pursuant to the Overholtzer Agreement, as amended. The Overholtzer Agreement, as amended is not subject to automatic
renewal.
Pursuant
to the terms and provisions of the Overholtzer Agreement, as amended by the Overholtzer Amendment, Mr. Overholtzer was entitled to an
annual base salary of $40,000 until the effectiveness of our registration statement in connection with our IPO on December 19, 2019,
when his annual base salary increased to $80,000. Cash bonuses as determined by our board of directors or its designated committee in
its sole discretion, participation in our 2018 Omnibus Equity Incentive Plan or similar equity incentive plans, and other employee benefits
as approved by our board of directors.
We
may terminate the Overholtzer Agreement without cause upon 30 days’ prior written notice and Mr. Overholtzer may resign with or
without cause upon 30 days’ prior written notice. We may also immediately terminate Overholtzer Agreement for Cause (as set forth
in the Overholtzer Agreement). Upon the termination of the Overholtzer Agreement for any reason, Mr. Overholtzer will be entitled to
receive payment of any base salary earned but unpaid through the date of termination and any other payment or benefit to which he is
entitled under the applicable terms of any applicable company arrangements. If Mr. Overholtzer is terminated during the term of the employment
agreement other than for cause, Mr. Overholtzer is entitled to, upon delivering to us a general release of our company and its affiliates
in a form satisfactory to us, the amount of base salary earned and not paid prior to termination. In addition, the Overholtzer Agreement,
as amended will terminate prior to its scheduled expiration date in the event of Mr. Overholtzer’s death or disability.
The
Overholtzer Agreement also includes confidentiality and non-disclosure covenants as well as twelve (12) month non-competition and non-solicitation
covenant. The Overholtzer Agreement is governed by Cayman Islands law.
Chia
Hsin “Charlie” Wu
On
February 27, 2019, our board of directors approved an employment agreement with Chia Hsin “Charlie” Wu and we entered into
such agreements (which we refer to as the Wu Agreement) with Mr. Wu effective February 1, 2019, under which he serves as our Chief Operating
Officer. We also entered into a share option agreement with Mr. Wu effective as of February 1, 2019.
The
Wu Agreement has an initial term beginning on February 1, 2019, and expiring one (1) year from such date. The Wu Agreement is subject
to automatic renewal on a year-to-year renewal basis unless either we or Mr. Wu provides written notice not to renew the Wu Agreement
no later than 30 days prior to the end of the then current or renewal term.
Pursuant
to the terms and provisions of the Wu Agreement, Mr. Wu is entitled to an annual base salary of $204,000 following our initial public
offering (Mr. Wu’s annual base salary prior to the completion of our initial public offering was $75,000), cash bonuses as determined
by our board of directors or its designated committee in its sole discretion, participation in our 2018 Omnibus Equity Incentive Plan
or similar equity incentive plans, and other employee benefits as approved by our board of directors.
We
may terminate the Wu Agreement without cause upon 30 days’ prior written notice and Mr. Wu may resign without cause upon 30 days’
prior written notice. We may also immediately terminate Wu Agreement for cause (as set forth in the Wu Agreement). Upon the termination
of the Wu Agreement for any reason, Mr. Wu will be entitled to receive payment of any base salary earned but unpaid through the date
of termination and any other payment or benefit to which he is entitled under the applicable terms of any applicable company arrangements.
If Mr. Wu is terminated during the term of the employment agreement other than for cause, Mr. Wu is entitled to, upon delivering to us
a general release of our company and its affiliates in a form satisfactory to us, the amount of base salary earned and not paid prior
to termination and such severance payments as may be mandated by Indonesian law (presently one month of base salary for every year worked
with us) (the “Wu Severance Payment”). In the event that such termination is upon a Change of Control (as defined in the
Wu Agreement), Mr. Wu shall be entitled to the Wu Severance Payment. In addition, the Wu Agreement will terminate prior to its scheduled
expiration date in the event of Mr. Wu’s death or disability.
The
Wu Agreement also includes confidentiality and non-disclosure covenants as well as a twelve (12) month non-competition and non-solicitation
covenants. The Wu Agreement is governed by Cayman Islands law.
Under
Mr. Wu’s share option agreement, Mr. Wu was granted an option to purchase 150,000 ordinary shares under our 2018 Omnibus Equity
Incentive Plan at an exercise price equal $11.00 per share. Mr. Wu’s option shall vest as follows (assuming, in each case, that
Mr. Wu remains employed with us): (a) 50,000 ordinary shares shall vest on the first anniversary of the closing of our initial public
offering, (b) 50,000 ordinary shares shall vest on the second anniversary of the closing of our initial public offering; and (c) 50,000
ordinary shares shall vest on the third anniversary of the closing of our initial public offering. The share option agreement is governed
by Cayman Islands law.
Mirza
F. Said
On
February 27, 2019, our board of directors approved an employment agreement with Mirza F. Said and we entered into such agreements (which
we refer to as the Said Agreement) with Mr. Said effective February 1, 2019, under which he serves as Chief Business Development Officer.
We also entered into a share option agreement with Mr. Said effective as of February 1, 2019.
The
Said Agreement has an initial term beginning on February 1, 2019, and expiring one (1) year from such date. The Said Agreement is subject
to automatic renewal on a year-to-year renewal basis unless either we or Mr. Said provides written notice not to renew the Said Agreement
no later than 30 days prior to the end of the then current or renewal term.
Pursuant
to the terms and provisions of the Said Agreement, Mr. Said is entitled to an annual base salary of $204,000 following our initial public
offering (Mr. Said’s annual base salary prior to the completion of our initial public offering was $135,000), cash bonuses as determined
by our board of directors or its designated committee in its sole discretion, participation in our 2018 Omnibus Equity Incentive Plan
or similar equity incentive plans, and other employee benefits as approved by our board of directors.
We
may terminate the Said Agreement without cause upon 30 days’ prior written notice and Mr. Said may resign without cause upon 30
days’ prior written notice. We may also immediately terminate Said Agreement for cause (as set forth in the Said Agreement). Upon
the termination of the Said Agreement for any reason, Mr. Said will be entitled to receive payment of any base salary earned but unpaid
through the date of termination and any other payment or benefit to which he is entitled under the applicable terms of any applicable
company arrangements. If Mr. Said is terminated during the term of the employment agreement other than for cause, Mr. Said is entitled
to, upon delivering to us a general release of our company and its affiliates in a form satisfactory to us, the amount of base salary
earned and not paid prior to termination and such severance payments as may be mandated by Indonesian law (presently one month of base
salary for every year worked with us) (the “Said Severance Payment”). In the event that such termination is upon a Change
of Control (as defined in the Said Agreement), Mr. Said shall be entitled to the Said Severance Payment. In addition, the Said Agreement
will terminate prior to its scheduled expiration date in the event of Mr. Said’s death or disability.
The
Said Agreement also includes confidentiality and non-disclosure covenants as well as a twelve (12) month non-competition and non-solicitation
covenant. The Said Agreement is governed by Cayman Islands law.
Under
Mr. Said’s share option agreement, Mr. Said was granted an option to purchase 150,000 ordinary shares under our 2018 Omnibus Equity
Incentive Plan at an exercise price equal to $11.00 per share. Mr. Said’s option shall vest as follows (assuming, in each case,
that Mr. Said remains employed with us): (a) 50,000 ordinary shares shall vest on the first anniversary of the closing of our initial
public offering, (b) 50,000 ordinary shares shall vest on the second anniversary of the closing of our initial public offering; and (c)
50,000 ordinary shares shall vest on the third anniversary of the closing of our initial public offering. The share option agreement
is governed by Cayman Islands law.
2018
Omnibus Equity Incentive Plan
There
were no outstanding stock awards held by any of our executive officers as of December 31, 2018.
On
October 31, 2018, our board of directors and shareholders adopted a 2018 Omnibus Equity Incentive Plan for our company (which we refer
to as the 2018 Plan).
Purpose
The
purpose of our 2018 Plan is to attract and retain directors, officers, consultants, advisors and employees whose services are considered
valuable, to encourage a sense of proprietorship and to stimulate an active interest of such persons in our development and financial
achievements.
Administration
The
compensation committee of our board of directors (or the Compensation Committee) will have primary responsibility for administering the
2018 Plan. The Compensation Committee will have the authority to, among other things, the (a) determine terms and conditions of any option
or stock purchase right granted, including the exercise price and the vesting schedule, (b) determine the persons who are to receive
options and stock purchase rights and (c) determine the number of shares to be subject to each option and stock purchase right, (d) prescribe
any limitations, restrictions and conditions upon any awards, including the vesting conditions of awards, (e) determine if a grant will
be an “incentive” options (qualified under section 422 of the Internal Revenue Code of 1986, as amended, which is referred
to herein as the Code) to employees of our company or a non-qualified options to directors and consultants of our company, and (f) make
any other determination and take any other action that the Compensation Committee deems necessary or desirable for the administration
of the 2018 Plan. The Compensation Committee will have full discretion to administer and interpret the 2018 Plan and to adopt such rules,
regulations and procedures as it deems necessary or advisable and to determine, among other things, the time or times at which the awards
may be exercised and whether and under what circumstances an award may be exercised.
Eligibility
Our
employees, directors, officers and consultants (and those of any affiliated companies of ours) are eligible to participate in the 2018
Plan. The Compensation Committee has the authority to determine who will be granted an award under the 2018 Plan, however, it may delegate
such authority to one or more of our officers under the circumstances set forth in the 2018 Plan; provided, however, that all awards
made to non-employee Directors shall be determined by our board of directors in its sole discretion
Number
of Shares Authorized
Approximately
1,104,546 ordinary shares are reserved for issuance under our 2018 Plan.
If
an award is forfeited, canceled, or if any option terminates, expires or lapses without being exercised, the ordinary shares subject
to such award will again be made available for future grant. However, shares that are used to pay the exercise price of an option or
that are withheld to satisfy the Participant’s tax withholding obligation will not be available for re-grant under the 2018 Plan.
Awards
Available for Grant
The
Compensation Committee may grant awards of non-qualified share options, incentive share options, share appreciation rights, restricted
share awards, restricted share units, share bonus awards, performance compensation awards (including cash bonus awards) or any combination
of the foregoing, as each type of award is described in the 2018 Plan. Unless accelerated in accordance with the 2018 Plan, unvested
awards shall, if so determined by the Compensation Committee, terminate immediately upon the grantee resigning from or our terminating
the grantee’s employment or contractual relationship with us or any related company without cause, including death or disability.
Options
The
Compensation Committee is authorized to grant options to purchase ordinary shares that are either “qualified,” meaning they
are intended to satisfy the requirements of Code Section 422 for incentive stock options, or “non-qualified,” meaning they
are not intended to satisfy the requirements of Section 422 of the Code. Options granted under the 2018 Plan will be subject to the terms
and conditions established by the Compensation Committee. Under the terms of the 2018 Plan, unless the Compensation Committee determines
otherwise in the case of an option substituted for another option in connection with a corporate transaction, the exercise price of the
options will not be less than the fair market value (as determined under the 2018 Plan) of the ordinary shares on the date of grant.
Options granted under the 2018 Plan are subject to such terms, including the exercise price and the conditions and timing of exercise,
as may be determined by the Compensation Committee and specified in the applicable award agreement. The maximum term of an option granted
under the 2018 Plan is 10 years from the date of grant (or five years in the case of an incentive share option granted to a 10% shareholder).
Payment in respect of the exercise of an option may be made in cash or by check, by surrender of unrestricted ordinary shares (at their
fair market value on the date of exercise) that have been held by the participant for any period deemed necessary by our accountants
to avoid an additional compensation charge or have been purchased on the open market, or the Compensation Committee may, in its discretion
and to the extent permitted by law, allow such payment to be made through a broker-assisted cashless exercise mechanism, a net exercise
method, or by such other method as the Compensation Committee may determine to be appropriate.
Share
Appreciation Rights
The
Compensation Committee is authorized to award share appreciation rights (or SARs) under the 2018 Plan. SARs are subject to such terms
and conditions as established by the Compensation Committee. A SAR is a contractual right that allows a participant to receive, either
in the form of cash, shares or any combination of cash and shares, the appreciation, if any, in the value of a share over a certain period
of time. A SAR granted under the 2018 Plan may be granted in tandem with an option and SARs may also be awarded to a participant independent
of the grant of an option. SARs granted in connection with an option shall be subject to terms similar to the option which corresponds
to such SARs. SARs shall be subject to terms established by the Compensation Committee and reflected in the award agreement.
Restricted
shares
The
Compensation Committee is authorized to award restricted shares under the 2018 Plan. The Compensation Committee will determine the terms
of such restricted shares awards. Restricted shares are ordinary shares that generally are non-transferable and subject to other restrictions
determined by the Compensation Committee for a specified period. Unless the Compensation Committee determines otherwise or specifies
otherwise in an award agreement, if the participant terminates employment or services during the restricted period, then any unvested
restricted shares will be forfeited.
Restricted
share unit Awards
The
Compensation Committee is authorized to award restricted share unit awards. The Compensation Committee will determine the terms of such
restricted share units. Unless the Compensation Committee determines otherwise or specifies otherwise in an award agreement, if the participant
terminates employment or services during the period of time over which all or a portion of the units are to be earned, then any unvested
units will be forfeited.
Bonus
Share Awards
The
Compensation Committee is authorized to grant awards of unrestricted ordinary shares or other awards denominated in ordinary shares,
either alone or in tandem with other awards, under such terms and conditions as the Compensation Committee may determine.
Performance
Compensation Awards
The
Compensation Committee is authorized to grant any award under the 2018 Plan in the form of a Performance Compensation Award exempt from
the requirements of Section 162(m) of the Code by conditioning the vesting of the Award on the attainment of specific performance criteria
of our company and/or one or more of our affiliates, divisions or operational units, or any combination thereof, as determined by the
Compensation Committee. The Compensation Committee will select the performance criteria based on one or more of the following factors:
(i) revenue; (ii) sales; (iii) profit (net profit, gross profit, operating profit, economic profit, profit margins or other corporate
profit measures); (iv) earnings (EBIT, EBITDA, earnings per share, or other corporate profit measures); (v) net income (before or after
taxes, operating income or other income measures); (vi) cash (cash flow, cash generation or other cash measures); (vii) share price or
performance; (viii) total shareholder return (share price appreciation plus reinvested dividends divided by beginning share price); (ix)
economic value added; (x) return measures (including, but not limited to, return on assets, capital, equity, investments or sales, and
cash flow return on assets, capital, equity, or sales); (xi) market share; (xii) improvements in capital structure; (xiii) expenses (expense
management, expense ratio, expense efficiency ratios or other expense measures); (xiv) business expansion or consolidation (acquisitions
and divestitures); (xv) internal rate of return or increase in net present value; (xvi) working capital targets relating to inventory
and/or accounts receivable; (xvii) inventory management; (xviii) service or product delivery or quality; (xix) customer satisfaction;
(xx) employee retention; (xxi) safety standards; (xxii) productivity measures; (xxiii) cost reduction measures; and/or (xxiv) strategic
plan development and implementation.
Transferability
Each
award may be exercised during the participant’s lifetime only by the participant or, if permissible under applicable law, by the
participant’s guardian or legal representative and may not be otherwise transferred or encumbered by a participant other than by
will or by the laws of descent and distribution. The Compensation Committee, however, may permit options (other than incentive share
options) to be transferred to family members, a trust for the benefit of such family members, a partnership or limited liability company
whose partners or shareholders are the participant and his or her family members or anyone else approved by it.
Amendment
In
addition, our board of directors may amend, in whole or in part, our 2018 Plan at any time. However, without shareholder approval, except
that (a) any amendment or alteration shall be subject to the approval of the our shareholders if such shareholder approval is required
by any federal or state law or regulation or the rules of any stock exchange or automated quotation system on which the Shares may then
be listed or quoted, and (b) our board of directors may otherwise, in its discretion, determine to submit other such amendments or alterations
to shareholders for approval. Awards previously granted under the 2018 Plan may not be impaired or affected by any amendment of our 2018
Plan, without the consent of the affected grantees.
Change
in Control
The
2018 Plan provides that in the event of a change of control, the Compensation Committee shall, unless an outstanding award is assumed
by the surviving company or replaced with an equivalent award granted by the surviving company in substitution for such outstanding award
cancel any outstanding awards that are not vested and non-forfeitable as of the consummation of such corporate transaction (unless the
Compensation Committee, in its discretion, accelerates the vesting of any such awards). In respect to any vested and non-forfeitable
awards, the Compensation Committee may, in its discretion, (i) allow all grantees to exercise such awards within a reasonable period
prior to the consummation of the corporate transaction and cancel any outstanding awards that remain unexercised, or (ii) cancel any
or all of such outstanding awards in exchange for a payment (in cash, or in securities or other property, up to the sole discretion of
the Compensation Committee) in an amount equal to the amount that the grantee would have received if such vested awards were settled
or distributed or exercised immediately prior to the consummation of the corporate transaction.
Director
Compensation
Each
independent director receives cash compensation equal to $30,000 per year for such directors’ services to our board of directors.
The Chairman of the Board receives an additional $15,000 per year. In addition to the annual cash compensation for serving on our board
of directors, each independent director that also serves on a committee of our board of directors receives compensation as follows: each
member of the audit committee and compensation committee (not including the chairperson) receives annual cash compensation of $3,000
per year and each member of the Nominating and Corporate Governance Committee (not including the chairperson) receives annual cash compensation
of $3,000 per year. The chairperson of our Audit Committee receives annual compensation of $27,000 and the chairperson of our Compensation
Committee receives annual compensation of $6,000 and the chairperson of our Nominating and Corporate Governance Committee receives annual
compensation of $3,000.
Equity
Awards for Non-Employee Directors
As
of December 31, 2021, none of our non-employee directors were granted any options.
Employees
As
of December 31, 2021, we had 28 permanent employees and 35 contract employees, respectively. Our employees are not represented by a labor
organization or covered by a collective bargaining agreement. We have not experienced any work stoppages, and we believe we maintain
good relationships with our employees. The table below sets forth the breakdown of our employees by function as of December 31, 2021:
Function | |
Number of Employees | | |
% of Total | |
Senior Management | |
| 6 | | |
| 9.52 | % |
Subsurface | |
| 3 | | |
| 4.76 | % |
Engineering | |
| 3 | | |
| 4.76 | % |
Operation and Production | |
| 3 | | |
| 4.76 | % |
Finance and Accounting | |
| 6 | | |
| 9.52 | % |
Administration, Procurement and Human Resources | |
| 5 | | |
| 7.94 | % |
Health, Safety, Security and Environment (or HSSE) | |
| 1 | | |
| 1.59 | % |
Local Relations | |
| 1 | | |
| 1.59 | % |
Operation Contract Employees (production, construction and HSSE) | |
| 35 | | |
| 55.56 | % |
Total | |
| 63 | | |
| 100 | % |
We
believe that all of our contract employees for non-specialized job functions are replaceable in the marketplace, thus not representing
a material risk to our business. We believe we are in material compliance with Indonesian labor regulations.
Share
Ownership
Please
see Principal Shareholders for information relating to ownership of our securities by our directors, officers and certain major
shareholders.
CERTAIN
RELATIONSHIPS AND RELATED PARTY TRANSACTIONS
Other
than the executive and director compensation and other arrangements discussed in the “Management” section of this prospectus,
and the transactions described below, we have not entered into any transactions to which we or our subsidiaries have been or are a party
of the type which is required to be disclosed under Item 7 B. of Form 20-F.
On
January 30, 2019, WJ Energy entered into an interest free loan agreement with Maderic Holding Limited, shareholder of our company, in
the amount of $3,800,000, with maturity date on August 31, 2024, in preparation for the extension of the operatorship in Kruh Block in
the form of KSO. This loan agreement was fully repaid in 2019.
Our
audit committee is required to review and approve any related party transaction we propose to enter into. Our audit committee charter
details the policies and procedures relating to transactions that may present actual, potential or perceived conflicts of interest and
may raise questions as to whether such transactions are consistent with the best interest of our company and our stockholders.
PRINCIPAL
SHAREHOLDERS
The
following table sets forth information regarding the beneficial ownership of our ordinary shares as of the date of this prospectus by
our officers, directors, and 5% or greater beneficial owners of ordinary shares. There is no other person or group of affiliated persons
known by us to beneficially own more than 5% of our ordinary shares.
We
have determined beneficial ownership in accordance with the rules of the SEC. These rules generally attribute beneficial ownership of
securities to persons who possess sole or shared voting power or investment power with respect to those securities. The person is also
deemed to be a beneficial owner of any security of which that person has a right to acquire beneficial ownership within 60 days. Unless
otherwise indicated, the person identified in this table has sole voting and investment power with respect to all shares shown as beneficially
owned by him, subject to applicable community property laws. Percentage ownership of our ordinary shares in the following table is based
on 7,647,214 ordinary shares outstanding as of the date of this prospectus. Unless otherwise noted, the business address for each
of our directors and executive officers is GIESMART PLAZA 7th Floor, Jl. Raya Pasar Minggu No. 17A, Pancoran – Jakarta 12780 Indonesia.
| |
Ordinary Shares Beneficially Owned | |
Name of Beneficial Owners | |
Number | | |
% | |
Directors and Executive Officers: | |
| | | |
| | |
Dr. Wirawan Jusuf (1) | |
| 5,267,767 | | |
| 68.88 | % |
Frank C. Ingriselli (2) | |
| 37,079 | | |
| * | |
Mirza F. Said (3) | |
| 45,545 | | |
| * | |
James J. Huang (4) | |
| 45,545 | | |
| * | |
Chia Hsin “Charlie” Wu (5) | |
| 45,545 | | |
| * | |
Gregory L. Overholtzer | |
| — | | |
| — | |
Mochtar Hussein | |
| — | | |
| — | |
Benny Dharmawan | |
| — | | |
| — | |
Tamba P. Hutapea | |
| — | | |
| — | |
Michael L. Peterson | |
| — | | |
| — | |
All directors and officers as a group | |
| 5,441,481 | | |
| 71.56 | % |
5% shareholders: | |
| | | |
| | |
MADERIC Holding Limited (1) | |
| 5,222,222 | | |
| 68.29 | % |
HFO Investment Group Limited (6) | |
| 647,778 | | |
| 8.47 | % |
(1) |
Dr.
Wirawan Jusuf, our Chairman and Chief Executive Officer, holds voting and dispositive control over, and thus beneficial ownership
of, the shares held by MADERIC Holding Limited. Beneficial ownership excludes options to purchase 50,000 ordinary shares at
$11.00 per share which vest December 19, 2022 (the third anniversary of the closing of our initial public offering). |
(2) |
Beneficial
ownership excludes 60,000 ordinary shares awarded pursuant to the Ingriselli Second Amendment, with 30,000 shares vesting
on July 1, 2022 and 30,000 vesting on January 1, 2023. |
(3) |
Beneficial
ownership excludes options to purchase 50,000 ordinary shares at $11.00 per share which vest December 19, 2022 (the
third anniversary of the closing of our initial public offering). |
(4) |
Beneficial
ownership excludes options to purchase 50,000 ordinary shares at $11.00 per share which vest December 19, 2022 (the third
anniversary of the closing of our initial public offering). |
(5) |
Beneficial
ownership excludes options to purchase 50,000 ordinary shares at $11.00 per share which vest December 19, 2022 (the third
anniversary of the closing of our initial public offering). |
(6) |
Wan-Yu
Huang (the adult sister of James J. Huang, our Chief Investment Officer) has voting and dispositive control over the shares held
by HFO Investment Group Limited. The number of ordinary shares held by HFO Investment Group Limited decreased from 777,778 as of
June 12, 2020 due to the transfer of an aggregate of 130,000 ordinary shares by HFO Investment Group Limited to Chien-Chia Chiu and
Chien-Ta Chiu in January 2021. |
DESCRIPTION
OF SHARE CAPITAL
The
following description of our share capital and provisions of our amended and restated memorandum and articles of association are summaries
and do not purport to be complete. Reference is made to our amended and restated memorandum and articles of association, a copy of which
is filed as an exhibit to the registration statement of which this prospectus is a part (and which is referred to in this section as,
respectively, the “memorandum” and the “articles of association”).
Overview
We
were incorporated as a Cayman Islands exempted company with limited liability on April 24, 2018. Our affairs are governed by our amended
and restated memorandum and articles of association, as amended from time to time, and the Companies Law (Revised) of the Cayman Islands,
which is referred to below as the Companies Law.
A
Cayman Islands exempted company:
|
● |
is
a company that conducts its business mainly outside the Cayman Islands; |
|
● |
is
prohibited from trading in the Cayman Islands with any person, firm or corporation except in furtherance of the business of the exempted
company carried on outside the Cayman Islands (and for this purpose can effect and conclude contracts in the Cayman Islands and exercise
in the Cayman Islands all of its powers necessary for the carrying on of its business outside the Cayman Islands); |
|
● |
does
not have to hold an annual general meeting; |
|
● |
does
not have to make its register of members open to inspection by shareholders of that company; |
|
● |
may
obtain an undertaking against the imposition of any future taxation; |
|
● |
may
register by way of continuation in another jurisdiction and be deregistered in the Cayman Islands; |
|
● |
may
register as a limited duration company; and |
|
● |
may
register as a segregated portfolio company. |
Share
Capital
All
of our issued and outstanding ordinary shares are fully paid and non-assessable. Our ordinary shares are issued in registered form, and
are issued when registered in our register of members. Our shareholders who are non-residents of the Cayman Islands may freely hold and
vote their ordinary shares. We may not issue shares or warrants to bearer.
Our
authorized share capital is US$110,000 divided into 37,500,000 ordinary shares of US$0.00267 par value each and 3,750,000 preferred shares
of US$0.00267 par value each. Subject to the provisions of the Companies Law and our articles regarding redemption and purchase of the
shares, the directors have general and unconditional authority to allot (with or without confirming rights of renunciation), grant options
over or otherwise deal with any unissued shares to such persons, at such times and on such terms and conditions as they may decide. Such
authority could be exercised by the directors to allot shares which carry rights and privileges that are preferential to the rights attaching
to ordinary shares. No share may be issued at a discount except in accordance with the provisions of the Companies Law. The directors
may refuse to accept any application for shares, and may accept any application in whole or in part, for any reason or for no reason.
As
of the date of this prospectus, warrants to purchase an aggregate of 383,620 ordinary shares exercisable at $6.00 per share by January
21, 2027.
Amended
and Restated Memorandum and Articles of Association
Our
amended and restated memorandum and articles of association are subject to provisions of the Companies Law (see “Differences in
Corporate Law” below) and will include provisions to the following effects:
Share
Rights
Without
prejudice to any rights attached to any existing ordinary shares or class of shares, any share may be issued with such preferred, deferred
or other special rights or subject to such restrictions as we may determine by ordinary resolution or, subject to and in default of such
determination, as our board of directors shall determine. We may issue redeemable shares.
Our
amended and restated memorandum and articles of association provide that, subject to Cayman Islands law, all or any of the special rights
for the time being attached to the shares or any class of shares may, unless otherwise provided by the terms of issue of the shares of
that class, from time to time be varied, modified or abrogated with the sanction of a special resolution passed at a separate general
meeting of the holders of the shares of that class.
Voting
Rights
On
a show of hands every shareholder who is present in person and every person representing a shareholder by proxy shall have one vote.
On a poll, every shareholder who is present in person and every person representing a shareholder by proxy shall have one vote for each
share of which he or the person represented by proxy is the holder. In addition, all shareholders holding shares of a particular class
are entitled to vote at a meeting of the holders of that class of shares. Votes may be given either personally or by proxy.
Dividends
Subject
to the provisions of the Companies Law and any rights for the time being attaching to any class or classes of shares, the directors may
declare dividends or distributions out of our funds which are lawfully available for that purpose.
Subject
to the provisions of the Companies Law and any rights for the time being attaching to any class or classes of shares, our shareholders
may, by ordinary resolution, declare dividends but no such dividend shall exceed the amount recommended by the directors.
Subject
to the requirements of the Companies Law regarding the application of a company’s share premium account and with the sanction of
an ordinary resolution, dividends may also be declared and paid out of any share premium account. The directors when paying dividends
to shareholders may make such payment either in cash or in specie.
Unless
provided by the rights attached to a share, no dividend shall bear interest.
Variation
of Rights
Whenever
our capital is divided into different classes of shares, the rights attaching to any class of share (unless otherwise provided by the
terms of issue of the shares of that class) may be varied either with the consent in writing of the holders of not less than two-thirds
of the issued shares of that class, or with the sanction of a resolution passed by a majority of not less than two-thirds of the holders
of shares of the class present in person or by proxy at a separate general meeting of the holders of shares of that class.
Unless
the terms on which a class of shares was issued state otherwise, the rights conferred on the shareholder holding shares of any class
shall not be deemed to be varied by the creation or issue of further shares ranking pari passu with the existing shares of that class.
Alteration
of share capital
Subject
to the Companies Law, our company may, by ordinary resolution:
|
(a) |
increase
our share capital by new shares of the amount fixed by that ordinary resolution and with the attached rights, priorities and privileges
set out in that ordinary resolution; |
|
(b) |
consolidate
and divide all or any of our share capital into shares of larger amount than our existing shares; |
|
(c) |
convert
all or any of our paid up shares into stock, and reconvert that stock into paid up shares of any denomination; |
|
(d) |
sub-divide
our shares or any of them into shares of an amount smaller than that fixed, so, however, that in the sub-division, the proportion
between the amount paid and the amount, if any, unpaid on each reduced share shall be the same as it was in case of the share from
which the reduced share is derived; and |
|
(e) |
cancel
shares which, at the date of the passing of that ordinary resolution, have not been taken or agreed to be taken by any person and
diminish the amount of our share capital by the amount of the shares so cancelled or, in the case of shares without nominal par value,
diminish the number of shares into which our capital is divided. |
Subject
to the Companies Law and to any rights for the time being conferred on the shareholders holding a particular class of shares, we may,
by special resolution, reduce our share capital in any way.
Calls
on shares and forfeiture
Subject
to the terms of allotment, the directors may make calls on the shareholders in respect of any monies unpaid on their shares including
any premium and each shareholder shall (subject to receiving at least fourteen clear days’ notice specifying when and where payment
is to be made), pay to us the amount called on his shares. Shareholders registered as the joint holders of a share shall be jointly and
severally liable to pay all calls in respect of the share. If a call remains unpaid after it has become due and payable the person from
whom it is due and payable shall pay interest on the amount unpaid from the day it became due and payable until it is paid at the rate
fixed by the terms of allotment of the share or in the notice of the call or if no rate is fixed, at the rate of ten per cent. per annum.
The directors may waive payment of the interest wholly or in part.
We
have a first and paramount lien on all shares (whether fully paid up or not) registered in the name of a shareholder (whether solely
or jointly with others). The lien is for all monies payable to us by the shareholder or the shareholder’s estate:
|
(a) |
either
alone or jointly with any other person, whether or not that other person is a shareholder; and |
|
(b) |
whether
or not those monies are presently payable. |
At
any time the directors may declare any share to be wholly or partly exempt from the lien on shares provisions of the articles.
We
may sell, in such manner as the directors may determine, any share on which the sum in respect of which the lien exists is presently
payable, if due notice that such sum is payable has been given (as prescribed by the articles) and, within fourteen days of the date
on which the notice is deemed to be given under the articles, such notice has not been complied with.
Unclaimed
dividend
A
dividend that remains unclaimed for a period of six years after it became due for payment shall be forfeited to, and shall cease to remain
owing by, our company.
Forfeiture
or surrender of shares
If
a shareholder fails to pay any call the directors may give to such shareholder not less than fourteen clear days’ notice requiring
payment and specifying the amount unpaid including any interest which may have accrued, any expenses which have been incurred by us due
to that person’s default and the place where payment is to be made. The notice shall also contain a warning that if the notice
is not complied with, the shares in respect of which the call is made will be liable to be forfeited.
If
such notice is not complied with, the directors may, before the payment required by the notice has been received, resolve that any share
the subject of that notice be forfeited (which forfeiture shall include all dividends or other monies payable in respect of the forfeited
share and not paid before such forfeiture).
A
forfeited share may be sold, re-allotted or otherwise disposed of on such terms and in such manner as the directors determine and at
any time before a sale, re-allotment or disposition the forfeiture may be cancelled on such terms as the directors think fit.
A
person whose shares have been forfeited shall cease to be a shareholder in respect of the forfeited shares, but shall, notwithstanding
such forfeit, remain liable to pay to us all monies which at the date of forfeiture were payable by him to us in respect of the shares,
together with all expenses and interest from the date of forfeiture or surrender until payment, but his liability shall cease if and
when we receive payment in full of the unpaid amount.
A
declaration, whether statutory or under oath, made by a director or the secretary shall be conclusive evidence that the person making
the declaration is a director or secretary of our company and that the particular shares have been forfeited or surrendered on a particular
date.
Subject
to the execution of an instrument of transfer, if necessary, the declaration shall constitute good title to the shares.
Share
premium account
The
directors shall establish a share premium account and shall carry the credit of such account from time to time to a sum equal to the
amount or value of the premium paid on the issue of any share or capital contributed or such other amounts required by the Companies
Law.
Redemption
and purchase of own shares
Subject
to the Companies Law and any rights for the time being conferred on the shareholders holding a particular class of shares, we may by
our directors:
|
(a) |
issue
shares that are to be redeemed or liable to be redeemed, at our option or the shareholder holding those redeemable shares, on the
terms and in the manner its directors determine before the issue of those shares; |
|
(b) |
with
the consent by special resolution of the shareholders holding shares of a particular class, vary the rights attaching to that class
of shares so as to provide that those shares are to be redeemed or are liable to be redeemed at our option on the terms and in the
manner which the directors determine at the time of such variation; and |
|
(c) |
purchase
all or any of our own shares of any class including any redeemable shares on the terms and in the manner which the directors determine
at the time of such purchase. |
We
may make a payment in respect of the redemption or purchase of its own shares in any manner authorized by the Companies Law, including
out of any combination of capital, our profits and the proceeds of a fresh issue of shares.
When
making a payment in respect of the redemption or purchase of shares, the directors may make the payment in cash or in specie (or partly
in one and partly in the other) if so authorized by the terms of the allotment of those shares or by the terms applying to those shares,
or otherwise by agreement with the shareholder holding those shares.
Transfer
of Shares
Subject
to the restrictions contained in our articles, any of our shareholders may transfer all or any of his or her shares by an instrument
of transfer in any usual or common form or any other form approved by our board of directors, executed by or on behalf of the transferor
(and, if in respect of a nil or partly paid up share, or if so required by our directors, by or on behalf of the transferee) and shall
be accompanied by the certificate (if any) of the shares to which it relates and such other evidence as the directors may reasonably
require to show the right of the transferor to make the transfer.
Our
board of directors may, in its absolute discretion, decline to register any transfer of any share that has not been fully paid up or
is subject to a company lien. Our board of directors may also decline to register any transfer of any shares unless:
|
(a) |
the
instrument of transfer is lodged with us, accompanied by the certificate for the shares to which it relates and such other evidence
as our board of directors may reasonably require to show the right of the transferor to make the transfer; |
|
(b) |
the
instrument of transfer is in respect of only one class of shares; |
|
(c) |
the
instrument of transfer is properly stamped, if required; |
|
(d) |
the
share transferred is fully paid up and free of any lien in favor of our company; |
|
(e) |
any
fee related to the transfer has been paid to us; and |
|
(f) |
the
transfer is not to more than four joint holders. |
If
our directors refuse to register a transfer, they are required, within three months after the date on which the instrument of transfer
was lodged, to send to each of the transferor and the transferee notice of such refusal.
The
registration of transfers may, on 14 calendar days’ notice being given by advertisement in such one or more newspapers or by electronic
means, be suspended and our register of members closed at such times and for such periods as our board of directors may from time to
time determine. However, the registration of transfers may not be suspended, and the register may not be closed, for more than 30 days
in any year.
Inspection
of Books and Records
Holders
of our shares will have no general right under the Companies Law to inspect or obtain copies of our register of members or our corporate
records.
General
Meetings
As
a Cayman Islands exempted company, we are not obligated by the Companies Law to call shareholders’ annual general meetings; accordingly,
we may, but shall not be obliged to, in each year hold a general meeting as an annual general meeting. Any annual general meeting held
shall be held at such time and place as may be determined by our board of directors. All general meetings other than annual general meetings
shall be called extraordinary general meetings.
The
directors may convene general meetings whenever they think fit. General meetings shall also be convened on the written requisition of
one or more of the shareholders entitled to attend and vote at our general meetings who (together) hold not less than ten per cent of
the rights to vote at such general meeting in accordance with the notice provisions in the articles, specifying the purpose of the meeting
and signed by each of the shareholders making the requisition. If the directors do not convene such meeting for a date not later than
twenty-one clear days’ after the date of receipt of the written requisition, those shareholders who requested the meeting may convene
the general meeting themselves within three months after the end of such period of twenty-one clear days in which case reasonable expenses
incurred by them as a result of the directors failing to convene a meeting shall be reimbursed by us.
At
least fourteen days’ notice of an extraordinary general meeting and twenty-one days’ notice of an annual general meeting
shall be given to shareholders entitled to attend and vote at such meeting. The notice shall specify the place, the day and the hour
of the meeting and the general nature of that business. In addition, if a resolution is proposed as a special resolution, the text of
that resolution shall be given to all shareholders. Notice of every general meeting shall also be given to the directors and our auditors.
Subject
to the Companies Law and with the consent of the shareholders who, individually or collectively, hold at least ninety per cent. of the
voting rights of all those who have a right to vote at a general meeting, a general meeting may be convened on shorter notice.
A
quorum shall consist of the presence of one or more shareholders holding shares that represent not less than one-third of the outstanding
shares carrying the right to vote at such general meeting.
If,
within fifteen minutes from the time appointed for the general meeting, or at any time during the meeting, a quorum is not present, the
meeting, if convened upon the requisition of shareholders, shall be cancelled. In any other case it shall stand adjourned to the same
time and place seven days or to such other time or place as is determined by the directors.
The
chairman may, with the consent of a meeting at which a quorum is present, adjourn the meeting. When a meeting is adjourned for seven
days or more, notice of the adjourned meeting shall be given in accordance with the articles.
At
any general meeting a resolution put to the vote of the meeting shall be decided on a show of hands, unless a poll is (before, or on,
the declaration of the result of the show of hands) demanded by the chairman of the meeting or by at least two shareholders having the
right to vote on the resolutions or one or more shareholders present who together hold at least ten per cent. of the voting rights of
all those who are entitled to vote on the resolution. Unless a poll is so demanded, a declaration by the chairman as to the result of
a resolution and an entry to that effect in the minutes of the meeting, shall be conclusive evidence of the outcome of a show of hands,
without proof of the number or proportion of the votes recorded in favor of, or against, that resolution.
If
a poll is duly demanded it shall be taken in such manner as the chairman directs and the result of the poll shall be deemed to be the
resolution of the meeting at which the poll was demanded.
In
the case of an equality of votes, whether on a show of hands or on a poll, the chairman of the meeting at which the show of hands takes
place or at which the poll is demanded, shall not be entitled to a second or casting vote.
Directors
We
may by ordinary resolution, from time to time, fix the maximum and minimum number of directors to be appointed. Under the articles, we
are required to have a minimum of one director and a maximum of nine directors.
A
director may be appointed by ordinary resolution or by the directors. Any appointment may be to fill a vacancy or as an additional director.
The
remuneration of the directors shall be determined by the shareholders by ordinary resolution, except that the directors shall be entitled
to such remuneration as the directors may determine.
The
shareholding qualification for directors may be fixed by our shareholders by ordinary resolution and unless and until so fixed no share
qualification shall be required.
Unless
removed or re-appointed, each director shall be appointed for a term expiring at the next-following annual general meeting, if one is
held. At any annual general meeting held, our directors will be elected by an ordinary resolution of our shareholders. At each annual
general meeting, each director so elected shall hold office for a one-year term and until the election of their respective successors
in office or removed.
A
director may be removed by ordinary resolution.
A
director may at any time resign or retire from office by giving us notice in writing. Unless the notice specifies a different date, the
director shall be deemed to have resigned on the date that the notice is delivered to us.
Subject
to the provisions of the articles, the office of a director may be terminated forthwith if:
|
(a) |
he
is prohibited by the law of the Cayman Islands from acting as a director; |
|
(b) |
he
is made bankrupt or makes an arrangement or composition with his creditors generally; |
|
(c) |
he
resigns his office by notice to us; |
|
(d) |
he
only held office as a director for a fixed term and such term expires; |
|
(e) |
in
the opinion of a registered medical practitioner by whom he is being treated he becomes physically or mentally incapable of acting
as a director; |
|
(f) |
he
is given notice by the majority of the other directors (not being less than two in number) to vacate office (without prejudice to
any claim for damages for breach of any agreement relating to the provision of the services of such director); |
|
(g) |
he
is made subject to any law relating to mental health or incompetence, whether by court order or otherwise; or |
|
(h) |
without
the consent of the other directors, he is absent from meetings of directors for continuous period of six months. |
Powers
and duties of directors
Subject
to the provisions of the Companies Law, our amended and restated memorandum and articles of association, our business shall be managed
by the directors, who may exercise all our powers. No prior act of the directors shall be invalidated by any subsequent alteration of
our amended and restated memorandum or articles of association. However, to the extent allowed by the Companies Law, shareholders may
by special resolution validate any prior or future act of the directors which would otherwise be in breach of their duties.
The
directors may delegate any of their powers to any committee consisting of one or more persons who need not be shareholders and may include
non-directors so long as the majority of those persons are directors; any committee so formed shall in the exercise of the powers so
delegated conform to any regulations that may be imposed on it by the directors. Our board of directors has established three standing
committees – the audit committee, the compensation committee and the nomination and corporate governance committee.
Our
board of directors may establish any local or divisional board of directors or agency and delegate to it its powers and authorities (with
power to sub-delegate) for managing any of our affairs whether in the Cayman Islands or elsewhere and may appoint any persons to be members
of a local or divisional board of directors, or to be managers or agents, and may fix their remuneration.
The
directors may from time to time and at any time by power of attorney or in any other manner they determine appoint any person, either
generally or in respect of any specific matter, to be our agent with or without authority for that person to delegate all or any of that
person’s powers.
The
directors may from time to time and at any time by power of attorney or in any other manner they determine appoint any person, whether
nominated directly or indirectly by the directors, to be our attorney or our authorized signatory and for such period and subject to
such conditions as they may think fit. The powers, authorities and discretions, however, must not exceed those vested in, or exercisable,
by the directors under the articles.
Our
board of directors may remove any person so appointed and may revoke or vary the delegation.
The
directors may exercise all of our powers to borrow money and to mortgage or charge its undertaking, property and assets both present
and future and uncalled capital or any part thereof, to issue debentures and other securities whether outright or as collateral security
for any debt, liability or obligation of ours or our parent undertaking (if any) or any subsidiary undertaking of our company or of any
third party.
A
director shall not, as a director, vote in respect of any contract, transaction, arrangement or proposal in which he has an interest
which (together with any interest of any person connected with him) is a material interest (otherwise then by virtue of his interests,
direct or indirect, in shares or debentures or other securities of, or otherwise in or through, us) and if he shall do so his vote shall
not be counted, nor in relation thereto shall he be counted in the quorum present at the meeting, but (in the absence of some other material
interest than is mentioned below) none of these prohibitions shall apply to:
|
(a) |
the
giving of any security, guarantee or indemnity in respect of: |
|
(i) |
money
lent or obligations incurred by him or by any other person for our benefit or any of our subsidiaries; or |
|
(ii) |
a
debt or obligation of ours or any of our subsidiaries for which the director himself has assumed responsibility in whole or in part
and whether alone or jointly with others under a guarantee or indemnity or by the giving of security; |
|
(b) |
where
we or any of our subsidiaries is offering securities in which offer the director is or may be entitled to participate as a holder
of securities or in the underwriting or sub-underwriting of which the director is to or may participate; |
|
(c) |
any
contract, transaction, arrangement or proposal affecting any other body corporate in which he is interested, directly or indirectly
and whether as an officer, shareholder, creditor or otherwise howsoever, provided that he (together with persons connected with him)
does not to his knowledge hold an interest representing one per cent or more of any class of the equity share capital of such body
corporate (or of any third body corporate through which his interest is derived) or of the voting rights available to shareholders
of the relevant body corporate; |
|
(d) |
any
act or thing done or to be done in respect of any arrangement for the benefit of the employees of ours or any of our subsidiaries
under which he is not accorded as a director any privilege or advantage not generally accorded to the employees to whom such arrangement
relates; or |
|
(e) |
any
matter connected with the purchase or maintenance for any director of insurance against any liability or (to the extent permitted
by the Companies Law) indemnities in favor of directors, the funding of expenditure by one or more directors in defending proceedings
against him or them or the doing of anything to enable such director or directors to avoid incurring such expenditure. |
A
director may, as a director, vote (and be counted in the quorum) in respect of any contract, transaction, arrangement or proposal in
which he has an interest which is not a material interest or as described above.
Capitalization
of profits
The
directors may resolve to capitalize:
|
(a) |
any
part of our profits not required for paying any preferential dividend (whether or not those profits are available for distribution);
or |
|
(b) |
any
sum standing to the credit of our share premium account or capital redemption reserve, if any. |
The
amount resolved to be capitalized must be appropriated to the shareholders who would have been entitled to it had it been distributed
by way of dividend and in the same proportions.
Liquidation
Rights
If
we are wound up, the shareholders may, subject to the articles and any other sanction required by the Companies Law, pass a special resolution
allowing the liquidator to do either or both of the following:
|
(a) |
to
divide in specie among the shareholders the whole or any part of our assets and, for that purpose, to value any assets and to determine
how the division shall be carried out as between the shareholders or different classes of shareholders; and |
|
(b) |
to
vest the whole or any part of the assets in trustees for the benefit of shareholders and those liable to contribute to the winding
up. |
The
directors have the authority to present a petition for our winding up to the Grand Court of the Cayman Islands on our behalf without
the sanction of a resolution passed at a general meeting.
Register
of Members
Under
the Companies Law, we must keep a register of members and there should be entered therein:
|
● |
the
names and addresses of our shareholders, a statement of the shares held by each shareholder, and of the amount paid or agreed to
be considered as paid, on the shares of each shareholder; |
|
● |
the
date on which the name of any person was entered on the register as a shareholder; and |
|
● |
the
date on which any person ceased to be a shareholder. |
Under
the Companies Law, the register of members of our company is prima facie evidence of the matters set out therein (that is, the register
of members will raise a presumption of fact on the matters referred to above unless rebutted) and a shareholder registered in the register
of members is deemed as a matter of the Companies Law to have legal title to the shares as set against its name in the register of members.
Upon a new issuance of ordinary shares by us, the register of members will be updated to record and give effect to such issuance of ordinary
shares.. Once our register of members has been updated, the shareholders recorded in the register of members will be deemed to have legal
title to the shares set against their name.
If
the name of any person is incorrectly entered in or omitted from our register of members, or if there is any default or unnecessary delay
in entering on the register the fact of any person having ceased to be a shareholder of our company, the person or shareholder aggrieved
(or any shareholder of our company or our company itself) may apply to the Grand Court of the Cayman Islands for an order that the register
be rectified, and the Court may either refuse such application or it may, if satisfied of the justice of the case, make an order for
the rectification of the register.
Differences
in Corporate Law
The
Companies Law is derived, to a large extent, from the older Companies Acts of England and Wales but does not follow recent United Kingdom
statutory enactments, and accordingly there are significant differences between the Companies Law and the current Companies Act of England.
In addition, the Companies Law differs from laws applicable to United States corporations and their shareholders. Set forth below is
a summary of certain significant differences between the provisions of the Companies Law applicable to us and the comparable laws applicable
to companies incorporated in the State of Delaware in the United States.
Mergers
and Similar Arrangements
The
Companies Law permits mergers and consolidations between Cayman Islands companies and between Cayman Islands companies and non-Cayman
Islands companies. For these purposes, (a) “merger” means the merging of two or more constituent companies and the vesting
of their undertaking, property and liabilities in one of such companies as the surviving company, and (b) a “consolidation”
means the combination of two or more constituent companies into a consolidated company and the vesting of the undertaking, property and
liabilities of such companies to the consolidated company. In order to effect such a merger or consolidation, the directors of each constituent
company must approve a written plan of merger or consolidation, which must then be authorized by (a) a special resolution of the shareholders
of each constituent company, and (b) such other authorization, if any, as may be specified in such constituent company’s articles
of association. The plan must be filed with the Registrar of Companies together with a declaration as to the solvency of the consolidated
or surviving company, a list of the assets and liabilities of each constituent company and an undertaking that a copy of the certificate
of merger or consolidation will be given to the shareholders and creditors of each constituent company and that notification of the merger
or consolidation will be published in the Cayman Islands Gazette. Court approval is not required for a merger or consolidation which
is effected in compliance with these statutory procedures.
A
merger between a Cayman parent company and its Cayman subsidiary or subsidiaries does not require authorization by a resolution of shareholders.
For this purpose a subsidiary is a company of which at least 90% of the issued shares entitled to vote are owned by the parent company.
The
consent of each holder of a fixed or floating security interest of a constituent company is required unless this requirement is waived
by a court in the Cayman Islands.
Except
in certain limited circumstances, a dissenting shareholder of a Cayman Islands constituent company is entitled to payment of the fair
value of his or her shares upon dissenting from a merger or consolidation. The exercise of such dissenter rights will preclude the exercise
by the dissenting shareholder of any other rights to which he or she might otherwise be entitled by virtue of holding shares, except
for the right to seek relief on the grounds that the merger or consolidation is void or unlawful.
In
addition, there are statutory provisions that facilitate the reconstruction and amalgamation of companies, provided that the arrangement
is approved by a majority in number of each class of shareholders and creditors with whom the arrangement is to be made, and who must,
in addition, represent three-fourths in value of each such class of shareholders or creditors, as the case may be, that are present and
voting either in person or by proxy at a meeting, or meetings, convened for that purpose. The convening of the meetings and subsequently
the arrangement must be sanctioned by the Grand Court of the Cayman Islands. While a dissenting shareholder has the right to express
to the court the view that the transaction ought not to be approved, the court can be expected to approve the arrangement if it determines
that:
|
(a) |
the
statutory provisions as to the required majority vote have been met; |
|
(b) |
the
shareholders have been fairly represented at the meeting in question and the statutory majority are acting bona fide without coercion
of the minority to promote interests adverse to those of the class; |
|
(c) |
the
arrangement is such that may be reasonably approved by an intelligent and honest man of that class acting in respect of his interest;
and |
|
(d) |
the
arrangement is not one that would more properly be sanctioned under some other provision of the Companies Law. |
When
a takeover offer is made and accepted by holders of 90% of the shares affected within four months the offeror may, within a two-month
period commencing on the expiration of such four month period, require the holders of the remaining shares to transfer such shares on
the terms of the offer. An objection can be made to the Grand Court of the Cayman Islands but this is unlikely to succeed in the case
of an offer which has been so approved unless there is evidence of fraud, bad faith or collusion.
If
an arrangement and reconstruction is thus approved, or if a takeover offer is made and accepted, a dissenting shareholder would have
no rights comparable to appraisal rights, which would otherwise ordinarily be available to dissenting shareholders of Delaware corporations,
providing rights to receive payment in cash for the judicially determined value of the shares.
Shareholders’
Suits
In
principle, we will normally be the proper plaintiff to sue for a wrong done to us as a company and as a general rule, a derivative action
may not be brought by a minority shareholder. However, based on English law authorities, which would in all likelihood be of persuasive
authority in the Cayman Islands, the Cayman Islands courts can be expected to follow and apply the common law principles (namely the
rule in Foss v. Harbottle and the exceptions thereto) so that a non-controlling shareholder may be permitted to commence a class
action against or derivative actions in the name of the company to challenge:
|
(a) |
an
act which is illegal or ultra vires with respect to the company and is therefore incapable of ratification by the shareholders; |
|
(b) |
an
act which, although not ultra vires, requires authorization by a qualified (or special) majority (that is, more than a simple majority)
which has not been obtained; and |
|
(c) |
an
act which constitutes a “fraud on the minority” where the wrongdoers are themselves in control of the company. |
Directors’
Fiduciary Duties
Under
Delaware corporate law, a director of a Delaware corporation has a fiduciary duty to the corporation and its shareholders. This duty
has two components: the duty of care and the duty of loyalty. The duty of care requires that a director act in good faith, with the care
that an ordinarily prudent person would exercise under similar circumstances. Under this duty, a director must inform himself of, and
disclose to shareholders, all material information reasonably available regarding a significant transaction. The duty of loyalty requires
that a director act in a manner he or she reasonably believes to be in the best interests of the corporation. He or she must not use
his or her corporate position for personal gain or advantage. This duty prohibits self-dealing by a director and mandates that the best
interests of the corporation and its shareholders take precedence over any interest possessed by a director, officer or controlling shareholder
and not shared by the shareholders generally. In general, actions of a director are presumed to have been made on an informed basis,
in good faith and in the honest belief that the action taken was in the best interests of the corporation. However, this presumption
may be rebutted by evidence of a breach of one of the fiduciary duties. Should such evidence be presented concerning a transaction by
a director, a director must prove the procedural fairness of the transaction, and that the transaction was of fair value to the corporation.
As
a matter of Cayman Islands law, a director owes three types of duties to the company: (a) statutory duties, (b) fiduciary duties, and
(iii) common law duties. The Companies Law imposes a number of statutory duties on a director. A Cayman Islands director’s fiduciary
duties are not codified, however the courts of the Cayman Islands have held that a director owes the following fiduciary duties (a) a
duty to act in what the director bona fide considers to be in the best interests of the company, (b) a duty to exercise their powers
for the purposes they were conferred, (c) a duty to avoid fettering his or her discretion in the future and (d) a duty to avoid conflicts
of interest and of duty. The common law duties owed by a director are those to act with skill, care and diligence that may reasonably
be expected of a person carrying out the same functions as are carried out by that director in relation to the company and, also, to
act with the skill, care and diligence in keeping with a standard of care commensurate with any particular skill they have which enables
them to meet a higher standard than a director without those skills. In fulfilling their duty of care to us, our directors must ensure
compliance with our amended articles of association, as amended and restated from time to time. We have the right to seek damages if
a duty owed by any of our directors is breached.
Shareholder
Proposals
Under
the Delaware General Corporation Law, a shareholder has the right to put any proposal before the annual meeting of shareholders, provided
it complies with the notice provisions in the governing documents. The Delaware General Corporation Law does not provide shareholders
an express right to put any proposal before the annual meeting of shareholders, but in keeping with common law, Delaware corporations
generally afford shareholders an opportunity to make proposals and nominations provided that they comply with the notice provisions in
the certificate of incorporation or bylaws. A special meeting may be called by the board of directors or any other person authorized
to do so in the governing documents, but shareholders may be precluded from calling special meetings.
The
Companies Law provides shareholders with only limited rights to requisition a general meeting, and does not provide shareholders with
any right to put any proposal before a general meeting. However, these rights may be provided in a company’s articles of association.
Our articles provide that general meetings shall be convened on the written requisition of one or more of the shareholders entitled to
attend and vote at our general meetings who (together) hold not less than ten per cent of the rights to vote at such general meeting
in accordance with the notice provisions in the articles, specifying the purpose of the meeting and signed by each of the shareholders
making the requisition. If the directors do not convene such meeting for a date not later than twenty-one clear days’ after the
date of receipt of the written requisition, those shareholders who requested the meeting may convene the general meeting themselves within
three months after the end of such period of twenty-one clear days in which case reasonable expenses incurred by them as a result of
the directors failing to convene a meeting shall be reimbursed by us.. Our articles provide no other right to put any proposals before
annual general meetings or extraordinary general meetings. As a Cayman Islands exempted company, we are not obligated by law to call
shareholders’ annual general meetings. However, our corporate governance guidelines require us to call such meetings every year.
Cumulative
Voting
Under
the Delaware General Corporation Law, cumulative voting for elections of directors is not permitted unless the corporation’s certificate
of incorporation specifically provides for it. Cumulative voting potentially facilitates the representation of minority shareholders
on a board of directors since it permits the minority shareholder to cast all the votes to which the shareholder is entitled on a single
director, which increases the shareholder’s voting power with respect to electing such director. As permitted under the Companies
Law, our articles do not provide for cumulative voting. As a result, our shareholders are not afforded any less protections or rights
on this issue than shareholders of a Delaware corporation.
Removal
of Directors
Under
the Delaware General Corporation Law, a director of a corporation with a classified board may be removed only for cause with the approval
of a majority of the outstanding shares entitled to vote, unless the certificate of incorporation provides otherwise. Subject to the
provisions of our articles (which include the removal of a director by ordinary resolution), the office of a director may be terminated
forthwith if (a) he is prohibited by the laws of the Cayman Islands from acting as a director, (b) he is made bankrupt or makes an arrangement
or composition with his creditors generally, (c) he resigns his office by notice to us, (d) he only held office as a director for a fixed
term and such term expires, (e) in the opinion of a registered medical practitioner by whom he is being treated he becomes physically
or mentally incapable of acting as a director, (f) he is given notice by the majority of the other directors (not being less than two
in number) to vacate office (without prejudice to any claim for damages for breach of any agreement relating to the provision of the
services of such director), (g) he is made subject to any law relating to mental health or incompetence, whether by court order or otherwise,
or (h) without the consent of the other directors, he is absent from meetings of directors for continuous period of six months.
Transactions
with Interested Shareholders
The
Delaware General Corporation Law contains a business combination statute applicable to Delaware public corporations whereby, unless the
corporation has specifically elected not to be governed by such statute by amendment to its certificate of incorporation or bylaws that
is approved by its shareholders, it is prohibited from engaging in certain business combinations with an “interested shareholder”
for three years following the date that such person becomes an interested shareholder. An interested shareholder generally is a person
or a group who or which owns or owned 15% or more of the target’s outstanding voting stock or who or which is an affiliate or associate
of the corporation and owned 15% or more of the corporation’s outstanding voting stock within the past three years. This has the
effect of limiting the ability of a potential acquirer to make a two-tiered bid for the target in which all shareholders would not be
treated equally. The statute does not apply if, among other things, prior to the date on which such shareholder becomes an interested
shareholder, the board of directors approves either the business combination or the transaction which resulted in the person becoming
an interested shareholder. This encourages any potential acquirer of a Delaware corporation to negotiate the terms of any acquisition
transaction with the target’s board of directors.
The
Companies Law has no comparable statute. As a result, we cannot avail ourselves of the types of protections afforded by the Delaware
business combination statute. However, although the Companies Law does not regulate transactions between a company and its significant
shareholders, under Cayman Islands law such transactions must be entered into bona fide in the best interests of the company and for
a proper corporate purpose and not with the effect of constituting a fraud on the minority shareholders.
Dissolution;
Winding Up
Under
the Delaware General Corporation Law, unless the board of directors approves the proposal to dissolve, dissolution must be approved by
shareholders holding 100% of the total voting power of the corporation. Only if the dissolution is initiated by the board of directors
may it be approved by a simple majority of the corporation’s outstanding shares. Delaware law allows a Delaware corporation to
include in its certificate of incorporation a supermajority voting requirement in connection with dissolutions initiated by the board
of directors.
Under
the Companies Law and our articles, we may be wound up by a special resolution of our shareholders, or if the winding up is initiated
by our board of directors, by either a special resolution of our members or, if our company is unable to pay its debts as they fall due,
by an ordinary resolution of our members. In addition, a company may be wound up by an order of the courts of the Cayman Islands. The
court has authority to order winding up in a number of specified circumstances including where it is, in the opinion of the court, just
and equitable to do so.
Variation
of Rights of Shares
Under
the Delaware General Corporation Law, a corporation may vary the rights of a class of shares with the approval of a majority of the outstanding
shares of such class, unless the certificate of incorporation provides otherwise. Under the Companies Law and our articles, if our share
capital is divided into more than one class of shares, the rights attaching to any class of share (unless otherwise provided by the terms
of issue of the shares of that class) may be varied either with the consent in writing of the holders of not less than two-thirds of
the issued shares of that class, or with the sanction of a resolution passed by a majority of not less than two-thirds of the holders
of shares of the class present in person or by proxy at a separate general meeting of the holders of shares of that class.
Amendment
of Governing Documents
Under
the Delaware General Corporation Law, a corporation’s certificate of incorporation may be amended only if adopted and declared
advisable by the board of directors and approved by a majority of the outstanding shares entitled to vote, and the bylaws may be amended
with the approval of a majority of the outstanding shares entitled to vote and may, if so provided in the certificate of incorporation,
also be amended by the board of directors. Under the Companies Law, our articles may only be amended by special resolution of our shareholders.
Anti-Takeover
Provisions in Our Articles
Some
provisions of our articles may discourage, delay or prevent a change in control of our company or management that shareholders may consider
favorable, including provisions that authorize our board of directors to issue shares at such times and on such terms and conditions
as the board of directors may decide without any further vote or action by our shareholders.
Under
the Companies Law, our directors may only exercise the rights and powers granted to them under our articles for what they believe in
good faith to be in the best interests of our company and for a proper purpose.
Anti-money
Laundering—Cayman Islands
In
order to comply with legislation or regulations aimed at the prevention of money laundering, we are required to adopt and maintain anti-money
laundering procedures, and may require subscribers to provide evidence to verify their identity. Where permitted, and subject to certain
conditions, we may also delegate the maintenance of our anti-money laundering procedures (including the acquisition of due diligence
information) to a suitable person.
We
reserve the right to request such information as is necessary to verify the identity of a subscriber. In the event of delay or failure
on the part of the subscriber in producing any information required for verification purposes, we may refuse to accept the application,
in which case any funds received will be returned without interest to the account from which they were originally debited.
We
also reserve the right to refuse to make any redemption payment to a shareholder if our directors or officers suspect or are advised
that the payment of redemption proceeds to such shareholder might result in a breach of applicable anti-money laundering or other laws
or regulations by any person in any relevant jurisdiction, or if such refusal is considered necessary or appropriate to ensure our compliance
with any such laws or regulations in any applicable jurisdiction.
If
any person resident in the Cayman Islands knows or suspects or has reason for knowing or suspecting that another person is engaged in
criminal conduct or is involved with terrorism or terrorist property and the information for that knowledge or suspicion came to their
attention in the course of their business in the regulated sector, or other trade, profession, business or employment, the person will
be required to report such knowledge or suspicion to (i) a nominated officer (appointed in accordance with the Proceeds of Crime Law
(Revised) of the Cayman Islands) or the Financial Reporting Authority of the Cayman Islands, pursuant to the Proceeds of Crime Law (Revised),
if the disclosure relates to criminal conduct or money laundering or (ii) to a police constable or a nominated officer (pursuant to the
Terrorism Law (Revised) of the Cayman Islands) or the Financial Reporting Authority, pursuant to the Terrorism Law (Revised), if the
disclosure relates to involvement with terrorism or terrorist financing and terrorist property. Such a report shall not be treated as
a breach of confidence or of any restriction upon the disclosure of information imposed by any enactment or otherwise.
SELLING
SHAREHOLDER
We
issued the Note and the Warrants to the Selling Shareholder in January 2022 (as amended in March 2022) in connection with the
transactions described below. References below to the “Note” shall refer to the Replacement Note which was issued to L1
Capital on March 4, 2022.
Closing
of First Tranche
On
the Initial Closing Date, we closed the First Tranche for a principal amount of $5,000,000 of then anticipated total $7,000,000 million
private placement with L1 Capital pursuant to the terms of the Purchase Agreement. In connection with the closing of the First
Tranche, we issued to L1 Capital (i) a 6% Original Issuance Discount Note in a principal amount of up to $7,000,000 (which was
subsequently expanded to $10,000,000 pursuant to the L1 Amendment) and (ii) a five year Initial Warrant to purchase up to
383,620 of our ordinary shares at an exercise price of $6.00 per share, subject to adjustment as described below.
Within
two (2) trading days of the declaration of effectiveness of the registration statement of which this prospectus forms a part, and subject
to the satisfaction of certain conditions precedent, the Second Tranche shall be provided by L1 Capital in the principal amount of $5,000,000
(which had been $2,000,000 prior to the L1 Amendment, and subject to potential reduction as described below). Such principal amount,
if funded, will be added to the principal amount of the Note, and L1 Capital will be entitled to the Second Warrant to purchase up to
383,620 ordinary shares (originally 153,450 prior to the L1 Amendment), if the full amount of the Second Tranche is funded,
at an exercise price of $6.00 per share, subject to adjustment as described below.
The
amount of the Second Tranche, and the corresponding number of ordinary shares underlying the Second Warrant, is subject to reduction
if the principal amount of the Note (after funding the Second Tranche) would be 20% or more of the then current market
capitalization of our company on the trading day following the date of effectiveness of the registration statement of which this
prospectus forms a part (this percentage was 25% prior to the L1 Amendment).
EF
Hutton, division of Benchmark Investment, LLC, acted as exclusive placement agent for the offering and received customary fees.
The
L1 Amendment
On
March 4, 2022, we entered into the SPA Amendment and the Replacement Note with L1 Capital to memorialize the following amendments to
the terms of the financing transaction:
1.
The amount of the Second Tranche was increased from $2,000,000 to $5,000,000 (less a 6% original issuance discount as provided for
in the original Note) (the “New Second Tranche Amount”).
2.
Because of the increase in the Second Tranche Amount, at the closing of the Second Tranche, L1 Capital will be entitled to receive a
Warrant (the “Second Warrant”) to purchase up to 383,620 Ordinary Shares (rather than 153,450 Ordinary Shares per the
initial terms, and assuming the full New Second Tranche Amount is funded) at an exercise price of $6.00 per share, subject to
adjustment as described below.
3.
Without the prior approval of L1 Capital, we will be restricted in issuing new ordinary shares or ordinary share equivalents
(subject to certain exceptions) during the period from March 4, 2022 through the date that is seven (7) trading days after the
registration statement of which this prospectus forms a part is declared effective; provided that this restriction will not apply if
then trading price of our ordinary shares is over $9.00 with average five (5) day trading volume of 500,000 shares.
Terms
of the Purchase Agreement
The
terms of the Purchase Agreement contains customary representations and warranties, indemnification, and other covenants of our company
and L1 Capital, as well as the following material terms (which reflect the L1 Amendment):
Registration
Rights. By March 9, 2022, we were required to prepare and file a Registration Statement (the “L1 Registration
Statement”) with the SEC covering the resale of all of the ordinary shares underlying the Note (assuming conversion at a floor
price of $1.20 per share) and the Warrants. The Registration Statement of which this prospectus forms apart is intended to satisfy our
filing obligations with respect to the L1 Registration Statement. We shall use our commercially reasonable efforts to have the L1 Registration
Statement declared effective as soon as practicable after filing thereof but in no event later than the date that is (i) 60 days following
the Initial Closing Date if the L1 Registration Statement is not subject to review by the SEC or (ii) 90 days following the Initial Closing
Date if the L1 Registration Statement is subject to review by the SEC. We have also granted L1 Capital certain “piggyback”
registration rights with respect to the ordinary shares underlying the Note and the Warrants. We will pay all fees and expenses incident
to such registrations, excluding discounts, commissions, fees of underwriters, selling brokers, dealer managers or similar securities
industry professionals with respect to the shares being sold.
Future
Financing Participation Right. Subject to certain exceptions, for a period ending on January 20, 2023, L1 Capital shall have
the right to participate in up to thirty percent (30%) of our future financings undertaken during that period.
Repayment
on Future Financings. If we issue any debt, including any subordinated debt or convertible debt (other than the Note), then L1 Capital
will have the option to cause us to immediately utilize 30% of the aggregate proceeds of such issuance to repay the Note. In addition,
if we issue any equity interests for cash as part of a financing transaction (other than in connection with an “at the market”
funding program), then we will have the option to cause us to direct 30% of such proceeds from such issuance to repay the Note.
Leak
Out. Subject to certain exceptions, and provided no Event of Default (as defined below) has occurred, we shall uses our best efforts
in any month not to offer, sell, agree to offer or sell, solicit offers to purchase, grant any call option or purchase any put option
with respect to, or pledge, encumber, assign, borrow or otherwise dispose of ordinary shares underlying the Note and the Warrants at
less than $6.00 per share in an aggregate amount not to exceed the greater of (i) $750,000, or (ii) 40% of the average trading volume
of the ordinary shares in the preceding month.
Prohibited
Transactions. We shall not (without the prior written consent of L1 Capital): (i) enter into any financing transactions that qualify
as “variable rate transactions” until thirty (30) days after such time as the Note has been repaid in full and/or has been
fully converted into ordinary shares or (ii) utilize any “at the market” offering program in respect of our ordinary shares
in the thirty (30) day period following any date that we have made payments under the Note in the form of ordinary shares.
No
Repricing. We shall not, without the prior written consent of Capital (i) authorize the amendment of any outstanding note, option,
warrant, or other derivative security convertible, exercisable or exchangeable for ordinary shares to reduce the conversion, exercise
or exchange price of any such security or (ii) grant a replacement note, option, warrant or other derivative security convertible, exercisable
or exchangeable for ordinary shares for the purpose of reducing the conversion, exercise or exchange price of any such security being
replaced.
Available
Information. As long as L1 Capital owns the Note, the Warrants or the Ordinary Shares underlying the Note and the Warrants, we (i)
will timely file all reports required to be filed by us pursuant to the Securities Exchange Act of 1934, as amended (the “Exchange
Act”) and (ii) if we are not required to file reports pursuant to the Exchange Act, we will prepare and furnish to such Investor
and make publicly available in accordance with Rule 144(c) promulgated under the Securities Act of 1933, as amended (the “Securities
Act”) such information as is required for such Investor to sell our securities under Rule 144.
Share
Reserve. We shall at all times keep authorized and reserved and available for issuance, free of preemptive rights, a number of ordinary
shares equal to two times the ordinary shares underlying the Note (based on an assumed conversion at the Floor Price, as defined below)
and the Warrants (the “Required Share Reserve”).
Termination.
The Purchase Agreement shall be subject to termination: (i) if trading in securities generally in the United States has been suspended
or limited for a consecutive period of greater than three (3) business days, or (ii) a banking moratorium has been declared by the United
States or the New York State authorities and is continuing for a consecutive period of greater than three (3) business days or (iii)
a change of control of our company (as defined in the Purchase Agreement).
Terms
of the Note
Seniority;
Subsidiary Guarantee. The obligations of us under the Note shall rank senior to all other existing indebtedness and equity of our
company. The Note is unsecured, but our payment obligations under the Note have been guaranteed by WJ Energy Group Limited, our wholly-owned
subsidiary, pursuant to a subsidiary guarantee in favor of L1 Capital (the “Subsidiary Guarantee”).
Original
Issuance Discount; Second Tranche Closing. The Note carries a 6.0% original issue discount, resulting in proceeds before expenses
to us for the First Tranche of approximately $4,700,000. If the full amount of the Second Tranche is funded, after taking into consideration
the 6.0% original issue discount, the proceeds before expenses to us from the Second Tranche would be approximately $4,700,000.
Among other conditions precedent to the Second Tranche, L1 Capital shall not be obligated to fund the Second Tranche if this Registration
Statement is not declared effective by the SEC within 120 days from the Initial Closing Date. As described above, the amount of the Second
Tranche is subject to reduction (and could be no amount) based on the then market capitalization of us.
Maturity;
Voluntary Conversion. The Note has an 18-month maturity and a fixed conversion price of $6.00 per ordinary share for voluntary conversions
of the Note, subject to “full ratchet” price based anti-dilution adjustments for future issuances of ordinary shares by us
(subject to certain exceptions) and customary share-based adjustments for stock splits and the like.
Monthly
Installment Payments. Beginning May 21, 2022, we are required to commence monthly installment payments of the Note through
maturity (or 14 payments) (“Monthly Payments”), which Monthly Payments may be made, at our election, in cash or ordinary
shares (or a combination of cash and ordinary shares), with such ordinary shares being issued at a valuation equal to the lesser of:
(i) $6.00 per share or (ii) 90% of the average of the two lowest closing bid prices of the ordinary shares for the ten (10) consecutive
trading days ending on the trading day immediately prior to the payment date (the “Market Price”), with a floor price of
$1.20 per share (which floor price may be waived by us, but not L1 Capital, under certain circumstances) (the “Floor Price”).
We shall not be permitted to make Monthly Payments under the Note in ordinary shares if certain equity conditions are not met, including
(i) an Event of Default (as defined below) has not occurred; (ii) the ordinary shares shall be registered pursuant to an effective L1
Registration Statement; (iii) no change of control of we have been announced; (iv) the ordinary shares are then listed on a national
stock exchange and (iv) the average daily trading volume for the ordinary shares on the principal trading market for the ordinary shares
for the 10 consecutive trading days prior to the applicable payment date exceeds 50% of the amount of ordinary shares that is proposed
to be paid by us in respect of such Monthly Payment. If the market price of the ordinary shares decreases in the 10 days following a
Monthly Payment made in ordinary shares, L1 Capital will be entitled to receive an amount in additional ordinary shares or in cash based
on a formula to account for the decrease in the share price. L1 Capital has the right, at its sole option, to defer or accelerate up
to four (4) Monthly Payments or any portion of a Monthly Payment.
Prepayment;
Change of Control Payment. Subject to certain conditions precedent, the Note may be prepaid by us at any time with a prepayment premium
equal to ten percent (10%) of the principal amount of the Note. In addition, if we enter into a definitive agreement with respect to
a change of control of our company, L1 Capital shall have the right to require our company to prepay the Note with a five
percent (5%) payment premium.
Events
of Default. The Note is subject to customary events of default (each, an “Event of Default”), including, without limitation:
(i) payment defaults; (ii) default in the performance by us of -our obligations, or breach by us of our representations and warranties,
under the Purchase Agreement, the Note or the Warrant; (iii) failure by us to maintain the Required Share Reserve; (iv) default by us
under other indebtedness in excess of $500,000; (v) bankruptcy, liquidation and similar matters of or concerning our or our subsidiaries;
(vi) delisting of the ordinary shares from a national exchange; (vii) consummation by our company of a “going private” transaction;
(viii) the conviction of certain key Company executives of a felony or the ability of such key executives to devote the full time to
us for 120 days; and (ix) the occurrence of a material adverse effect in respect of our company which would reasonably be considered
to substantially impair the ability of our company to satisfy its obligations in the Purchase Agreement, the Note or the Warrants.
Upon
an Event of Default, in additional to other customary remedies, L1 Capital shall have the right to convert the Note into ordinary shares
at 80% of the then Market Price.
Covenants.
The Note contains certain affirmative and negative covenants, including that we shall maintain a cash balance of at least $1.0 million.
The
table below sets forth, as of the date of this prospectus, the following information regarding the Selling Shareholder:
|
● |
the
number of ordinary shares owned by the Selling Shareholder prior to this offering, without regard to any beneficial ownership limitations
contained in the Warrants; |
|
● |
the
number of ordinary shares to be offered by the Selling Shareholder in this offering; |
|
● |
the
number of ordinary shares to be owned by the Selling Shareholder assuming the sale of all of the shares of ordinary shares
covered by this prospectus; and |
|
● |
the
percentage of our issued and outstanding ordinary shares to be owned by the Selling Shareholder assuming the sale of all of the ordinary
shares covered by this prospectus based on the number of ordinary shares issued and outstanding as of the date of this prospectus. |
Except
as described above, the number of ordinary shares beneficially owned by the Selling Shareholders has been determined in accordance with
Rule 13d-3 under the Exchange Act and includes, for such purpose, ordinary shares that the Selling Shareholders have the right to acquire
within 60 days of the date of this prospectus.
The
ordinary shares that may be offered by the Selling Shareholder hereunder will be acquired by such Selling Shareholder upon the conversion
by such Selling Shareholder of the Note (or repayments of the Note by us in the form of ordinary shares) or upon exercise of
the Warrants that are held by such Selling Shareholder and that were previously issued in private transactions by our company. Descriptions
of the private transactions in which we issued the Note and the Warrants are set forth above. Except as otherwise indicated, we believe
the Selling Shareholder has sole voting and investment power with respect to such ordinary shares.
All
information with respect to the ownership of the Selling Stockholder in the ordinary shares has been furnished by or on behalf of the
Selling Shareholder. We believe, based on information supplied by the Selling Shareholder, that except as may otherwise be indicated
in the footnotes to the table below, each Selling Shareholder has sole voting and dispositive power with respect to the ordinary shares
reported as beneficially owned by it. Because the Selling Shareholder may sell some or all of the ordinary shares beneficially owned
by them and covered by this prospectus, and because there are currently no agreements, arrangements or understandings with respect to
the sale of any of the ordinary shares, no estimate can be given as to the number of ordinary shares available for resale hereby that
will be held by the Selling Shareholder upon termination of this offering. In addition, the Selling Shareholder may have sold, transferred
or otherwise disposed of, or may sell, transfer or otherwise dispose of, at any time and from time to time, the ordinary shares it beneficially
owns in transactions exempt from the registration requirements of the Securities Act after the date on which it provided the information
set forth in the table below. We have, therefore, assumed for the purposes of the following table, that the Selling Shareholder will
sell all of the ordinary shares owned beneficially by it that are covered by this prospectus, but will not sell any other ordinary shares,
if any, that it presently owns. The Selling Shareholder has not held any position or office, or has otherwise had a material relationship,
with us or any of our subsidiaries within the past three years other than as a result of the ownership of our ordinary shares or other
securities.
Selling Shareholder | |
Beneficial Ownership Before the Offering | | |
Number of Shares Being
Offered | | |
Beneficial Ownership After the
Offering | | |
Percentage of Ownership After the
Offering | |
| |
| | | |
| | | |
| | | |
| | |
L1 Capital Global Opportunities Master Fund (1) | |
| 9,100,574 | (2) | |
| 9,100,574 | | |
| 0 | | |
| 0 | % |
(1) |
David
Feldman is the control person of L1 Capital Global Opportunities Master Fund, and has sole voting control and investment discretion
over the securities held by L1 Capital Global Opportunities Master Fund. Mr. Feldman disclaims beneficial ownership over the securities
listed except to the extent of his pecuniary interest therein. The principal business address of the L1 Capital Global Opportunities
Master Fund is 161A Shedden Road, 1 Artillery Court, PO Box 10085, Grand Cayman KY1-1001, Cayman Islands. |
(2) |
The
number of shares beneficially owned is based on 767,240 ordinary shares issuable upon exercise of the Warrants plus 8,333,334
ordinary shares issuable upon the conversion of the principal of the Note, assuming the conversion price per share
of $1.20 (the floor conversion price of the Note), and not taking into account any beneficial share ownership limitations provisions
provided for in the Note and the Warrants. The actual number of shares issuable upon the conversion of the principal and periodic
payments on the Note may be lower depending on the price of our ordinary shares on the date of conversion or payment. |
Other
than in connection with the transactions described above, we have not had any material relationships with the Selling Shareholder in
the last three (3) years.
PLAN
OF DISTRIBUTION
The
Selling Shareholder and any of their pledgees, donees, assignees and successors-in-interest may, from time to time, sell any or all of
our ordinary shares being offered under this prospectus on any share exchange, market or trading facility on which our ordinary shares
are traded or in private transactions. These sales may be at fixed or negotiated prices. The Selling Shareholder may use any one or more
of the following methods when disposing of our ordinary shares covered by this prospectus:
|
● |
ordinary
brokerage transactions and transactions in which the broker-dealer solicits purchasers; |
|
● |
block
trades in which the broker-dealer will attempt to sell the shares as agent but may position and resell a portion of the block as
principal to facilitate the transaction; |
|
● |
purchases
by a broker-dealer as principal and resales by the broker-dealer for its account; |
|
● |
an
exchange distribution in accordance with the rules of the applicable exchange; |
|
● |
privately
negotiated transactions; |
|
● |
to
cover short sales made after the date that the registration statement of which this prospectus is a part is declared effective by
the SEC; |
|
● |
broker-dealers
may agree with the Selling Shareholders to sell a specified number of such shares at a stipulated price per share; |
|
● |
a
combination of any of these methods of sale; and |
|
● |
any
other method permitted pursuant to applicable law. |
Such
ordinary shares may also be sold under Rule 144
under the Securities Act, or any other exemption from registration under the Securities Act, if available for a Selling Shareholder,
rather than under this prospectus. The Selling Shareholder has the sole and absolute discretion not to accept any purchase offer or make
any sale of shares if it deems the purchase price to be unsatisfactory at any particular time.
The
Selling Shareholder may pledge its ordinary shares to their brokers under the margin provisions of customer agreements. If the Selling
Shareholder defaults on a margin loan, the broker may, from time to time, offer and sell the pledged shares.
Broker-dealers
engaged by the Selling Shareholder may arrange for other broker-dealers to participate in sales. Broker-dealers may receive commissions
or discounts from a Selling Shareholder (or, if any broker-dealer acts as agent for the purchaser of shares, from the purchaser) in amounts
to be negotiated, which commissions as to a particular broker or dealer may be in excess of customary commissions to the extent permitted
by applicable law.
If
sales of ordinary shares offered under this prospectus are made to broker-dealers as principals, we would be required to file
a post-effective amendment to the registration statement of which this prospectus is a part. In the post-effective amendment, we would
be required to disclose the names of any participating broker-dealers and the compensation arrangements relating to such sales.
The
Selling Shareholder and any broker-dealers or agents that are involved in selling the shares offered under this prospectus may be deemed
to be “underwriters” within the meaning of the Securities Act in connection with these sales. Commissions received by these
broker-dealers or agents and any profit on the resale of the shares purchased by them may be deemed to be underwriting commissions or
discounts under the Securities Act. Any broker-dealers or agents that are deemed to be underwriters may not sell common shares offered
under this prospectus unless and until we set forth the names of the underwriters and the material details of their underwriting arrangements
in a supplement to this prospectus or, if required, in a replacement prospectus included in a post-effective amendment to the registration
statement of which this prospectus is a part.
The
Selling Shareholder and any other persons participating in the sale or distribution of the shares offered under this prospectus will
be subject to applicable provisions of the Exchange Act, and the rules and regulations under that act, including Regulation M. These
provisions may restrict activities of, and limit the timing of purchases and sales of any of the shares by, the Selling Shareholder or
any other person. Furthermore, under Regulation M, persons engaged in a distribution of securities are prohibited from simultaneously
engaging in market making and other activities with respect to those securities for a specified period of time prior to the commencement
of such distributions, subject to specified exceptions or exemptions. All of these limitations may affect the marketability of the shares.
If
any of the shares offered for sale pursuant to this prospectus are transferred other than pursuant to a sale under this prospectus, then
subsequent holders could not use this prospectus until a post-effective amendment or prospectus supplement is filed, naming such holders.
We offer no assurance as to whether the Selling Shareholder will sell all or any portion of the shares offered under this prospectus.
We
have agreed with the Selling Shareholder to use commercially reasonable efforts to keep the registration statement of which
this prospectus is a part effective at all times until the Selling Shareholder no longer owns any Warrants or ordinary
shares issuable upon the exercise thereof. The ordinary shares will be sold only through registered or licensed brokers
or dealers if required under applicable state securities laws. In addition, in certain states, the ordinary shares covered hereby
may not be sold unless they have been registered or qualified for sale in the applicable state or an exemption from the registration
or qualification requirement is available and is complied with.
TAXATION
The
following discussion of material Cayman Islands, Indonesia and United States federal income tax consequences of an investment in our
ordinary shares is based upon laws and relevant interpretations thereof in effect as of the date of this prospectus, all of which are
subject to change. This discussion does not deal with all possible tax consequences relating to an investment in our ordinary shares,
such as the tax consequences under state, local and other tax laws. To the extent that the discussion relates to matters of Cayman Islands
tax law, it represents the opinion of Ogier, our Cayman Islands counsel.
Cayman
Islands Taxation
The
Cayman Islands currently levies no taxes on individuals or corporations based upon profits, income, gains or appreciation and there is
no taxation in the nature of inheritance tax or estate duty. There are no other taxes likely to be material to us levied by the Government
of the Cayman Islands except for stamp duties which may be applicable on instruments executed in, or after execution brought within,
the jurisdiction of the Cayman Islands. No stamp duty is payable in the Cayman Islands on the issue of shares by, or any transfers of
shares of, Cayman Islands companies (except those which hold interests in land in the Cayman Islands). The Cayman Islands is not party
to any double tax treaties which are applicable to any payments made to or by our company. There are no exchange control regulations
or currency restrictions in the Cayman Islands.
Payments
of dividends and capital in respect of our shares will not be subject to taxation in the Cayman Islands and no withholding will be required
on the payment of dividends or capital to any holder of our shares, nor will gains derived from the disposal of our shares be subject
to Cayman Islands income or corporation tax.
Pursuant
to Section 6 of the Tax Concessions Law (Revised) of the Cayman Islands, we have obtained an undertaking from the Financial Secretary
of the Cayman Islands:
|
(1) |
that
no law which is enacted in the Cayman Islands imposing any tax to be levied on profits or income or gains or appreciation shall apply
to us or our operations; and |
|
(2) |
in
addition, that no tax to be levied on profits, income, gains or appreciations or which is in the nature of estate duty or inheritance
tax shall be payable: |
|
(i) |
on
or in respect of the shares, debentures or other obligations of our company; or |
|
(ii) |
by
way of the withholding in whole or in part of any “relevant payment” as defined in section 6(3) of the Tax Concessions
Law (Revised). |
The
undertaking is for a period of twenty years from November 2, 2018.
Material
U.S. Federal Income Tax Considerations
Subject
to the qualifications and limitations described below, the following are the material U.S. federal income tax consequences of the purchase,
ownership and disposition of ordinary shares to a “U.S. Holder.” Non-U.S. Holders are urged to consult their own tax advisors
regarding the U.S. federal income tax consequences of the purchase, ownership and disposition of ordinary shares to them.
For
purposes of this discussion, a “U.S. Holder” means a beneficial owner of ordinary shares that is, for U.S. federal income
tax purposes:
|
● |
an
individual who is a citizen or resident of the United States; |
|
● |
a
corporation (or other entity taxed as a corporation for U.S. federal income tax purposes) created or organized in or under the laws
of the United States or any of its political subdivisions; |
|
● |
an
estate, whose income is includible in gross income for U.S. federal income tax purposes regardless of its source; or |
|
● |
a
trust if (i) a court within the United States is able to exercise primary supervision over the administration of the trust and one
or more U.S. persons have the authority to control all substantial decisions of the trust, or (ii) it has a valid election to be
treated as a U.S. person. |
A
“non-U.S. Holder” is any individual, corporation, trust or estate that is a beneficial owner of ordinary shares and is not
a U.S. Holder.
This
discussion is based on current provisions of the Internal Revenue Code of 1986, as amended, or the Code, applicable U.S. Treasury Regulations
promulgated thereunder, and administrative and judicial decisions as at the date hereof, all of which are subject to change, possibly
on a retroactive basis, and any change could affect the continuing accuracy of this discussion.
This
summary does not purport to be a comprehensive description of all of the tax considerations that may be relevant to each person’s
decision to purchase ordinary shares. This discussion does not address all aspects of U.S. federal income taxation that may be relevant
to any particular U.S. Holder based on such holder’s particular circumstances, including Medicare tax imposed on certain investment
income. In particular, this discussion considers only U.S. Holders that will own ordinary shares as capital assets within the meaning
of section 1221 of the Code and does not address the potential application of U.S. federal alternative minimum tax or the U.S. federal
income tax consequences to U.S. Holders that are subject to special treatment, including:
|
● |
broker
dealers or insurance companies; |
|
● |
U.S.
Holders who have elected mark-to-market accounting; |
|
● |
tax-exempt
organizations or pension funds; |
|
● |
regulated
investment companies, real estate investment trusts, insurance companies, financial institutions or “financial services entities”; |
|
● |
U.S.
Holders who hold ordinary shares as part of a “straddle,” “hedge,” “constructive sale” or “conversion
transaction” or other integrated investment; |
|
● |
U.S.
Holders who own or owned, directly, indirectly or by attribution, at least 10% of the voting power of our ordinary shares; |
|
● |
U.S.
Holders whose functional currency is not the U.S. Dollar; |
|
● |
U.S.
Holders who received ordinary shares as compensation; |
|
● |
U.S.
Holders who are otherwise subject to UK taxation; |
|
● |
persons
holding ordinary shares in connection with a trade or business outside of the United States; and |
|
● |
certain
expatriates or former long-term residents of the United States. |
This
discussion does not consider the tax treatment of holders that are entities treated as partnerships for U.S. federal income tax purposes
or other pass-through entities or persons who hold ordinary shares through a partnership or other pass-through entity. In addition, this
discussion does not address any aspect of state, local or non-U.S. tax laws, or the possible application of U.S. federal gift or estate
tax.
BECAUSE
OF THE COMPLEXITY OF THE TAX LAWS AND BECAUSE THE TAX CONSEQUENCES TO ANY PARTICULAR HOLDER OF ORDINARY SHARES MAY BE AFFECTED BY MATTERS
NOT DISCUSSED HEREIN, EACH HOLDER OF ORDINARY SHARES IS URGED TO CONSULT WITH ITS TAX ADVISOR WITH RESPECT TO THE SPECIFIC TAX CONSEQUENCES
OF THE ACQUISITION AND THE OWNERSHIP AND DISPOSITION OF ORDINARY SHARES, INCLUDING THE APPLICABILITY AND EFFECT OF STATE, LOCAL AND NON-U.S.
TAX LAWS, AS WELL AS U.S. FEDERAL TAX LAWS AND APPLICABLE TAX TREATIES.
Taxation
of Dividends Paid on Ordinary Shares
Subject
to the passive foreign investment company rules discussed below, the gross amount of distributions made by us with respect to our ordinary
shares generally will be includable in the gross income of U.S. Holders as foreign source passive income. Because we do not determine
our earnings and profits for U.S. federal income tax purposes, a U.S. Holder will be required to treat any distribution paid on ordinary
shares, including the amount of non-U.S. taxes, if any, withheld from the amount paid, as a dividend on the date the distribution is
received. Such distribution generally will not be eligible for the dividends-received deduction generally allowed to U.S. corporations
in respect of dividends received from other U.S. corporations.
Cash
distributions paid in a non-U.S. currency will be included in the income of U.S. Holders at a U.S. Dollar amount equal to the spot rate
of exchange in effect on the date the dividends are includible in the income of the U.S. Holders, regardless of whether the payment is
in fact converted to U.S. Dollars, and U.S. Holders will have a tax basis in such non-U.S. currency for U.S. federal income tax purposes
equal to such U.S. Dollar value. If a U.S. Holder converts a distribution paid in non-U.S. currency into U.S. Dollars on the day the
dividend is includible in the income of the U.S. Holder, the U.S. Holder generally should not be required to recognize gain or loss arising
from exchange rate fluctuations. If a U.S. Holder subsequently converts the non-U.S. currency, any subsequent gain or loss in respect
of such non-U.S. currency arising from exchange rate fluctuations will be U.S.-source ordinary income or loss.
Dividends
we pay with respect to our ordinary shares to non-corporate U.S. Holders may be “qualified dividend income,” which is currently
taxable at a reduced rate; provided that (i) our ordinary shares are readily tradable on an established securities market in the
United States, (ii) we are not a passive foreign investment company (as discussed below) with respect to the U.S. Holder for either our
taxable year in which the dividend was paid or the preceding taxable year, (iii) the U.S. Holder has held our ordinary shares for at
least 61 days of the 121-day period beginning on the date which is 60 days before the ex-dividend date, and (v) the U.S. Holder is not
under an obligation to make related payments on substantially similar or related property. We believe our ordinary shares, which are
expected to be listed on the NYSE American, will be considered to be readily tradable on an established securities market in the United
States, although there can be no assurance that this will continue to be the case in the future. Any days during which a U.S. Holder
has diminished its risk of loss on our ordinary shares are not counted towards meeting the 61-day holding period. U.S. Holders should
consult their own tax advisors on their eligibility for reduced rates of taxation with respect to any dividends paid by us.
Distributions
paid on ordinary shares generally will be foreign-source passive category income for U.S. foreign tax credit purposes and will not qualify
for the dividends received deduction generally available to corporations. Subject to certain conditions and limitations, non-U.S. taxes,
if any, withheld from a distribution may be eligible for credit against a U.S. Holder’s U.S. federal income tax liability. In addition,
if 50 percent or more of the voting power or value of our shares is owned, or is treated as owned, by U.S. persons (whether or not we
are a “controlled foreign corporation” for U.S. federal income tax purposes), the portion of our dividends attributable to
income which we derive from sources within the United States (whether or not in connection with a trade or business) would generally
be U.S.-source income. U.S. Holders would not be able directly to utilize foreign tax credits arising from non U.S. taxes considered
to be imposed upon U.S.-source income.
Taxation
of the Sale or Other Disposition of Ordinary Shares
Subject
to the passive foreign investment company rules discussed below, a U.S. Holder generally will recognize a capital gain or loss on the
taxable sale or other disposition of our ordinary shares in an amount equal to the difference between the U.S. Dollar amount realized
on such sale or other disposition (determined in the case of consideration in currencies other than the U.S. Dollar by reference to the
spot exchange rate in effect on the date of the sale or other disposition or, if the ordinary shares are treated as traded on an established
securities market and the U.S. Holder is a cash basis taxpayer or an electing accrual basis taxpayer, the spot exchange rate in effect
on the settlement date) and the U.S. Holder’s adjusted tax basis in such ordinary shares determined in U.S. Dollars. The initial
tax basis of ordinary shares to a U.S. Holder will be the U.S. Holder’s U.S. Dollar cost for ordinary shares (determined by reference
to the spot exchange rate in effect on the date of the purchase or, if the ordinary shares are treated as traded on an established securities
market and the U.S. Holder is a cash basis taxpayer or an electing accrual basis taxpayer, the spot exchange rate in effect on the settlement
date).
Capital
gain from the sale, exchange or other disposition of ordinary shares held more than one year generally will be treated as long-term capital
gain and is eligible for a reduced rate of taxation for non-corporate holders. Gain or loss recognized by a U.S. Holder on a sale or
other disposition of ordinary shares generally will be treated as U.S.-source income or loss for U.S. foreign tax credit purposes. The
deductibility of a capital loss recognized on the sale or exchange of ordinary shares is subject to limitations. A U.S. Holder that receives
currencies other than U.S. Dollars upon disposition of the ordinary shares and converts such currencies into U.S. Dollars subsequent
to receipt will have foreign exchange gain or loss based on any appreciation or depreciation in the value of such currencies against
the U.S. Dollar, which generally will be U.S.-source ordinary income or loss.
Passive
Foreign Investment Company
Based
on our current composition of assets and market capitalization (which will fluctuate from time to time), we believe that we are not and
will not become a passive foreign investment company, or a PFIC, for U.S. federal income tax purposes. However, the determination of
whether we are a PFIC is made annually, after the close of the relevant taxable year. Therefore, it is possible that we could be classified
as a PFIC for the current taxable year or in future years due to changes in the composition of our assets or income, as well as changes
to our market capitalization. The market value of our assets may be determined in large part by reference to the market price of our
ordinary shares, which may fluctuate.
In
general, a non-U.S. corporation will be classified as a PFIC for any taxable year if at least (i) 75% of its gross income is classified
as “passive income” or (ii) 50% of its assets (determined on the basis of a quarterly average) produce or are held for the
production of passive income. For these purposes, cash is considered a passive asset. In making this determination, the non-U.S. corporation
is treated as earning its proportionate share of any income and owning its proportionate share of any assets of any corporation in which
it holds 25% or more (by value) of the stock.
Under
the PFIC rules, if we were considered a PFIC at any time that a U.S. Holder holds our shares, we would continue to be treated as a PFIC
with respect to such holder’s investment unless (i) we cease to be a PFIC and (ii) the U.S. Holder has made a “deemed sale”
election under the PFIC rules.
If
we are considered a PFIC at any time that a U.S. Holder holds our shares, any gain recognized by the U.S. Holder on a sale or other disposition
of the shares, as well as the amount of an “excess distribution” (defined below) received by such holder, would be allocated
ratably over the U.S. Holder’s holding period for the shares. The amounts allocated to the taxable year of the sale or other disposition
and to any year before we became a PFIC would be taxed as ordinary income. The amount allocated to each other taxable year would be subject
to tax at the highest rate in effect for individuals or corporations, as appropriate, for that taxable year, and an interest charge would
be imposed. For purposes of these rules, an excess distribution is the amount by which any distribution received by a U.S. Holder on
its shares exceeds 125% of the average of the annual distributions on the shares received during the preceding three years or the U.S.
Holder’s holding period, whichever is shorter. Certain elections may be available that would result in alternative treatments (such
as mark-to-market treatment) of the shares.
If
we are treated as a PFIC with respect to a U.S. Holder for any taxable year, the U.S. Holder will be deemed to own shares in any of our
subsidiaries that are also PFICs. However, an election for mark-to-market treatment would likely not be available with respect to any
such subsidiaries. If we are considered a PFIC, a U.S. Holder will also be subject to information reporting requirements on an annual
basis. U.S. Holders should consult their own tax advisors about the potential application of the PFIC rules to an investment in our shares.
If
we were classified as a PFIC, a U.S. Holder may be able to make a mark-to-market election with respect to our ordinary shares (but not
with respect to the shares of any lower-tier PFICs) if the ordinary shares are “regularly traded” on a “qualified exchange”.
In general, our ordinary shares issued will be treated as “regularly traded” in any calendar year in which more than a de
minimis quantity of ordinary shares are traded on a qualified exchange on at least 15 days during each calendar quarter. We believe the
NYSE American is a qualified exchange. However, we can make no assurance that the ordinary shares will be listed on a “qualified
exchange” or that there will be sufficient trading activity for the ordinary shares to be treated as “regularly traded”.
Accordingly, U.S. Holders should consult their own tax advisers as to whether their ordinary shares would qualify for the mark-to-market
election.
If
a U.S. Holder makes the mark-to-market election, for each year in which our company is a PFIC, the holder will generally include as ordinary
income the excess, if any, of the fair market value of the ordinary shares at the end of the taxable year over their adjusted tax basis,
and will be permitted an ordinary loss in respect of the excess, if any, of the adjusted tax basis of the ordinary shares over their
fair market value at the end of the taxable year (but only to the extent of the net amount of previously included income as a result
of the mark-to-market election). If a U.S. Holder makes the election, the holder’s tax basis in our ordinary shares will be adjusted
to reflect any such income or loss amounts. Any gain recognized on the sale or other disposition of our ordinary shares will be treated
as ordinary income, and any loss will be treated as an ordinary loss to the extent of any prior mark-to-market gains.
If
a U.S. Holder makes the mark-to-market election, it will be effective for the taxable year for which the election is made and all subsequent
taxable years unless the ordinary shares are no longer regularly traded on a qualified exchange or the IRS consents to the revocation
of the election.
If
we were classified as a PFIC, U.S. Holders would not be eligible to make an election to treat us as a “qualified electing fund,”
or a QEF election, because we do not anticipate providing U.S. Holders with the information required to permit a QEF election to be made.
U.S.
Information Reporting and Backup Withholding
A
U.S. Holder is generally subject to information reporting requirements with respect to dividends paid in the United States on ordinary
shares and proceeds paid from the sale, exchange, redemption or other disposition of ordinary shares. A U.S. Holder is subject to backup
withholding (currently at 24%) on dividends paid in the United States on ordinary shares and proceeds paid from the sale, exchange, redemption
or other disposition of our ordinary shares unless the U.S. Holder is a corporation, provides an IRS Form W-9 or otherwise establishes
a basis for exemption.
Backup
withholding is not an additional tax. Amounts withheld under the backup withholding rules may be credited against a U.S. Holder’s
U.S. federal income tax liability, and a U.S. Holder may obtain a refund from the IRS of any excess amount withheld under the backup
withholding rules, provided that certain information is timely furnished to the IRS. Holders are urged to consult their own tax advisors
regarding the application of backup withholding and the availability of and procedures for obtaining an exemption from backup withholding
in their particular circumstances.
Certain
Reporting Obligations
If
a U.S. Holder (together with persons considered to be related to the U.S. Holder) subscribes for ordinary shares for a total initial
public offering price in excess of $100,000 (or the equivalent in a foreign currency), such holder may be required to file IRS Form 926
for the holder’s taxable year in which the initial public offering price is paid. U.S. Holders should consult their own tax advisors
to determine whether they are subject to any Form 926 filing requirements.
Individuals
that own “specified foreign financial assets” may be required to file an information report with respect to such assets with
their tax returns. Subject to certain exceptions, “specified foreign financial assets” include any financial accounts maintained
by foreign financial institutions, as well as any of the following, but only if they are not held in accounts maintained by financial
institutions: (i) stocks and securities issued by non U.S. persons, (ii) financial instruments and contracts held for investment that
have non U.S. issuers or counterparties, and (iii) interests in foreign entities. The ordinary shares may be subject to these rules.
Persons required to file U.S. tax returns that are individuals are urged to consult their tax advisers regarding the application of this
legislation to their ownership of the ordinary shares.
LEGAL
MATTERS
The
validity of the ordinary shares offered by this prospectus are being passed upon for us by Ogier, Grand Cayman, Cayman Islands.
EXPERTS
The
consolidated financial statements as of December 31, 2020 and 2019 and for each of three years in the period ended December 31,
2020 included in this prospectus have been so included in reliance on the report of Marcum Bernstein & Pinchuk LLP, an independent
registered public accounting firm, given on the authority of said firm as experts in accounting and auditing. The office of Marcum Bernstein
& Pinchuk LLP is located at 7 Penn Plaza, Suite 830, New York, NY 10001.
WHERE
YOU CAN FIND ADDITIONAL INFORMATION
We
have filed with the SEC a registration statement on Form F-1 under the Securities Act with respect to the ordinary shares described herein.
This prospectus, which constitutes part of the registration statement, does not include all of the information contained in the registration
statement. You should refer to the registration statement and its exhibits for additional information. Whenever we make reference in
this prospectus to any of our contracts, agreements or other documents, the references are not necessarily complete and you should refer
to the exhibits attached to the registration statement for copies of the actual contract, agreement or other document. We anticipate
making these documents publicly available, free of charge, on our website at www.indo-energy.com as soon as reasonably practicable
after filing such documents with the SEC. The information on our website is not incorporated by reference into this prospectus and should
not be considered to be a part of this prospectus. We have included our website address as an inactive textual reference only.
You
can read the registration statement and our future filings with the SEC, over the Internet at the SEC’s web site at www.sec.gov.
You may also read and copy any document that we file with the SEC at its public reference room at 100 F Street, N.E., Washington, DC
20549.
GLOSSARY
OF TERMS
The
following is a glossary of oil and gas industry and other defined terms used in this prospectus:
“AMDAL” |
|
Environmental
impact assessment report |
|
|
|
“BP
Migas” |
|
Badan
Pelaksana Kegiatan Usaha Hulu Minyak dan Gas Bumi, the non-profit Government-owned operating board that succeeded to Pertamina’s
role as regulator of upstream oil and gas activities under the Oil and Gas Law |
|
|
|
“BPH
Migas” |
|
Badan
Pengatur Hilir Minyak dan Gas Bumi, the non-profit Government-owned operating board that succeeded to Pertamina’s role
as regulator of downstream oil and gas activities under the Oil and Gas Law |
|
|
|
“BPJS
Kesehatan” |
|
Indonesian
Health Social Security Administrative Body |
|
|
|
“BPJS
Ketenagakerjaan” |
|
Indonesian
the Manpower Social Security Administrative Body |
|
|
|
“Brexit” |
|
The
United Kingdom referendum voting in favor to leave the European Union and voted to leave |
|
|
|
“CNE” |
|
PT
Cogen Nusantara Energi, our indirect, wholly-owned subsidiary |
|
|
|
“Company” |
|
Indonesia
Energy Corporation Limited |
|
|
|
“Cost
Recovery” |
|
The
arrangement with the Government under which oil and gas contractors are allowed to recover their costs from the revenue. Different
contracts may impose different ceiling on the percentage of revenue recoverable |
|
|
|
“delineation
well” |
|
A
well that is drilled to exploit the hydrocarbon accumulation defined by an appraisal or delineation well |
|
|
|
“DGOG” |
|
The
Indonesian Director-General of Oil and Gas |
|
|
|
“DMO” |
|
Domestic
market obligation |
|
|
|
“exploration
well” |
|
A
well that is designed to test the validity of a seismic interpretation and to confirm the presence of hydrocarbons in an undrilled
formation |
|
|
|
“FTP” |
|
First
tranche petroleum |
|
|
|
“G&G
study” |
|
Geological
and geophysical study |
|
|
|
“GHG” |
|
Regulation
of greenhouse gas |
|
|
|
“Government” |
|
The
Government of the Republic of Indonesia |
|
|
|
“GWN”
|
|
PT
Green World Nusantara, our indirect, wholly-owned subsidiary |
|
|
|
“HNE” |
|
PT
Harvel Nusantara Energi, our indirect, wholly-owned subsidiary |
|
|
|
“HSSE” |
|
Health,
safety, security and environment activities |
“HWN” |
|
PT
Hutama Wiranusa Energi, our indirect, wholly-owned subsidiary |
|
|
|
“ICP” |
|
Indonesian
Crude Price for the “Talang Akar Pendopo (TAP) / Air Hitam” crude oil type |
|
|
|
“IDR”,
“Rp.” or “Rupiah” |
|
Indonesian
Rupiah |
|
|
|
“Indonesia” |
|
The
Republic of Indonesia |
|
|
|
“ITB” |
|
Bandung
Institute of Technology |
|
|
|
“JOB” |
|
Joint
Operating Body |
|
|
|
“Joint
Study” |
|
A
program with the Government whose objective is to determine oil and gas potential within a proposed working area by conducting geological
and geophysical work |
|
|
|
“KSO” |
|
Kerja
Sama Operasi/Joint Operation with Pertamina, a type of contract between Pertamina and exploration companies |
|
|
|
“lead” |
|
Preliminary
interpretation of geological and geophysical information that may or may not lead to prospects |
|
|
|
“LNG” |
|
Liquefied
natural gas |
|
|
|
“LPG” |
|
Liquefied
petroleum gas |
|
|
|
“medium-sized
blocks” |
|
We
use a three-tier classification for the size of blocks in Indonesia. The mean reserve size of middle third class (medium-sized field)
of 610 oil fields in Indonesia is 5.1 MMBO reserve with a range of 2 to 11 MMBO. With a proved and probable reserves of 5.69 MMBO,
Kruh Block is considered a medium-sized oil production block |
|
|
|
“MEMR” |
|
The
Ministry of Energy and Mineral Resources of Indonesia |
|
|
|
“MK” |
|
The
Constitutional Court of the Republic of Indonesia |
|
|
|
“Oil
and Gas Law” |
|
The
oil and gas law enacted on November 23, 2001 by the Government |
|
|
|
“OPEC” |
|
The
Organization of Petroleum Exporting Countries |
|
|
|
“P50” |
|
In
connection with oil and gas exploration, if probabilistic methods are used, there should be at least a 50% probability that the quantities
actually recovered will equal or exceed the best estimate |
|
|
|
“Pertamina” |
|
PT
Pertamina (Persero), the Indonesia state-owned oil and gas company |
|
|
|
“Profit
Sharing” |
|
The
revenue remaining after cost recovery is profit petroleum which is shared between the Government and the exploration company |
|
|
|
“Program
Legislasi Nasional” |
|
The
Indonesian National Legislation Program |
|
|
|
“PRMS” |
|
Petroleum
Resources Management System |
“proved
reserves” |
|
Those
quantities of petroleum which, by analysis of geological and engineering data, can be estimated with reasonable certainty to be commercially
recoverable, from a given date forward, from known reservoirs and under current economic conditions, operating methods, and Government
regulations |
|
|
|
“PSC” |
|
Production
Sharing Contract, a type of contract between Pertamina and exploration companies |
|
|
|
“SKK
Migas” |
|
Special
Task Force for Upstream Oil and Gas Business Activities, an institution established by the Government |
|
|
|
“TAC” |
|
Technical
Assistance Contract, a contract between Pertamina and an exploration company |
|
|
|
“U.S.
GAAP” |
|
Generally
accepted accounting principles in the United States |
|
|
|
“UPL” |
|
Environmental
monitoring effort plan |
|
|
|
“US$” |
|
United
States dollars |
|
|
|
“USGS” |
|
United
States Geological Survey |
|
|
|
“WJ
Energy” |
|
WJ
Energy Group Limited, our direct, wholly-owned subsidiary |
|
|
|
Units
of Measurement |
|
|
|
|
|
“BBOE” |
|
Billion
barrels of oil equivalent; natural gas is converted to BBOE using the ratio of one billion barrels of crude oil in the range of 5.19
— 6.54 thousand cubic feet of natural gas |
|
|
|
“Bbl.”
or “bbl” |
|
Barrels
of oil |
|
|
|
“BOPD” |
|
Barrels
of oil production |
|
|
|
“BSCF” |
|
Billion
standard cubic feet |
|
|
|
“MMBNGL” |
|
Million
barrels of natural gas liquids |
|
|
|
“MMBO” |
|
Million
barrels of oil |
|
|
|
“MMSCFD”
|
|
Million
standard cubic feet per day |
|
|
|
“TCF” |
|
Trillion
cubic feet |
INDONESIA
ENERGY CORPORATION LIMITED
INDEX
TO CONSOLIDATED FINANCIAL STATEMENTS
INDONESIA
ENERGY CORPORATION LIMITED
CONDENSED
CONSOLIDATED BALANCE SHEETS
The
accompanying notes are an integral part of these condensed consolidated financial statements
INDONESIA
ENERGY CORPORATION LIMITED
CONDENSED
CONSOLIDATED STATEMENTS OF OPERATIONS
The
accompanying notes are an integral part of these condensed consolidated financial statements
INDONESIA
ENERGY CORPORATION LIMITED
CONDENSED
CONSOLIDATED STATEMENTS OF CHANGES IN EQUITY
FOR
THE SIX MONTHS ENDED JUNE 30, 2021
FOR
THE SIX MONTHS ENDED JUNE 30, 2020
|
|
Preferred
Shares, $0.00267 Par Value |
|
|
Ordinary
Shares, $0.00267 Par Value |
|
|
Additional |
|
|
|
|
|
Accumulated
Other |
|
|
|
|
|
|
Number
of
Shares |
|
|
Amount |
|
|
Number
of Shares |
|
|
Amount |
|
|
Paid-in
Capital |
|
|
Accumulated
Deficit |
|
|
Comprehensive
Income |
|
|
Total
Equity |
|
Balance
as of January 1, 2020 |
|
|
- |
|
|
$ |
- |
|
|
|
7,363,637 |
|
|
$ |
19,636 |
|
|
$ |
36,910,568 |
|
|
$ |
(20,783,084 |
) |
|
$ |
46,805 |
|
- |
$ |
16,193,925 |
|
Net
loss |
|
|
- |
|
|
|
- |
|
|
|
- |
|
|
|
- |
|
|
|
- |
|
|
|
(3,563,138 |
) |
|
|
- |
|
- |
|
(3,563,138 |
) |
Realized
actuarial gain of post-employment benefits |
|
|
- |
|
|
|
- |
|
|
|
- |
|
|
|
- |
|
|
|
- |
|
|
|
- |
|
|
|
(46,805 |
) |
|
|
(46,805 |
) |
Issuance
of ordinary shares for service fee settlement |
|
|
- |
|
|
|
- |
|
|
|
44,318 |
|
|
|
118 |
|
|
|
155,437 |
|
|
|
- |
|
|
|
- |
|
|
|
155,555 |
|
Share-based
compensation |
|
|
- |
|
|
|
- |
|
|
|
- |
|
|
|
- |
|
|
|
1,549,707 |
|
|
|
- |
|
|
|
- |
|
|
|
1,549,707 |
|
Balance
as of June 30, 2020 (unaudited) |
|
|
- |
|
|
$ |
- |
|
|
|
7,407,955 |
|
|
$ |
19,754 |
|
|
$ |
38,615,712 |
|
|
$ |
(24,346,222 |
) |
|
$ |
- |
|
- |
$ |
14,289,244 |
|
The
accompanying notes are an integral part of these condensed consolidated financial statements
INDONESIA
ENERGY CORPORATION LIMITED
CONDENSED
CONSOLIDATED STATEMENTS OF CASH FLOWS
The
accompanying notes are an integral part of these condensed consolidated financial statements
INDONESIA
ENERGY CORPORATION LIMITED
NOTES
TO THE CONDENSED CONSOLIDATED FINANCIAL STATEMENTS
NOTE
1 – ORGANIZATION AND PRINCIPAL ACTIVITIES
Indonesia
Energy Corporation Limited (the “Company” or “IEC”), through its subsidiaries in Hong Kong and in Indonesia,
is an oil and gas exploration and production company focused on the Indonesian market. The Company currently holds two oil and gas assets
through subsidiaries in Indonesia: one producing block (the “Kruh Block”) and one exploration block (the “Citarum Block”).
The Company also identified a potential third exploration block known as the “Rangkas Area”.
Impact
of COVID-19 Pandemic
On
January 30, 2020, the World Health Organization declared the coronavirus outbreak a “Public Health Emergency of International Concern”
and on March 10, 2020, declared it to be a pandemic. Actions taken around the world to help mitigate the spread of the coronavirus include
restrictions on travel, and quarantines in certain areas, and forced closures for certain types of public places and businesses. The
coronavirus and actions taken to mitigate it have had and are expected to continue to have an adverse impact on the economies and financial
markets of many countries, including in Indonesia, where the Company operates. As the pandemic and new variants of COVID-19 have continued
into 2021, the Company has experienced delays which have, and may continue to materially and adversely impact, the Company’s business
operations.
As
of the date of issuance of these condensed consolidated financial statements, the impact of COVID-19 on the Company’s business,
financial condition, and results of operations includes, but are not limited to, the following:
|
● |
The
Company modified its business practices, including restricting employee travel, requiring employees to work remotely, and cancelling
physical participation in meetings, events, and conferences. |
|
|
|
|
● |
The
health-related mandate or guidelines issued by the Indonesian or local authorities has caused and may continue to cause the Company
to restrict the number of workers deployed to the drilling sites, therefore delaying the Company’s drilling and exploration
operations. In addition, the large scale of social restrictions in Jakarta and many Indonesian regions severely prolongs the time
required for the approval of any project proposal, permit application, procurement, and tender process. |
|
|
|
|
● |
Crude oil prices (including, of note to the Company,
the Indonesian Crude Price published by the Government of Indonesia (the “ICP”)) have been negatively impacted due to
low oil demand, increased production, and disputes between the Organization of the Petroleum Exporting Countries (“OPEC”)
and Russia on production cuts. While oil prices have risen and fluctuated during the periods presented, the Company’s revenue
and potential for profit have been adversely impacted and could in the future be adversely impacted due to decreases in prevailing
oil prices.
|
|
● |
During
2021, the Company commenced pre-drilling operations for its planned new wells at Kruh Block. The process of drilling for the
first 3 new wells was delayed to the government permitting process but also because of delays that resulted from COVID-19-related
restrictions. Commencement of new drilling was intended to begin during the first quarter of 2021 but began in the second quarter
and has continued during the year, with two of three anticipated new wells for 2021 having been drilled. |
|
|
|
|
● |
The
COVID-19 pandemic may disrupt the Company’s ability to raise additional capital to finance its operations in the future, which
could materially and adversely affect the Company’s business, financial condition, and prospects. |
Consequently,
due to the factors discussed above, and other unforeseen and unpredictable consequences of the COVID-19 pandemic, the Company’s
business and results of operations have been and may continue to be adversely impacted by COVID-19.
Given the speed and frequency of the continuously evolving developments with respect to the COVID-19 pandemic, the Company cannot
reasonably estimate the magnitude of the impact to its consolidated results of operations during 2021 and beyond.
NOTE
2 – SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES
Basis
of presentation and consolidation
The
unaudited condensed consolidated financial statements of the Company have been prepared in accordance with accounting principles
generally accepted in the United States of America (“US GAAP”) for interim financial statements. Accordingly, they may
not include all of the information and footnotes required by U.S. GAAP for complete financial statements. The interim financial
information should be read in conjunction with the consolidated financial statements and footnotes thereto included
in the Company’s financial statements for the year ended December 31, 2020 included in the Company’s Form 20-F filed
with the SEC on May 18, 2021.
In
the opinion of management, all adjustments (which include normal recurring adjustments) necessary to present a fair presentation of the
Company’s condensed consolidated balance sheet as of June 30, 2021, condensed consolidated statements of operations, changes in
equity and cash flows for the six months ended June 30, 2021 and 2020, as applicable, have been made. Operating results for the six months
ended June 30, 2021 are not necessarily indicative of the operating results that may be expected for the year ending December 31, 2021
or any future periods.
The
condensed consolidated financial statements include the financial statements of the Company and all its majority-owned subsidiaries from
the dates they were acquired or incorporated. All intercompany balances and transactions have been eliminated in consolidation.
Short-term
investment - available for sale security
The Company
classifies its bond as security available for sale based upon management’s intent and ability to hold the security. In
accordance with ASC 820, the Company measures its available-for-sale investment at fair value on a recurring basis. Increases and
decreases in the net unrealized gain or loss on the security available for sale are reflected as adjustments to the carrying value
of the security and as an adjustment, net of tax, to accumulated other comprehensive income. Interest earned on security available
for sale is included in interest income in the Company’s condensed consolidated statements of operations. On June 30, 2021, the
fair value of this investment is $307,500.
There were no
material unrealized gain or loss generated for the six months ended June 30, 2021.
Recently
issued accounting standards
The
Company is an “emerging growth company,” as defined in the Jumpstart Our Business Startups Act of 2012 (the “JOBS Act”).
Under the JOBS Act, emerging growth companies (“EGCs”) can delay adopting new or revised accounting standards issued subsequent
to the enactment of the JOBS Act until such time as those standards apply to private companies.
In
February 2016, the Financial Accounting Standards Board (“FASB”) issued ASU No. 2016-02, Leases (Topic 842). The guidance
supersedes existing guidance on accounting for leases, with the main difference being that operating leases are to be recorded in the
statement of financial position as right-of-use assets and lease liabilities, initially measured at the present value of the lease payments.
For operating leases with a term of 12 months or less, a lessee is permitted to make an accounting policy election not to recognize lease
assets and liabilities. In July 2018, ASU 2016-02 was updated with ASU 2018-11, Targeted Improvements to ASC Topic 842, which provides
entities with relief from the costs of implementing certain aspects of the new leasing standard. Specifically, under the amendments in
ASU 2018-11, (1) entities may elect not to recast the comparative periods presented when transitioning to ASC 842 and (2) lessors may
elect not to separate lease and non-lease components when certain conditions are met. In November 2019, ASU 2019-10, Codification Improvements
to ASC 842 modified the effective dates of all other entities. In June 2020, ASU 2020-05 defer the effective date for one year for entities
in the “all other” category. For all other entities, the amendments in ASU 2020-05 are effective for fiscal years beginning
after December 15, 2021, and interim periods within fiscal years beginning after December 15, 2022. Early application of the guidance
continues to be permitted. The Company will adopt ASU 2016-02 from January 1, 2022. The Company expects material changes to its consolidated
balance sheet to recognize right-of-use lease assets and related lease liabilities for operating leases. The Company is
in the process of evaluating the impact on its consolidated financial statements upon adoption.
In
June 2016, the FASB issued ASU No. 2016-13, “Financial Instruments – Credit Losses”, which will require the measurement
of all expected credit losses for financial assets held at the reporting date based on historical experience, current conditions, and
reasonable and supportable forecasts. Subsequently, the FASB issued ASU No. 2018-19, Codification Improvements to Topic 326, to clarify
that receivables arising from operating leases are within the scope of lease accounting standards. Further, the FASB issued ASU No. 2019-04,
ASU 2019-05, ASU 2019-10, ASU 2019-11 and ASU 2020-02 to provide additional guidance on the credit losses standard. For all other entities,
the amendments for ASU 2016-13 are effective for fiscal years beginning after December 15, 2022, including interim periods within those
fiscal years, with early adoption permitted. Adoption of the ASUs is on a modified retrospective basis. The Company will adopt ASU 2016-13
from January 1, 2023. The adoption is not expected to have a material impact on its condensed consolidated financial statements.
Other
accounting pronouncements that have been issued or proposed by the FASB or other standards-setting bodies that do not require adoption
until a future date are not expected to have a material impact on the Company’s condensed consolidated financial statements
upon adoption.
NOTE
3 – CASH, CASH EQUIVALENTS AND RESTRICTED CASH
The
following table provides a reconciliation of cash, cash equivalents, and restricted cash reported within the Condensed Consolidated Balance
Sheets that sum to the total of the same such amounts shown in the Condensed Consolidated Statements of Cash Flows:
SCHEDULE OF CASH, CASH EQUIVALENTS AND RESTRICTED CASH
|
|
June
30,
2021 |
|
|
December
31,
2020 |
|
|
|
|
(Unaudited) |
|
|
|
|
|
Cash
and cash equivalent |
|
$ |
4,067,987 |
|
|
$ |
6,903,499 |
|
Restricted
cash-current |
|
|
2,500,000 |
|
|
|
2,500,000 |
|
Restricted cash-non current |
|
|
|
|
|
|
|
|
Total
Cash and cash equivalent and Restricted cash |
|
$ |
6,567,987 |
|
|
$ |
9,403,499 |
|
As
of June 30, 2021 and December 31, 2020, the restricted cash-current was comprised of (i) cash held in a special account as collateral
against a bank loan with amount equal to $1,000,000
and $1,000,000
respectively, and (ii) cash held in a time
deposit account at Bank Mandiri’s Jakarta Cut Mutia Branch with amount equal to $1,500,000
and $1,500,000,
respectively (such restricted cash is used as collateral for the issuance of a bank guarantee related to the implementation of the Company’s
contractual commitments for Citarum Block).
NOTE
4 – OTHER ASSETS
SCHEDULE OF OTHER ASSETS
|
|
|
|
|
|
|
|
|
Consumables
and spare parts (i) |
|
$ |
412,971 |
|
|
$ |
296,611 |
|
Operational
Advance in Indonesian Rupiah |
|
|
301,998 |
|
|
|
138,416 |
|
Prepaid
taxes |
|
|
288,007 |
|
|
|
154,736 |
|
Prepaid to Vendor |
|
|
246,882 |
|
|
|
- |
|
Prepaid Business Insurance |
|
|
90,377 |
|
|
|
21,597 |
|
Others |
|
|
57,965 |
|
|
|
94,576 |
|
Prepaid expenses and advances |
|
|
|
|
|
|
254,589 |
|
Other
assets –current |
|
$ |
1,398,200 |
|
|
$ |
705,936 |
|
|
|
|
|
|
|
|
|
|
Durable
spare parts (i) |
|
$ |
350,668 |
|
|
$ |
328,006 |
|
Deposit
and others |
|
|
316,314 |
|
|
|
254,608 |
|
Other
assets –non current |
|
$ |
666,982 |
|
|
$ |
582,614 |
|
(i) |
The
balances include durable spare parts, consumable chemicals and replacement parts. Where there is evidence that the utility of these assets,
in their disposal in the ordinary course of business, will be less than cost due to physical deterioration, obsolescence, changes in
price levels, or other causes, these assets are written down to their net realizable value. For the six months ended June 30, 2021 and
2020, there were no other assets write-downs. |
NOTE
5 – OIL AND GAS PROPERTY, NET
The
following tables summarize the Company’s oil and gas activities by classification.
SCHEDULE OF OIL AND GAS ACTIVITIES
|
|
June
30,
2021 |
|
|
December
31,
2020 |
|
|
|
|
(Unaudited) |
|
|
|
|
|
Oil
and gas property – subject to amortization |
|
$ |
22,053,581 |
|
|
$ |
20,912,041 |
|
Accumulated
depletion and impairment |
|
|
(19,839,524 |
) |
|
|
(19,573,054 |
) |
Oil
and gas property – subject to amortization, net |
|
$ |
2,214,057 |
|
|
$ |
1,338,987 |
|
|
|
|
|
|
|
|
|
|
Oil
and gas property – not subject to amortization |
|
$ |
1,129,500 |
|
|
$ |
1,113,494 |
|
Accumulated
impairment |
|
|
- |
|
|
|
- |
|
Oil
and gas property – not subject to amortization, net |
|
$ |
1,129,500 |
|
|
$ |
1,113,494 |
|
The
following shows the movement of the oil and gas property – subject to amortization balance.
SCHEDULE OF MOVEMENT OF THE OIL AND GAS PROPERTY
|
|
|
Oil
& Gas Property – Kruh |
|
December
31, 2020 |
|
$ |
1,338,987 |
|
Additional
capitalization |
|
|
1,141,540 |
|
Depletion |
|
|
(266,470 |
) |
June
30, 2021 (Unaudited) |
|
$ |
2,214,057 |
|
For
the six months ended June 30, 2021, the Company incurred an aggregated development costs and abandonment and site restoration provisions,
which were capitalized, at $1,141,540,
mainly for the purpose of drilling 3 new wells at Kruh Block, geological and geophysical studies as well as development
administration for these new wells.
Depletion
recorded for production on properties subject to amortization for the six months ended June 30, 2021 and 2020, were $266,470 and $265,625,
respectively.
Furthermore,
for the six months ended June 30, 2021, the Company did not
record any impairment to the oil and gas property according to the ceiling tests conducted, which showed that the present value of estimated
future net revenues generated by the oil and gas property exceeded the carrying balances.
NOTE
6 – PROPERTY AND EQUIPMENT, NET
SCHEDULE OF PROPERTY AND EQUIPMENT, NET
|
|
June
30,
2021 |
|
|
December
31,
2020 |
|
|
|
|
(Unaudited) |
|
|
|
|
|
Housing
and welfare |
|
$ |
4,312 |
|
|
$ |
4,312 |
|
Furniture
and office equipment |
|
|
4,013 |
|
|
|
4,013 |
|
Computer
and software |
|
|
5,605 |
|
|
|
5,605 |
|
Production
facilities |
|
|
93,049 |
|
|
|
93,049 |
|
Drilling
and production tools |
|
|
1,499,535 |
|
|
|
1,499,535 |
|
Equipment |
|
|
1,650 |
|
|
|
1,650 |
|
Total |
|
|
1,608,164 |
|
|
|
1,608,164 |
|
Less:
accumulated depreciation |
|
|
(1,493,313 |
) |
|
|
(1,476,835 |
) |
Property
and equipment, net |
|
$ |
114,851 |
|
|
$ |
131,329 |
|
Depreciation
charged to expense amounted to $16,478
and $22,135
for the six months ended June 30, 2021 and 2020, respectively.
NOTE
7 – BANK LOAN
Bank
loans consist of the following:
SCHEDULE OF BANK LOAN
| |
As
of December 31, | |
| |
2020 | | |
2019 | |
PT
Bank UOB Indonesia | |
$ | 980,452 | | |
$ | 1,105,741 | |
Total | |
$ | 980,452 | | |
$ | 1,105,741 | |
On
November 14, 2016, PT Green World Nusantara, an indirect, wholly-owned subsidiary of the Company, entered in an agreement and
obtained a credit facility in the form of an overdraft loan from PT Bank UOB Indonesia with a principal amount not exceeding $1,900,000,
an automatically renewable term of 1
year first due on November 14, 2017, and floating
interest rate spread of 1%
per annum above the interest rate earned by the collateral account in which the Company deposits a balance of $2
million for the purpose of pledging this loan.
The pledge decreased to $1,000,000
since the facility decreased from $1,900,000
to $1,000,000
based on Latest Amendment of Credit Agreement
No. 0875 dated April 1, 2020. The unpaid borrowings were extended and
due on November 14, 2021.
The
Company has booked interest expense on the loan of $5,712
and $5,664
for the six months ended June 30, 2021 and 2020,
respectively. The interest expense is recorded in the other expense on the condensed consolidated statements of operations, and
unpaid interest is recorded in the condensed consolidated balance sheets under accrued expenses.
NOTE
8 – ACCRUED EXPENSES
SCHEDULE OF ACCRUED EXPENSES
|
|
June
30,
2021 |
|
|
December
31,
2020 |
|
|
|
|
(Unaudited) |
|
|
|
|
|
Accrued
interest |
|
$ |
144,440 |
|
|
$ |
133,215 |
|
Accrued
operating expenses (i) |
|
|
748,443 |
|
|
|
296,156 |
|
Total |
|
$ |
892,883 |
|
|
$ |
429,371 |
|
(i) |
Accrued
operating expenses are mainly due to unbilled transactions from vendors related to the operations under the current Kruh Block
Joint Operation Partnership with Pertamina, the Indonesian state-owned oil and gas company (“Pertamina”), which
runs until May 2030 (the “KSO”). |
NOTE
9 – TAXES
The
components of the income tax provision are:
SCHEDULE OF COMPONENTS OF INCOME TAX PROVISION
| |
| 2020 | | |
| 2019 | | |
| 2018 | |
| |
| Years
Ended December 31, | |
| |
| 2020 | | |
| 2019 | | |
| 2018 | |
Current | |
$ | - | | |
$ | - | | |
$ | - | |
Deferred | |
| - | | |
| - | | |
| - | |
Total income
tax provision | |
$ | - | | |
$ | - | | |
$ | - | |
The
reconciliation of income taxes provision computed at the statutory tax rate applicable to income tax provision are as follows:
SCHEDULE OF RECONCILIATION OF INCOME TAXES PROVISION
| |
Years
Ended December 31, | |
| |
2020 | | |
2019 | | |
2018 | |
(Loss) income before
income tax | |
$ | ) | |
$ | ) | |
$ | |
Computed income tax expense (benefit)
with statutory income tax rate | |
| (1,737,925 | ) | |
| (418,434 | ) | |
| 35,247 | |
Effect of tax holiday and preferential
tax rate | |
| 16,759 | | |
| 25,045 | | |
| 21,841 | |
Effect of different tax rates in
other jurisdictions | |
| 1,281,519 | | |
| 130,962 | | |
| 100,390 | |
Effect of different tax rates for
the TAC/KSO operations | |
| (86,668 | ) | |
| (41,896 | ) | |
| 36,286 | |
Effect of tax exemption for unrecovered
expenditures on TAC/KSO operations | |
| 520,007 | | |
| 251,378 | | |
| (217,714 | ) |
Change in
valuation allowance | |
| 6,308 | | |
| 52,945 | | |
| 23,950 | |
Total income
tax provision | |
$ | - | | |
$ | - | | |
$ | - | |
The
components of the deferred tax assets are as follows:
SCHEDULE OF COMPONENTS OF DEFERRED TAX ASSETS
| |
2020 | | |
2019 | |
| |
As
of December 31, | |
| |
2020 | | |
2019 | |
Tax
loss carry forwards | |
$ | 83,203 | | |
$ | 76,895 | |
Total deferred tax assets, gross | |
| 83,203 | | |
| 76,895 | |
Valuation
allowance | |
| (83,203 | ) | |
| (76,895 | ) |
Total deferred
tax assets, net | |
$ | - | | |
$ | - | |
The
current and deferred components of the income tax provision which are substantially attributable to the Company’s subsidiaries
in Indonesia. Due to the unrecovered expenditures on TAC and KSO operations, there was no provision for income taxes for the six months
ended June 30, 2021 and 2020.
The
effective tax rate is based on expected income and statutory tax rates. For interim financial reporting, the Company estimates the annual
tax rate based on projected taxable income for the full year and records an interim income tax provision in accordance with guidance
on accounting for income taxes in an interim period. As the year progresses, the Company refines the estimates of the year’s taxable
income as new information becomes available. The Company’s effective tax rates for the six months ended June 30, 2021 and 2020
were 0% and 0%, respectively.
The
Company did not incur any interest and penalties related to potential underpaid income tax expenses.
NOTE
10 – EQUITY
On
February 18, 2021, the Company issued 35,000
of the Company’s restricted ordinary
shares to Frank Ingriselli, the Company’s President, pursuant to his employment agreement with the Company.
Such ordinary shares were valued at $7.84
per share, which was based on the closing
price of the shares traded on the NYSE American exchange on February 18, 2021 and $274,400 in total was charged to General
and administrative expenses.
NOTE
11 – COMMITMENTS AND CONTINGENCIES
Litigation
From
time to time, the Company may be subject to routine litigation, claims, or disputes in the ordinary course of business. The Company defends
itself vigorously in all such matters. In the opinion of management, no pending or known threatened claims, actions or proceedings against
the Company are expected to have a material adverse effect on its financial position, results of operations or cash flows. However, the
Company cannot predict with certainty the outcome or effect of any such litigation or investigatory matters or any other pending litigation
or claims. There can be no assurance as to the ultimate outcome of any such lawsuits and investigations. The Company has no significant
pending litigation as of June 30, 2021.
Commitments
As
a requirement to acquire and maintain the operatorship of oil and gas blocks in Indonesia, the Company follows a work program and budget
that includes firm capital commitments.
Currently,
Kruh Block is operated under a KSO until May 2030. The Company has material commitments in regards to the development and exploration
activities in the Kruh Block and material commitments in regards to the exploration activity in the Citarum Block under a Production
Sharing Contract with the the Indonesian Special Task Force for Upstream Oil and Gas Business Activities (known as SKK Migas) (the “PSC”).
The following table summarizes future commitments amounts on an undiscounted basis as of June 30, 2021 for all the planned expenditures
to be carried out in Kruh Block and Citarum Block:
SUMMARY OF FUTURE COMMITMENTS AMOUNTS ON AN UNDISCOUNTED FOR ALL THE PLANNED EXPENDITURES
|
|
|
|
|
Future
commitments |
|
|
|
Nature
of commitments |
|
|
Remaining
of 2021 |
|
|
2022 |
|
|
2023
and beyond |
|
Citarum
Block PSC |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Environmental study |
|
|
|
|
|
|
23,217 |
|
|
|
- |
|
|
|
- |
|
Geological
and geophysical (G&G) studies |
|
|
(a)
|
|
|
$ |
- |
|
|
$ |
150,000 |
|
|
$ |
200,000 |
|
2D
seismic |
|
|
(a)
|
|
|
|
- |
|
|
|
3,300,000 |
|
|
|
- |
|
Drilling |
|
|
(b)(c) |
|
|
|
- |
|
|
|
- |
|
|
|
25,000,000 |
|
Total
commitments -Citarum PSC |
|
|
|
|
|
$ |
23,217 |
|
|
$ |
3,450,000 |
|
|
$ |
25,200,000 |
|
Kruh
Block KSO |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
- |
|
Operating
lease commitments |
|
|
(d)
|
|
|
$ |
327,214 |
|
|
$ |
1,522,599 |
|
|
$ |
13,324,526 |
|
Production
facility |
|
|
|
|
|
|
500,000 |
|
|
|
1,500,000 |
|
|
|
3,000,000 |
|
G&G
studies |
|
|
(a)
|
|
|
|
- |
|
|
|
200,000 |
|
|
|
800,000 |
|
Sand
fracturing |
|
|
|
|
|
|
200,000 |
|
|
|
- |
|
|
|
- |
|
2D
seismic |
|
|
(a)
|
|
|
|
- |
|
|
|
1,227,634 |
|
|
|
- |
|
3D
seismic |
|
|
(a)
|
|
|
|
- |
|
|
|
1,227,634 |
|
|
|
- |
|
Drilling |
|
|
(a)(c) |
|
|
|
4,500,000 |
|
|
|
4,500,000 |
|
|
|
18,000,000 |
|
Re-opening
(2 wells) |
|
|
(a)
|
|
|
|
- |
|
|
|
50,000 |
|
|
|
50,000 |
|
Total
commitments -Kruh KSO |
|
|
|
|
|
$ |
5,527,214 |
|
|
$ |
10,227,867 |
|
|
$ |
35,174,526 |
|
Total
Commitments |
|
|
|
|
|
$ |
5,550,431 |
|
|
$ |
13,677,867 |
|
|
$ |
60,374,526 |
|
Nature
of commitments:
|
(a) |
Both
firm commitments and 5 years work program according to the economic model are included in the estimate. Firm capital commitments
represent legally binding obligations with respect to the KSO for Kruh Block or the PSC for Citarum Block in which the contract
specifies the minimum exploration or development work to be performed by the Company within the first three years of the contract.
In certain cases where the Company executes contracts requiring commitments to a work scope, those commitments have been included
to the extent that the amounts and timing of payments can be reliably estimated. |
|
|
|
|
(b) |
Include
one exploration and two delineation wells. |
|
|
|
|
(c) |
Abandonment
and site restoration are primarily upstream asset removal costs at the drilling completion of a field life related to or associated with site clearance, site restoration, and site remediation,
based on Indonesian government rules. |
|
|
|
|
(d) |
Operating
lease commitments are contracts that allow for the use of an asset but does not convey rights
of ownership of the asset. An operating lease presents an off-balance sheet financing of
assets, where a leased asset and associated liabilities of future rent payments are not included
on the balance sheet of a company. An operating lease represents a rental agreement for an
asset from a lessor under the terms. Most of the Company’s operating leases are related to the equipment
and machinery used in oil production. All of the Company’s operating lease agreements with third parties
can be cancelled or terminated at any time by the Company. |
NOTE
12 – GOING CONCERN
The
Company reported a net loss of $2,932,213
and net cash used in operating activities of $1,635,829
for the six months ended June 30, 2021. In addition, the Company had an accumulated deficit of $30,666,995
and working capital of $6,488,761
as of June 30, 2021. However, considering the planned level of capital expenditures during the next twelve months, the
Company expects to incur a capital deficit. These conditions raise substantial doubt about the
Company’s ability to continue as a going concern.
When preparing the condensed consolidated
financial statements as of June 30, 2021, the Company’s management concluded that a going concern basis of preparation was
appropriate after analyzing the cash flow forecast for the next twelve months. In preparing the cash flow analysis, management took
into account the Company’s ability to reduce capital expenditures when there is lack of available cash, and the
Company’s ability to obtain financial support to fund any shortfall in cash requirements from potential public and private
issuances of its securities, funding from its principal shareholder and through bank debt with banks in Indonesia with which the
Company has pre-existing relationships.
Based on the Company’s current
liquidity and anticipated funding requirements, particular if the Company’s efforts discussed above are unsuccessful if the
Company fails to achieve these goals, the Company will likely need additional financing to execute its business plan. If additional
financing is required, the Company cannot predict whether this additional financing will be in the form of equity, debt, or another
form, and the Company may not be able to obtain the necessary additional capital on a timely basis, on acceptable terms, or at all.
In the event that financing sources are not available from any source, or that the Company is unsuccessful in increasing its
revenues, achieving profitability gross profit margin and reducing operating losses, the Company may be unable to implement its
current plans for expansion, repay debt obligations or respond to competitive pressures, any of which would have a material adverse
effect on the Company’s business, prospects, financial condition and results of operations.
Management prepared the condensed
consolidated financial statements assuming the Company will continue as a going concern. However, there is no assurance that the
measures above can be achieved as planned. The condensed consolidated financial statements do not include any adjustments that might
result from the outcome of this uncertainty. If the Company is unable to continue as a going concern, it may have to liquidate its
assets and may receive less than the value at which those assets are carried on the financial statements.
NOTE
13 – SUBSEQUENT EVENTS
The
Company evaluated all events that occurred subsequent to June 30, 2021 through the issuance of the condensed consolidated financial
statements, and determined that no events that would have required adjustment or disclosure in the condensed consolidated financial
statements.
REPORT
OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM
To
the Shareholders and Board of Directors of
Indonesia
Energy Corporation Limited
Opinion
on the Financial Statements
We
have audited the accompanying consolidated balance sheets of Indonesia Energy Corporation Limited (the “Company”)
as of December 31, 2020 and 2019, the related consolidated statements of operations and comprehensive (loss) income, changes in
equity (deficit) and cash flows for each of the three years in the period ended December 31, 2020, and the related notes (collectively
referred to as the “financial statements”). In our opinion, the financial statements present fairly, in all material
respects, the financial position of the Company as of December 31, 2020 and 2019, and the results of its operations and its cash
flows for each of the three years in the period ended December 31, 2020, in conformity with accounting principles generally accepted
in the United States of America.
Explanatory
Paragraph – Going Concern
The
accompanying consolidated financial statements have been prepared assuming that the Company will continue as a going concern.
As more fully described in Note 18, the Company has a significant working capital deficiency, has incurred significant losses
and needs to raise additional funds to meet its obligations and sustain its operations. These conditions raise substantial doubt
about the Company’s ability to continue as a going concern. Management’s plans in regard to these matters are also described in
Note 18. The consolidated financial statements do not include any adjustments that might result from the outcome of this uncertainty.
Basis
for Opinion
These
financial statements are the responsibility of the Company’s management. Our responsibility is to express an opinion on
the Company’s financial statements based on our audits. We are a public accounting firm registered with the Public Company
Accounting Oversight Board (United States) (“PCAOB”) and are required to be independent with respect to the Company
in accordance with the U.S. federal securities laws and the applicable rules and regulations of the Securities and Exchange Commission
and the PCAOB.
We
conducted our audits in accordance with the standards of the PCAOB. Those standards require that we plan and perform the audits
to obtain reasonable assurance about whether the financial statements are free of material misstatement, whether due to error
or fraud. The Company is not required to have, nor were we engaged to perform, an audit of its internal control over financial
reporting. As part of our audits we are required to obtain an understanding of internal control over financial reporting but not
for the purpose of expressing an opinion on the effectiveness of the Company’s internal control over financial reporting.
Accordingly, we express no such opinion.
Our
audits included performing procedures to assess the risks of material misstatement of the financial statements, whether due to
error or fraud, and performing procedures that respond to those risks. Such procedures included examining, on a test basis, evidence
regarding the amounts and disclosures in the financial statements. Our audits also included evaluating the accounting principles
used and significant estimates made by management, as well as evaluating the overall presentation of the financial statements.
We believe that our audits provide a reasonable basis for our opinion.
/s/
Marcum Bernstein & Pinchuk LLP
Marcum
Bernstein & Pinchuk LLP
We
have served as the Company’s auditor since 2018.
New
York, New York
May
17, 2021
INDONESIA
ENERGY CORPORATION LIMITED
CONSOLIDATED
BALANCE SHEETS
The
accompanying notes are an integral part of these consolidated financial statements
INDONESIA
ENERGY CORPORATION LIMITED
CONSOLIDATED
STATEMENTS OF OPERATIONS AND COMPREHENSIVE (LOSS) INCOME
* | The shares are
presented on a retroactive basis to reflect the nominal share issuance and the reverse stock split |
The
accompanying notes are an integral part of these consolidated financial statements
INDONESIA
ENERGY CORPORATION LIMITED
CONSOLIDATED
STATEMENTS OF CHANGES IN EQUITY (DEFICIT)
* | The shares are
presented on a retroactive basis to reflect the nominal share issuance and the reverse stock split |
The
accompanying notes are an integral part of these consolidated financial statements
INDONESIA
ENERGY CORPORATION LIMITED
CONSOLIDATED
STATEMENTS OF CASH FLOWS
The
accompanying notes are an integral part of these consolidated financial statements
INDONESIA
ENERGY CORPORATION LIMITED
NOTES
TO THE CONSOLIDATED FINANCIAL STATEMENTS
NOTE
1 – ORGANIZATION AND PRINCIPAL ACTIVITIES
Indonesia
Energy Corporation Limited (the “Company” or “IEC”)
Indonesia
Energy Corporation Limited was formed on April 24, 2018 as an exempted company with limited liability under the laws of the Cayman
Islands and is a holding company for WJ Energy Group Limited (or “WJ Energy”), which in turn owns 100% of the operating
subsidiaries in Indonesia, which are described below. The Company has two shareholders: Maderic Holding Limited (or “Maderic”)
and HFO Investment Group (or “HFO”), which hold 87.04% and 12.96%, respectively, of IEC’s outstanding shares,
prior to the initial public offering (“IPO”). Certain of IEC’s officers and directors own interests in Maderic
and HFO. The Company, through its subsidiaries in Hong Kong and in Indonesia, is an oil and gas exploration and production company
focused on the Indonesian market. The Company currently holds two oil and gas assets through subsidiaries in Indonesia: one producing
block (the Kruh Block) and one exploration block (the Citarum Block). The Company also identified a potential third exploration
block (the Rangkas Area).
WJ
Energy Group Limited (or “WJ Energy”)
WJ
Energy was incorporated in Hong Kong on June 3, 2014 as a holding company.
PT
Green World Nusantara (or “GWN”)
On
February 27, 2015, WJ Energy acquired GWN as a vehicle to acquire and thereafter operate the Kruh Block.
PT
Harvel Nusantara Energi (or “HNE”)
On
March 20, 2017, HNE, an Indonesian limited liability company, was acquired by WJ Energy as a required vehicle for oil and gas
block acquisitions in compliance with Indonesian law.
PT
Cogen Nusantara Energi (or “CNE”)
On
December 7, 2017, CNE, an Indonesian limited liability company, was acquired under HNE as a required vehicle for the prospective
acquisition of a new oil and gas block through a joint study program in consortium with GWN.
PT
Hutama Wiranusa Energi (or “HWE”)
On
May 14, 2018, HWE, was formed under GWN as a requirement to sign the contract for the acquisition of Citarum Block as part of
the consortium that conducted the joint study for the Citarum Block.
The
following diagram illustrates the Company’s structure, including its consolidated holding and operating subsidiaries:
Corporate
Restructuring
In
anticipation of the IPO of the Company’s equity securities, a restructuring was initiated in June 2018. On June 30, 2018,
the Company entered into two agreements with Maderic and HFO (the two then shareholders of WJ Energy): a Sale and Purchase of
Shares and Receivables Agreement and a Debt Conversion Agreement (collectively, the “Restructuring Agreements”). The
intention of the Restructuring Agreements was to restructure the Company’s capitalization. As a result of the transactions
contemplated by the Restructuring Agreements: (i) WJ Energy (including its assets and liabilities) became a wholly-owned subsidiary
of the Company, (ii) loans amounting to $21,150,000 and $3,150,000 that were owed by WJ Energy to Maderic and HFO, respectively,
were converted for nominal value into ordinary shares of the Company and (iii) the Company issued an aggregate of 15,999,000 ordinary
shares to Maderic and HFO.
As
a result, the Company became the ultimate holding company of WJ Energy, GWN, HNE and its subsidiaries, which were all controlled
by the same shareholders before and after the restructuring Therefore, the restructuring was accounted for as a legal reorganization
of the entities under common control in a manner akin to a pooling of interest. The accompanying consolidated financial statements
have been prepared as if the current corporate structure has been in existence throughout the periods presented. The consolidation
of the Company and its subsidiaries has been accounted for at historical cost as of the beginning of the first period presented
in the accompanying consolidated financial statements.
Details
of the subsidiaries of the Company are set out below:
SUMMARY OF DETAILS OF THE SUBSIDIARIES OF THE COMPANY
| |
| | |
| |
Percentage
of | | |
|
| |
Date
of | | |
Place of | |
effective | | |
Principal |
Name | |
Incorporation | | |
Incorporation | |
ownership | | |
Activities |
WJ Energy Group Limited
(“WJ Energy”) | |
| June
3, 2014 | | |
Hong Kong | |
| 100 | % | |
Holding company |
| |
| | | |
| |
| | | |
|
PT Green World Nusantara (“GWN”) | |
| February
27, 2015 | | |
Indonesia | |
| 100 | % | |
Kruh Block operation |
| |
| | | |
| |
| | | |
|
PT Harvel Nusantara Energi (“HNE”) | |
| March
20, 2017 | | |
Indonesia | |
| 100 | % | |
Holding company |
| |
| | | |
| |
| | | |
|
PT Cogen Nusantara Energi (“CNE”) | |
| December
7, 2017 | | |
Indonesia | |
| 100 | % | |
Citarum Block operation |
| |
| | | |
| |
| | | |
|
PT Hutama Wiranusa Energi (“HWE”) | |
| May
14, 2018 | | |
Indonesia | |
| 100 | % | |
Citarum Block operation |
Kruh
Block Technical Assistance Contract (“TAC”) and Joint Operation Partnership (“KSO”)
The
Company’s revenue and potential for profit depend mostly on the level of oil production in Kruh Block and the Indonesian
Crude Price (“ICP”) that is correlated to international crude oil prices.
The
Kruh Block operation is governed by the TAC established between GWN and PT Pertamina (Persero) (“Pertamina”), under
which the Company has the operatorship to, but not the ownership of, the extraction and production of oil from the designated
oil deposit location in Indonesia until May 2020 and the operatorship of Kruh Block will continue as a KSO from May 2020 until
May 2030. During the operations, the Company pays all expenditures and obligations incurred including but not limited to exploration,
development, extraction, production, transportation, abandonment and site restoration. These costs, depending on the purpose,
are either capitalized on the balance sheet as Oil and gas property – subject to amortization, net, or expensed as lease
operating expenses. Section “Oil & Gas Property, Full Cost Method” of Note 2 provides further discussion about
the accounting treatment of these costs.
On
a monthly basis, based on TAC, the Company submits to Pertamina an Entitlement Calculation Statement (“ECS”) stating
the amount of money that GWN is entitled to. Such entitlement is made through the proceeds of the sale, conducted by Pertamina,
of the crude oil produced in the block on a monthly basis based on the prevailing ICP, but capped at 65% of such monthly proceeds.
In addition, the Company is also entitled to an additional 26.79% of the remaining 35% of the proceeds from the sale of the crude
oil as part of the profit sharing. Both of these two portions of entitlements are recognized as revenue of the Company, net of
tax. Section “Revenue Recognition” of Note 2 provides further discussion about the accounting treatment of these entitlement.
After
May 2020, the Company continued the operatorship of Kruh Block under a KSO contract. In essence, the TAC and KSO are very similar
in nature due to its “cost recovery” system, with a few important differences to note. The main differences between
the two contracts are that: (1) in the TAC, all oil produced is shareable between Pertamina and its contractor, while in the KSO,
a Non-Shareable Oil (NSO) production is determined and agreed between Pertamina and its partners so that the baseline production,
with an established decline rate, belongs entirely to Pertamina, so that the partners’ revenue and production sharing portion
shall be determined only from the production above the NSO baseline; (2) in the TAC, the cost recovery was capped at 65% (sixty-five
percent) of the proceeds from the sale of the oil produced in the block, while in the KSO, the cost recovery is capped at 80%
of the proceeds from the sale of the oil produced within Kruh Block for the cost incurred during the term under the KSO plus 80%
of the operating cost per bbl multiplying NSO. Any remaining cost recovery balance from the KSO period of contract is carried
over to the next period, although the cost recovery balance from the TAC contract will not be carried over to the KSO, meaning
that the cost recovery balance were reset to nil with the commencement of the operatorship under the KSO in May 2020.
NOTE
2 – SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES
Basis
of presentation and consolidation
The
consolidated financial statements of the Company have been prepared in accordance with accounting principles generally accepted
in the United States of America (“US GAAP”).
The
consolidated financial statements include the financial statements of the Company and all its majority-owned subsidiaries from
the dates they were acquired or incorporated. All intercompany balances and transactions have been eliminated in consolidation.
Use
of estimates
The
preparation of the consolidated financial statements in conformity with US GAAP requires management of the Company to make a number
of estimates and assumptions relating to the reported amounts of assets and liabilities and the disclosure of contingent assets
and liabilities at the date of the consolidated financial statements and the reported amounts of revenues and expenses during
the period. Significant accounting estimates reflected in the Company’s consolidated financial statements include but are
not limited to estimates and judgments applied in the allowance for receivables, write down of other assets, estimated useful
lives of property and equipment, oil and gas depletion, impairment of long-lived assets, provision for post-employment benefit
and going concern. Actual results could differ from those estimates and judgments.
Cash
and cash equivalents
Cash
and cash equivalents consist of cash on hand, bank deposits and short-term, highly liquid investments that are readily convertible
to known amounts of cash, and have insignificant risk of changes in value related to changes in interest rates with original maturities
of three months or less, which are unrestricted as to withdrawal and use.
Restricted
cash
Restricted
cash include cash pledged for bank loan facilities, cash deposits in special account for the abandonment and site restoration
and as performance guarantee in the oil and gas concessions in which the Company operates.
Financial
statements in United States Dollars
The
reporting currency of the Company is United States dollar (“USD”, “dollar”). The currency of the primary
economic environment in which the operations of the Company are conducted is dollar. Therefore, the dollar has been determined
to be the Company’s functional currency. Non-dollar transactions and balances have been translated into dollars for financial
reporting purposes. Transactions in foreign currency (primarily in Indonesian Rupiahs – “IDR”) are recorded
at the exchange rate as of the transaction date. Monetary assets and liabilities denominated in foreign currency are translated
on the basis of the representative rates of exchange at the balance sheet dates. All exchange gains and losses from re-measurement
of monetary balance sheet items denominated in non-dollar currencies are reflected in the statement of operations as they arise.
Accounts
receivable and other receivables
Accounts
receivable and other receivables are recorded at net realizable value consisting of the carrying amount less an allowance for
uncollectible accounts as needed. The allowance for doubtful accounts is the Company’s best estimate of the amount of probable
credit losses in the Company’s existing accounts receivable and other receivables. The Company determines the allowance
based on aging data, historical collection experience, customer specific facts and economic conditions. Account balances are charged
off against the allowance after all means of collection have been exhausted and the potential for recovery is considered remote.
The Company did not have any off-balance-sheet credit exposure relating to its customers, suppliers or others. For the years ended
December 31, 2020, 2019 and 2018, the Company did not record any allowances for doubtful accounts against its accounts receivable
and other receivables nor did it charge off any such amounts, respectively.
Credit
and concentration risk
As
of December 31, 2020 and 2019, all of the Company’s accounts receivable result from the entitlement of Oil & Gas Property
subject to amortization and profit sharing from the sale of the crude oil under the TAC and KSO by Pertamina. This concentration
of receivables from one party may impact the Company’s overall credit risk, either positively or negatively, in that Pertamina
may be similarly affected by changes in economic or other conditions.
For
the years ended December 31, 2020, 2019 and 2018, 100% of the Company’s revenues were generated through the operatorship
of Kruh Block. The Company does not believe that there will be any material adverse change in the operatorship of Kruh Block or
the TAC and KSO.
Property
and equipment, net
Property
and equipment are stated at cost less accumulated depreciation and accumulated impairment losses. Cost represents the purchase
price of the asset and other costs incurred to bring the asset into its existing use. Maintenance and repairs are charged to expense;
major additions to physical properties are capitalized.
Depreciation
of property and equipment is provided using the declining balance method over their estimated useful lives:
SCHEDULE OF PROPERTY AND EQUIPMENT ESTIMATED USEFUL LIVES
|
|
|
Useful
life |
|
Housing
and welfare |
|
|
10
years |
|
Furniture
and office equipment |
|
|
5
years |
|
Computer
and software |
|
|
5
years |
|
Production
facilities |
|
|
5
years |
|
Drilling
and production tools |
|
|
5
years |
|
Equipment |
|
|
5
years |
|
Upon
sale or disposal, the applicable amounts of asset cost and accumulated depreciation are removed from the accounts and the net
amount less proceeds from disposal is charged or credited to income.
Impairment
of long-lived assets
The
Company reviews its long-lived assets for impairment whenever events or changes in circumstances indicate that the carrying amount
of an asset may no longer be recoverable. When these events occur, the Company assesses the recoverability of the long-lived assets
by comparing the carrying value of the long-lived assets to the estimated undiscounted future cash flows expected to result from
the use of the assets and their eventual disposition, where the fair value is lower than the carrying value, an impairment loss
is recognized in the consolidated statements of operations and comprehensive (loss) income for the difference between the fair
value, using the expected future discounted cash flows, and the carrying value of the assets.
Oil
& Gas Property, net, Full Cost Method
The
Company follows the full-cost method of accounting for the Oil & Gas Property. Under the full-cost method, all productive
and non-productive costs incurred in the acquisition, exploration and development associated with properties with proven reserves,
such as the TAC and KSO Kruh Block, are capitalized. As of December 31, 2020 and 2019, all capitalized costs associated with Kruh’s
reserves were subject to amortization. Capitalized costs are subject to a quarterly ceiling test that limits such costs to the
aggregate of the present value of estimated future net cash flows of proved reserves, computed using the unweighted arithmetic
average of the first-day-of the-month oil and gas prices for each month within the 12-month period prior to the end of reporting
period, discounted at 10%, and the lower of cost or fair value of proved properties. If unamortized costs capitalized exceed the
ceiling, the excess is charged to expense in the period the excess occurs. There were no cost ceiling write-downs for the years
ended December 31, 2020, 2019 and 2018.
Depletion
for each of the reported periods is computed on the units-of-production method. Depletion base is the total capitalized oil and
gas property in the previous period, plus the period capitalization and future development costs. Furthermore, the depletion rate
is calculated as the depletion base divided by the total estimated proved reserves that expected to be extracted during the operatorship.
Then, depletion is calculated as the production of the period times the depletion rate.
For
the years ended December 31, 2020, 2019 and 2018, the estimated proved reserves were considered based on the operatorship of the
Kruh Block expiring in May 2030, as the Company completed all administrative steps of the
process to obtain the extension of the operatorship of the Kruh Block in the last quarter of 2018 and the uncertainty regarding
the extension was removed.
The
costs associated with properties with unproved reserves or under development, such as Production Sharing Contract (“PSC”)
Citarum Block, are not initially included in the full-cost depletion base. The costs include but are not limited to unproved property
acquisition costs, seismic data and geological and geophysical studies associated with the property. These costs are transferred
to the depletion base once the reserve has been determined as proven.
Deferred
charges
Deferred
charges mainly represent the compensation paid for the acquisition of the oil and gas mineral rights to the employer of the block,
such as Pertamina or SKK Migas, for information, equipment and services, signature bonus and other fees required by law for the
operatorship of a TAC, KSO or PSC. As these payments are made as part of the requirements for the participating in the bidding
of the oil and gas operatorship contract, such payments are amortized on a straight-line basis throughout the contract period.
Asset
retirement obligations
The
Company measures its obligations for the retirement of the oil fields using various assumptions such as the expected period upon
the expiry of the contract and the complete depletion of the oil deposits underground, the degree of the damage the operation
had done to the oil field, and the related governmental requirements imposed on the Company as a contractor. The asset retirement
obligation is reviewed and adjusted each quarter for any liabilities incurred or settled during the period, accretion expense
and any revisions made to the estimated cash flows and changes required by Pertamina.
As
of December 31, 2020 and 2019, asset retirement obligations were $321,253 and $222,344, respectively.
Provision
for post-employment benefit
Post-employment
benefits are recognized, pursuant to the regulatory requirements under the Indonesia Labor Law Article 167 Law No. 13 of 2003,
to capture the amount the Company is obligated to pay, in lump-sum, to the employees hired under the governance of TAC and KSO
upon its maturity. Such recognition is reviewed on an annual basis during the period in which the employees provide their services
to the Company and is performed through the involvement of an actuary.
Actuarial
gains or losses are recognized in the other comprehensive income (“OCI”) and excluded permanently from profit or loss.
Expected returns on plan assets are not recognized in profit or loss. Expected returns are replaced by recognizing interest income
(or expense) on the net defined asset (or liability) in profit or loss, which is calculated using the discount rate used to measure
the pension obligation.
All
past service costs will be recognized at the earlier of when the amendment/curtailment occurs or when the Entity recognizes related
restructuring or termination costs.
Such
changes are made in order that the net pension assets or liabilities are recognized in the statement of financial position to
reflect the full value of the plan deficit or surplus.
The
following table summarizes the quantitative information about the Company’s level 3 fair value measurements in the determination
of the balance of the post-employment benefits, which utilize significant unobservable inputs:
SUMMARY OF QUANTITATIVE INFORMATION ABOUT LEVEL 3 FAIR VALUE MEASUREMENTS OF POST-EMPLOYMENT BENEFITS
Actuarial Assumption | |
December
31, 2020 | | |
December
31, 2019 | |
Discount Rate | |
| 5.98 | % | |
| 4.93 | % |
Expected Return on Plan Assets | |
| N/A | | |
| 4.93 | % |
Wage Increase Rate | |
| 7.00 | % | |
| 9.00 | % |
Mortality Rate | |
| Table
Mortality Index (“TMI”) of Indonesia, TMI IV 2019 | | |
| Table
Mortality Index (“TMI”) of Indonesia, 2011 | |
Disability Rate | |
| 5%
of TMI IV 2019 | | |
| 5%
of TMI 2011 | |
Normal retirement age | |
| 58
Years (All employees are assumed to retire at pension age). With work contract until
May 22, 2030 | | |
| 58
Years (All employees are assumed to retire at pension age). With work contract until
May 31, 2020 | |
Withdrawal
Rate |
|
Age | | |
Rate | | |
Age | | |
Rate | |
|
|
20
– 29 | | |
| 5 | % | |
| 20
- 29 | | |
| 5 | % |
|
|
30 – 39 | | |
| 4 | % | |
| 30
- 39 | | |
| 4 | % |
|
|
49 – 44 | | |
| 3 | % | |
| 49
- 44 | | |
| 3 | % |
|
|
45 – 49 | | |
| 2 | % | |
| 45
- 49 | | |
| 2 | % |
|
|
50 – 57 | | |
| 1 | % | |
| 50
- 57 | | |
| 1 | % |
|
|
>57 | | |
| 0 | % | |
| >57 | | |
| 0 | % |
The
Company adopted ASC Topic 606, “Revenue from Contracts with Customers” on January 1, 2019, using the modified retrospective
method applied to contract that was not completed as of January 1, 2019, the TAC with Pertamina. Under the modified retrospective
method, prior period financial positions and results will not be adjusted. The cumulative effect adjustment recognized in the
opening balances included no significant changes as a result of this adoption.
The
Company recognizes revenue from the entitlement of Oil & Gas Property - Kruh Block Proven and profit sharing from the sale
of the crude oil under the TAC and KSO with Pertamina, when the Entitlement Calculation Sheets have been submitted to Pertamina
after the monthly Indonesian Crude Price (“ICP”) has been published by the Government of Indonesia. The Company delivers
the crude oil it produces to Pertamina Jirak Gathering Station (“Pertamina-Jirak”), located approximately 3 miles
away from Kruh Block. After the volume and quality of the crude oil delivered is accepted and recorded by Pertamina, Pertamina
is responsible for the ultimate sales of the crude to the end-users. The total volume of crude oil sold is confirmed by Pertamina
and, combining with the monthly published ICP, the Company calculates the entire amount of its entitlement with Pertamina through
the Entitlement Calculation Sheets, at which point revenue is recognized.
The
revenue is calculated based on the proceeds of the sales of the crude oil produced by the Company and conducted by Pertamina,
For TAC with a 65% cap on the proceeds of such sale as part of the cost recovery scheme, on a monthly basis, calculated by
multiplying the quantity of crude oil produced by the Company and the prevailing ICP published by the Government of
Indonesia. In addition, the Company is also entitled to an additional 26.7857% of the remaining 35% of such sales proceeds as
part of the profit sharing. Both of these two portions are recognized as revenue of the Company, net of tax. For KSO with a
80% cap on the proceeds of such sale as part of the cost recovery scheme, on a monthly basis, calculated by multiplying the
quantity of crude oil produced by the Company and the prevailing ICP published by the Government of Indonesia plus 80% of the operating cost per bbl multiplying Non-Shareable Oil (“NSO”). In addition,
the Company is also entitled to an additional 23.5294% (twenty-three point five two nine four percent) of the remaining 20%
of such sales proceeds as part of the profit sharing. In the TAC, all oil produced is shareable between Pertamina and the
Company, while in the KSO, a NSO production is determined and agreed between Pertamina and the Company so that the baseline
production, with an established decline rate, belongs entirely to Pertamina, so that the Company’s revenue and
production sharing portion shall be determined only from the production above the NSO baseline;
Accordingly,
there were no significant changes to the timing or valuation of revenue recognized for sales of production from exploration and
production activities.
The
Company does not have any contract assets (unbilled receivables) since revenue is recognized when control of the crude oil is
transferred to the refinery and the payment for the crude oil is not contingent on a future event.
There
were no significant contract liabilities or transaction price allocations to any remaining performance obligations as of December
31, 2020 and 2019.
Income
taxes
The
Company follows the asset and liability method of accounting for income taxes. Under this method, deferred tax assets and liabilities
are recorded for the estimated future tax consequences attributable to the differences between the financial carrying amounts
of existing assets and liabilities and their respective tax basis. Deferred tax assets and liabilities are measured using the
tax rate in effect for the year in which those temporary differences are expected to reverse. The effect of a change in tax rates
on deferred tax assets and liabilities is recognized in the year of the enacted rate change. A valuation allowance is established
to reduce deferred tax assets if it is more likely than not that the related tax benefits will not be realized.
Uncertain
tax positions
The
Company follows the guidance of ASC Topic 740 “Income taxes”, which prescribes a more likely than not threshold for
financial statement recognition and measurement of a tax position taken or expected to be taken in a tax return. This Topic also
provides guidance on recognition of income tax assets and liabilities, classification of current and deferred income tax assets
and liabilities, accounting for interest and penalties associated with tax positions, accounting for income taxes in interim periods,
and income tax disclosures. The Company recognizes interest on non-payment of income taxes and penalties associated with tax positions
when a tax position does not meet more likely than not thresholds be sustained under examination. The tax returns of the IEC’s
subsidiaries are subject to examination by the relevant tax authorities. According to the Directorate General of Tax of the Republic
of Indonesia, the statute of limitations is 10 years for the company keeping the documents transaction for tax examination. There
is no statute of limitation in the case of tax evasion. The Company recognizes the provisions and any interest and penalties within
the income tax expense line item in the accompanying Consolidated Statements of operations. The accrued provisions and any related
interest and penalties are included in the other tax liabilities account.
For
years ended December 31, 2020, 2019 and 2018, the Company did not have any material interest or penalties associated with tax
positions nor did the Company have any significant unrecognized uncertain tax benefits. The Company does not expect that its assessment
regarding unrecognized tax position will materially change over the following 12 months. The Company is not currently under examination
by an income tax authority, nor has been notified that an examination is contemplated.
Non-controlling
interest
A
non-controlling interest in a subsidiary of the Company represents the portion of the equity (net assets) in the subsidiary not
directly or indirectly attributable to the Company. Net loss and other comprehensive loss attributable to non-controlling shareholders
are presented as a separate component on the consolidated statement of operations and comprehensive loss for the year ended December
31, 2018. There were no non-controlling interests presented on the consolidated balance sheets as of December 31, 2020 and 2019
as such non-controlling interest was bought out in the year end December 31, 2018.
Fair
value of financial instruments
The
Company records certain of its financial assets and liabilities at fair value on a recurring basis. Fair value is considered to
be the price that would be received from selling an asset or paid to transfer a liability in an orderly transaction between market
participants at the measurement date. When determining the fair value measurements for assets and liabilities required or permitted
to be recorded at fair value, the Company considers the principal or most advantageous market in which it would transact and considers
assumptions that market participants would use when pricing the asset or liability. The established fair value hierarchy requires
an entity to maximize the use of observable inputs and minimize the use of unobservable inputs when measuring fair value. A financial
instrument’s categorization within the fair value hierarchy is based upon the lowest level of input that is significant
to the fair value measurement. The three levels of inputs may be used to measure fair value include:
Level |
1
applies to assets or liabilities for which there are quoted prices in active markets for identical assets or liabilities. |
Level |
2
applies to assets or liabilities for which there are inputs other than quoted prices included within Level 1 that are observable
for the asset or liability such as quoted prices for similar assets or liabilities in active markets; quoted prices for identical
assets or liabilities in markets with insufficient volume or infrequent transactions (less active markets); or model-derived
valuations in which significant inputs are observable or can be derived principally from, or corroborated by, observable market
data. |
Level |
3
applies to assets or liabilities for which there are unobservable inputs to the valuation methodology that are significant
to the measurement of the fair value of the assets or liabilities. |
The
carrying values of the Company’s financial instruments, including cash and cash equivalents, restricted cash, accounts receivable,
other receivables, accounts payables, due from and due to related parties, other current liabilities, accrued expenses and tax
payables, approximate their fair values due to the short-term nature of these instruments.
Liabilities
measured at fair value on a recurring basis by level within the fair value hierarchy as of December 31, 2020 and 2019 are as follows:
SCHEDULE OF LIABILITIES MEASURED AT FAIR VALUE ON A RECURRING BASIS BY LEVEL WITHIN FAIR VALUE HIERARCHY
|
|
|
|
|
Fair
value measurement at reporting date using |
|
|
|
As
of
December
31,
2020 |
|
|
Quoted
Prices
in
Active Markets
for
Identical
Assets/Liabilities
(Level
1) |
|
|
Significant
Other
Observable
Inputs
(Level
2) |
|
|
Significant
Unobservable
Inputs
(Level
3) |
|
Provision
for post-employment benefit |
|
$ |
68,701 |
|
|
$ |
- |
|
|
$ |
- |
|
|
$ |
68,701 |
|
|
|
|
|
|
Fair
value measurement at reporting date using |
|
|
|
As
of
December
31,
2019 |
|
|
Quoted
Prices
in
Active Markets
for
Identical
Assets/Liabilities
(Level
1) |
|
|
Significant
Other
Observable
Inputs
(Level
2) |
|
|
Significant
Unobservable
Inputs
(Level
3) |
|
Provision
for post-employment benefit |
|
$ |
- |
|
|
$ |
- |
|
|
$ |
- |
|
|
$ |
- |
|
Segment
reporting
The
Company uses the “management approach” in determining reportable segments. The management approach considers the internal
organization and reporting used by the Company’s chief operating decision maker (CODM) for making operating decisions and
assessing performance as the source for determining the Company’s reportable segments. The Company’s CODM has been
identified as the chief executive officer, who reviews consolidated results when making decisions about allocating resources and
assessing performance of the Company.
The
Company manages its business as a single operating segment engaged in upstream Oil and Gas industry in Indonesia. Substantially
all of its revenues are derived in Indonesia. All long-lived assets are located in Indonesia.
Comprehensive
income
Comprehensive
income consists of two components, net income and other comprehensive income. Other comprehensive income refers to revenue, expenses,
gains and losses that under U.S. GAAP are recorded as an element of equity but are excluded from net income or loss. Other comprehensive
income or loss consists of actuarial gain or loss for post-employment benefits.
Commitments
and contingencies
The
Company’s estimated loss contingencies are accrued by a charge to income when information available before financial statements
are issued or are available to be issued indicates that it is probable that an asset had been impaired, or a liability had been
incurred at the date of the financial statements and the amount of the loss can be reasonably estimated. Legal expenses associated
with the contingency are expensed as incurred. If a loss contingency is not probable or reasonably estimable, disclosure of the
loss contingency is made in the financial statements when it is at least reasonably possible that a material loss could be incurred.
Recently
issued accounting standards
The
Company is an “emerging growth company,” as defined in the Jumpstart Our Business Startups Act of 2012 (the “JOBS
Act”). Under the JOBS Act, emerging growth companies (“EGCs”) can delay adopting new or revised accounting standards
issued subsequent to the enactment of the JOBS Act until such time as those standards apply to private companies.
In
February 2016, FASB issued ASU No. 2016-02, Leases (Topic 842). The guidance supersedes existing guidance on accounting for leases
with the main difference being that operating leases are to be recorded in the statement of financial position as right-of-use
assets and lease liabilities, initially measured at the present value of the lease payments. For operating leases with a term
of 12 months or less, a lessee is permitted to make an accounting policy election not to recognize lease assets and liabilities.
In July 2018, ASU 2016-02 was updated with ASU 2018-11, Targeted Improvements to ASC Topic 842, which provides entities with relief
from the costs of implementing certain aspects of the new leasing standard. Specifically, under the amendments in ASU 2018-11,
(1) entities may elect not to recast the comparative periods presented when transitioning to ASC 842 and (2) lessors may elect
not to separate lease and non-lease components when certain conditions are met. In November 2019, ASU 2019-10, Codification Improvements
to ASC 842 modified the effective dates of all other entities. In June 2020, ASU 2020-05 defer the effective date for one year
for entities in the “all other” category. For all other entities, the amendments in ASU 2020-05 are effective for
fiscal years beginning after December 15, 2021, and interim periods within fiscal years beginning after December 15, 2022. Early
application of the guidance continues to be permitted. The Company will adopt ASU 2016-02 from January 1, 2022. The Company is
in the process of evaluating the effect of the adoption of this ASU.
In
June 2016, the FASB issued ASU No. 2016-13, “Financial Instruments – Credit Losses”, which will require the
measurement of all expected credit losses for financial assets held at the reporting date based on historical experience, current
conditions, and reasonable and supportable forecasts. Subsequently, the FASB issued ASU No. 2018-19, Codification Improvements
to Topic 326, to clarify that receivables arising from operating leases are within the scope of lease accounting standards. Further,
the FASB issued ASU No. 2019-04, ASU 2019-05, ASU 2019-10, ASU 2019-11 and ASU 2020-02 to provide additional guidance on the credit
losses standard. For all other entities, the amendments for ASU 2016-13 are effective for fiscal years beginning after December
15, 2022, including interim periods within those fiscal years, with early adoption permitted. Adoption of the ASUs is on a modified
retrospective basis. The Company will adopt ASU 2016-13 from January 1, 2023. The adoption
is not expected to have a material impact on its consolidated financial statements.
Other
accounting pronouncements that have been issued or proposed by the FASB or other standards-setting bodies that do not require
adoption until a future date are not expected to have a material impact on the Company’s consolidated financial statements
upon adoption.
NOTE
3 – CASH, CASH EQUIVALENTS AND RESTRICTED CASH
The
following table provides a reconciliation of cash, cash equivalents, and restricted cash reported within the Consolidated Balance
Sheets that sum to the total of the same such amounts shown in the Consolidated Statements of Cash Flows:
SCHEDULE OF CASH, CASH EQUIVALENTS AND RESTRICTED CASH
| |
2020 | | |
2019 | |
| |
As
of December 31, | |
| |
2020 | | |
2019 | |
Cash and cash equivalent | |
$ | 6,903,499 | | |
$ | 12,241,339 | |
Restricted cash-current | |
| 2,500,000 | | |
| 2,064,130 | |
Restricted
cash-non current | |
| - | | |
| 1,766,700 | |
Total Cash
and cash equivalent and Restricted cash | |
$ | 9,403,499 | | |
$ | 16,072,169 | |
As
of December 31, 2020 and 2019, the restricted cash -current related to (i) cash held in a special account as collateral against
a bank loan with amount to $1,000,000 and $2,000,000 respectively, (ii) cash held by Restricted Cash in Bank Time Deposit for
Cutting Mutia is $1,500,000 and nil, respectively.
NOTE
4 – ACCOUNTS RECEIVABLE, NET
SCHEDULE OF ACCOUNTS RECEIVABLE
| |
2020 | | |
2019 | |
| |
As
of December 31, | |
| |
2020 | | |
2019 | |
Accounts receivable | |
$ | 1,131,954 | | |
$ | 350,672 | |
Allowance
for doubtful accounts | |
| - | | |
| - | |
Accounts receivable,
net | |
$ | 1,131,954 | | |
$ | 350,672 | |
The
Company analyzed the collectability of accounts receivable based on historical collection and the customers’ intention of
payment and, as a result of such analysis, the Company did not recognize any allowance for doubtful accounts for the years ended
December 31, 2020, 2019 and 2018. All balances as of December 31, 2020 and 2019 have been fully collected in the subsequent year.
NOTE
5 – OTHER ASSETS
SCHEDULE OF OTHER ASSETS
| |
2020 | | |
2019 | |
| |
As
of December 31, | |
| |
2020 | | |
2019 | |
Consumables and spare
parts | |
$ | 296,611 | | |
$ | 248,367 | |
Prepaid taxes | |
| 154,736 | | |
| 75,534 | |
Prepaid expenses and advances | |
| 254,589 | | |
| 94,683 | |
Other assets
-current | |
$ | 705,936 | | |
$ | 418,584 | |
| |
| | | |
| | |
Durable spare parts | |
$ | 328,006 | | |
$ | 249,588 | |
Deposit and
others | |
| 254,608 | | |
| 262,517 | |
Other assets
–non current | |
$ | 582,614 | | |
$ | 512,105 | |
NOTE
6 – OIL AND GAS PROPERTY, NET
The
following tables summarize the Company’s oil and gas activities by classification.
SCHEDULE OF OIL AND GAS ACTIVITIES
| |
2020 | | |
2019 | |
| |
As
of December 31, | |
| |
2020 | | |
2019 | |
Oil and gas property
– subject to amortization | |
$ | 20,912,041 | | |
$ | 20,345,797 | |
Accumulated
depletion and impairment | |
| (19,573,054 | ) | |
| (18,918,311 | ) |
Oil and gas
property – subject to amortization, net | |
$ | 1,338,987 | | |
$ | 1,427,486 | |
| |
| | | |
| | |
Oil and gas property – not
subject to amortization | |
$ | 1,113,494 | | |
$ | 958,133 | |
Accumulated
impairment | |
| - | | |
| - | |
Oil and gas
property – not subject to amortization, net | |
$ | 1,113,494 | | |
$ | 958,133 | |
The
following shows the movement of the oil and gas property – subject to amortization balance.
SCHEDULE OF MOVEMENT OF THE OIL AND GAS PROPERTY
| |
Oil
& Gas Property – Kruh | |
January 1, 2018 | |
$ | 2,911,730 | |
Additional capitalization | |
| 166,871 | |
Depletion | |
| (1,078,784 | ) |
January 1, 2019 | |
$ | 1,999,817 | |
Additional capitalization | |
| 245,202 | |
Depletion | |
| (817,533 | ) |
December 31, 2019 | |
$ | 1,427,486 | |
Additional capitalization | |
| 566,244 | |
Depletion | |
| (654,743 | ) |
December 31, 2020 | |
$ | 1,338,987 | |
During
the years ended December 31, 2020, 2019, and 2018 the Company incurred an aggregated development costs and abandonment and site
restoration provisions, which were capitalized, at $566,244, $245,202 and $166,871 respectively, mainly for the purpose of the
geological and geophysical studies and drilling of wells.
Depletion
recorded for production on properties subject to amortization for the years ended December 31, 2020, 2019 and 2018 were $654,743,$817,533
and $1,078,784 respectively.
Furthermore,
the Company did not record any impairment to the Oil and gas property -Kruh Block Proven as a result of the ceiling tests conducted
due to that the present value of estimated future net revenues generated by the Oil and gas property -Kruh Block Proven exceeded
the carrying balances on the Consolidated Balance Sheets.
NOTE
7 – PROPERTY AND EQUIPMENT, NET
SCHEDULE OF PROPERTY AND EQUIPMENT, NET
| |
As
of December 31, | |
| |
2020 | | |
2019 | |
Housing and welfare | |
$ | 4,312 | | |
$ | 4,312 | |
Furniture and office equipment | |
| 4,013 | | |
| 4,013 | |
Computer and software | |
| 5,605 | | |
| 5,605 | |
Production facilities | |
| 93,049 | | |
| 93,049 | |
Drilling and production tools | |
| 1,499,535 | | |
| 1,499,535 | |
Equipment | |
| 1,650 | | |
| 1,650 | |
Total | |
| 1,608,164 | | |
| 1,608,164 | |
Less: accumulated
depreciation | |
| (1,476,835 | ) | |
| (1,432,727 | ) |
Property and
equipment, net | |
$ | 131,329 | | |
$ | 234,580 | |
Depreciation
charged to expense amounted to $44,108, $59,143 and$77,710 for the years ended December 31, 2020, 2019 and 2018, respectively.
NOTE
8 – BANK LOAN
Bank
loans consist of the following:
SCHEDULE OF BANK LOAN
| |
As
of December 31, | |
| |
2020 | | |
2019 | |
PT
Bank UOB Indonesia | |
$ | 980,452 | | |
$ | 1,105,741 | |
Total | |
$ | 980,452 | | |
$ | 1,105,741 | |
On
November 14, 2016, GWN, a subsidiary of the Company, entered in an agreement and obtained a credit facility in the form of an
overdraft loan with a principal amount not exceeding $1,900,000, an automatically renewable term of 1 year first due on November
14, 2017, and floating interest rate spread of 1% per annum above the interest rate earned by the collateral account in which
the Company deposits a balance of $2 million for the purpose of pledging this loan. The pledge decreased to $1,000,000 since the
facility decreased from $1,900,000 to $1,000,000 on March 2, 2020. The unpaid borrowings were extended to the next year.
The
Company has booked interest expense on the loan of$10,891, $11,991 and $16,194 for the years ended December 31, 2020, 2019 and
2018, respectively. The interest expense is recorded in the other income (expenses), net on the consolidated statements of operations
and comprehensive (loss) income, and unpaid interest is recorded in the consolidated balance sheets under accrued expenses.
NOTE
9 – RELATED PARTIES BALANCE AND TRANSACTIONS
Related
parties with whom the Company had transactions are:
Related
Parties |
|
Relationship |
Maderic
Holding Limited |
|
Shareholder
of IEC |
HFO
Investment Group Limited |
|
Shareholder
of IEC |
Coalville
Holdings Limited |
|
Controlled
by Dr. Wirawan Jusuf |
Mr.
Ignatius Indiarto |
|
Commissioner
of GWN, subsidiary of IEC |
Mr.
Mirza F. Said |
|
Chief
Business Development Officer of IEC |
The
related party transactions during the years ended December 31, 2020 ,2019 and 2018 are as follows:
SCHEDULE OF RELATED PARTY TRANSACTIONS
| |
Years
Ended December 31, | |
| |
2020 | | |
2019 | | |
2018 | |
Repayment from
a related party | |
| | | |
| | | |
| | |
Coalville
Holdings Limited | |
$ | - | | |
$ | - | | |
$ | 160,100 | |
Repayment
from a related party | |
$ | - | | |
$ | - | | |
$ | 160,100 | |
| |
| | | |
| | | |
| | |
Loan from a related
party | |
| | | |
| | | |
| | |
Maderic Holding Limited | |
$ | - | | |
$ | 3,800,000 | | |
$ | 4,500,000 | |
Repayment to
related parties | |
| | | |
| | | |
| | |
Maderic Holding Limited | |
| - | | |
| (3,800,000 | ) | |
| (2,140,000 | ) |
Net
loan from related parties | |
$ | - | | |
$ | - | | |
$ | 2,360,000 | |
| |
| | | |
| | | |
| | |
Shareholder debts
converted to capital contribution | |
| | | |
| | | |
| | |
Maderic Holding Limited | |
$ | - | | |
$ | - | | |
$ | 21,150,000 | |
HFO Investment
Group Limited | |
| - | | |
| - | | |
| 3,150,000 | |
Total shareholder
debts converted to capital contribution | |
$ | - | | |
$ | - | | |
$ | 24,300,000 | |
| |
| | | |
| | | |
| | |
NCI subscription
receivables transferred to the Company | |
| | | |
| | | |
| | |
Mr. Ignatius Indiarto (HNE) | |
$ | - | | |
$ | - | | |
$ | 7,750 | |
Mr. Mirza F. Said (HNE) | |
| - | | |
| - | | |
| 7,455 | |
Mr. Mirza
F. Said (CNE) | |
| - | | |
| - | | |
| 7,750 | |
Total NCI
subscription receivables transferred to the Company | |
$ | - | | |
$ | - | | |
$ | 22,955 | |
NOTE
10 – ACCRUED EXPENSES
Accrued
expenses are comprised as follows:
SCHEDULE OF ACCRUED EXPENSES
| |
2020 | | |
2019 | |
| |
As
of December 31, | |
| |
2020 | | |
2019 | |
Accrued interest | |
$ | 133,215 | | |
$ | 106,563 | |
Accrued operating
expenses | |
| 296,156 | | |
| 469,823 | |
Total | |
$ | 429,371 | | |
$ | 576,386 | |
Accrued
interest represented the accrual of interests from the $1,000,000 loan from Thalesco Eurotronics Pte Ltd (Note 13 LONG TERM LOAN)
and accrual of interests from bank loan (Note 8 BANK LOAN).
Accrued
operating expenses mainly due to unpaid professional fees and unbilled transactions from vendors related to the operations in
the Kruh Block TAC and KSO.
During the
year ended December 31, 2020 the Company wrote off a payable in the amount of $146,662 due to a vendor as it has
been deemed remote for the vendor to request the Company to pay the balance.
NOTE
11 – TAXES
The
Company and its subsidiaries file tax returns separately.
1)
Value added tax (“VAT”)
The
Company’s subsidiaries’ activities and revenues are not subject to VAT. VAT is typically due on events involving the
transfer of taxable goods or the provision of taxable services in the Indonesia, except for some goods and services, such as mining
or drilling products extracted directly from their sources, for example crude oil, natural gas and geothermal energy.
Nevertheless,
the Company’s subsidiaries are classified as VAT Collectors. As the name implies, VAT Collector is required to collect the
VAT due from a taxable enterprise (vendor) on the delivery to it of taxable goods or services and to pass the VAT payment directly
to the government, rather than to the vendor or the service provider. The VAT Collectors are currently the State Treasury, State
Owned Enterprises (Badan Usaha Milik Negara/BUMN) and some of their subsidiaries, and PSC (Production Sharing Contract) companies
such as the Company’s. This means that, although the Company is not subject to VAT, the Company has the obligation to collect
the VAT and pay the VAT on behalf of the Company’s vendors to the Indonesian government.
2)
Income tax
Cayman
Islands
The
Company is incorporated in the Cayman Islands. Under the current laws of the Cayman Islands, the Company is not subject to income
or capital gains taxes. In addition, dividend payments are not subject to withholdings tax in the Cayman Islands.
Hong
Kong
WJ
Energy does not have assessable profits derived from Hong Kong, and accordingly is not subject to Hong Kong taxation.
Indonesia
The
Company’s subsidiaries incorporated in Indonesia are subject to Indonesia Corporate Income Tax (“CIT”) law.
Pursuant to the Indonesia CIT law, given the specific year (2000) in which the TAC was signed, GWN’s TAC operations are
subject to a CIT rate of 30%. Unless that GWN fully recovers its expenditures, the GWN’s TAC operations are effectively
exempted from the application of the CIT. Upon the expiry of the TAC, any unrecovered portion of the Kruh Block oil and gas investment
will be deemed as waived by the Company and will not be available for tax deduction purposes for any future earnings. As of December
31, 2020 and 2019, the unrecovered expenditures on TAC operations are $16,766,664.59 and $16,373,223, respectively.
Other
Indonesia subsidiaries are subject to a flat standard CIT rate of 25%, on which these subsidiaries would also enjoy a 50% discount
over the standard CIT rate provided that each of these subsidiaries’ annual revenue proceed is less than 50 billion Rupiah
(or approximately $374,000) per year.
The
components of the income tax provision are:
SCHEDULE OF COMPONENTS OF INCOME TAX PROVISION
| |
| 2020 | | |
| 2019 | | |
| 2018 | |
| |
| Years
Ended December 31, | |
| |
| 2020 | | |
| 2019 | | |
| 2018 | |
Current | |
$ | - | | |
$ | - | | |
$ | - | |
Deferred | |
| - | | |
| - | | |
| - | |
Total income
tax provision | |
$ | - | | |
$ | - | | |
$ | - | |
The
reconciliation of income taxes provision computed at the statutory tax rate applicable to income tax provision are as follows:
SCHEDULE OF RECONCILIATION OF INCOME TAXES PROVISION
| |
Years
Ended December 31, | |
| |
2020 | | |
2019 | | |
2018 | |
(Loss) income before
income tax | |
$ | ) | |
$ | ) | |
$ | |
Computed income tax expense (benefit)
with statutory income tax rate | |
| (1,737,925 | ) | |
| (418,434 | ) | |
| 35,247 | |
Effect of tax holiday and preferential
tax rate | |
| 16,759 | | |
| 25,045 | | |
| 21,841 | |
Effect of different tax rates in
other jurisdictions | |
| 1,281,519 | | |
| 130,962 | | |
| 100,390 | |
Effect of different tax rates for
the TAC/KSO operations | |
| (86,668 | ) | |
| (41,896 | ) | |
| 36,286 | |
Effect of tax exemption for unrecovered
expenditures on TAC/KSO operations | |
| 520,007 | | |
| 251,378 | | |
| (217,714 | ) |
Change in
valuation allowance | |
| 6,308 | | |
| 52,945 | | |
| 23,950 | |
Total income
tax provision | |
$ | - | | |
$ | - | | |
$ | - | |
The
components of the deferred tax assets are as follows:
SCHEDULE OF COMPONENTS OF DEFERRED TAX ASSETS
| |
2020 | | |
2019 | |
| |
As
of December 31, | |
| |
2020 | | |
2019 | |
Tax
loss carry forwards | |
$ | 83,203 | | |
$ | 76,895 | |
Total deferred tax assets, gross | |
| 83,203 | | |
| 76,895 | |
Valuation
allowance | |
| (83,203 | ) | |
| (76,895 | ) |
Total deferred
tax assets, net | |
$ | - | | |
$ | - | |
The
Company considers positive and negative evidence to determine whether some portion or all of the deferred tax assets will more
likely than not be realized. This assessment considers, among other matters, the nature, frequency and severity of recent losses,
forecasts of future profitability, the duration of statutory carry forward periods, the Company’s experience with tax attributes
expiring unused and tax planning alternatives. Valuation allowances have been established for deferred tax assets based on a more-likely-than-not
threshold. The Company’s ability to realize deferred tax assets depends on its ability to generate sufficient taxable income
within the carry forward periods provided for in the tax law. As of December 31, 2020 and 2019, the Company had tax operating
loss carry forwards of $118,533 and $181,875, respectively from its subsidiary in Hong Kong and $509,156 and $375,086, respectively
from its subsidiaries in Indonesia, which can be carried forward to offset taxable income. The net operating loss will be carried
forwards indefinitely under Hong Kong Tax regulations, while the net operating loss will expire in year 2023 if not utilized under
Indonesian Tax regulations. For the years ended December 31, 2020 and 2019, the Company recognized a valuation allowance against
deferred tax assets on tax loss carry forward of $83,203 and $76,895, respectively.
NOTE
12 – PROVISION FOR POST-EMPLOYMENT BENEFITS
Provision
for post-employment benefits consists of the following:
SCHEDULE OF PROVISION FOR POST-EMPLOYMENT BENEFITS
| |
As
of December 31, | |
| |
2020 | | |
2019 | |
Provision
for post-employment benefits | |
$ | 68,701 | | |
$ | - | |
The
provision for post-employment benefits are recognized in the period in which the benefit is earned by the employee, rather than
when it is paid or payable.
The
following outlines how each category of employee benefits are measured, providing reconciliation on present value of Defined Benefit
Obligation and Plan Asset.
SCHEDULE OF RECONCILIATION ON PRESENT VALUE OF DEFINED BENEFIT OBLIGATION AND PLAN ASSETS
| |
As
of December 31, | |
| |
2020 | | |
2019 | |
Present Value of Defined Benefit Obligation (DBO) and Fair
Value of Plan Assets | |
| | |
| |
Present Value of DBO,
at the Beginning of Year | |
$ | - | | |
$ | 264,253 | |
Current service cost | |
| 68,701 | | |
| 75,695 | |
Interest cost on the DBO | |
| - | | |
| 16,188 | |
Employee benefits are already noted
for quit employees | |
| - | | |
| - | |
Exchange rate
impact | |
| - | | |
| 12,805 | |
Present Value of DBO, (expected)
at the End of Year | |
| 68,701 | | |
| 368,941 | |
Actuarial
gain on DBO | |
| | | |
| (4,179 | ) |
Present Value
of DBO, (actual) at the End of Year | |
$ | 68,701 | | |
$ | 364,762 | |
| |
| | | |
| | |
Fair Value of Plan Assets at the
Beginning of Year | |
$ | - | | |
$ | 236,621 | |
Interest income on Plan Assets | |
| - | | |
| 14,496 | |
Company contribution to Plan Assets | |
| - | | |
| 105,052 | |
Exchange rate
impact | |
| - | | |
| 12,223 | |
Fair Value of Plan Assets, (expected)
at the End of Year | |
| - | | |
| 368,392 | |
Actuarial
gain or loss on Plan Assets | |
| - | | |
| 6,528 | |
Fair Value
of Plan Assets, (actual) at the End of Year | |
$ | - | | |
$ | 374,920 | |
| |
| | | |
| | |
The effect
of asset ceiling | |
| - | | |
| (10,158 | ) |
| |
| | | |
| | |
Provision
for post-employment benefits | |
$ | 68,701 | | |
$ | - | |
The
following are key information for the recalculation of employee benefits obligations as of December 31, 2020 and 2019:
SCHEDULE OF KEY INFORMATION FOR THE RECALCULATION OF EMPLOYEE BENEFITS OBLIGATIONS
| |
As
of December 31, | |
| |
2020 | | |
2019 | |
Liabilities at the Beginning
of Year | |
$ | - | | |
$ | 27,632 | |
Post-employment benefits costs | |
| 68,701 | | |
| 77,388 | |
Actuarial gain on liabilities | |
| - | | |
| (549 | ) |
Company contribution | |
| - | | |
| (105,052 | ) |
Employee benefits paid | |
| - | | |
| - | |
Exchange rate
impact | |
| - | | |
| 581 | |
Liabilities
at the End of Year | |
$ | 68,701 | | |
$ | - | |
The
Company recorded actuarial gain of nil, $549 and $20,356 for the years ended December 31, 2020, 2019 and 2018, respectively.
NOTE
13 – LONG TERM LOAN
SCHEDULE OF LONG TERM LIABILITIES
| |
As
of December 31, | |
| |
2020 | | |
2019 | |
Loan
from a third party | |
$ | 1,000,000 | | |
$ | 2,000,000 | |
Total | |
$ | 1,000,000 | | |
$ | 2,000,000 | |
On
July 19, 2016, GWN entered into a loan agreement with Thalesco Eurotronics Pte Ltd. and obtained a loan facility in the amount
of $2,000,000 with original maturity date on July 30, 2017, and renewed until July 30, 2020, to finance the drilling of one well
in Kruh Block. On June 3, 2019, the loan was further extended until May 22, 2023.The
loan bears an interest rate of 1.5% per annum. On August 25, 2020, the Company repaid $1,000,000 in the principal to Thalesco
Eurotronics Pte Ltd. The Company has booked interest expense on the loan of $24,380, $30,009 and $32,468 for the years ended December
31, 2020, 2019 and 2018, respectively. The interest expense is recorded in the other income (expenses), net in the consolidated
statement of operations and comprehensive (loss) income, and unpaid interest is recorded in the consolidated balance sheets under
accrued expenses.
NOTE
14 – EQUITY
Immediately
before and after the restructuring (Note 1), the ultimate owners’ equity interests of WJ Energy were identical to those
of the Company. Accordingly, the restructuring was accounted for as a legal reorganization of the entities under common control
in a manner akin to a pooling of interest as if the Company, through its wholly owned subsidiaries, had been in existence throughout
the periods presented in the consolidated financial statements.
The
Company was established under the laws of the Cayman Islands on April 24, 2018 and IEC issued 1,000 ordinary shares to Maderic.
The authorized number of ordinary shares was 100,000,000 shares with par value of US$0.001 each upon establishment.
On
June 30, 2018, the Company entered into two agreements with Maderic and HFO (the two then shareholders of WJ Energy): a Sale and
Purchase of Shares and Receivables Agreement and a Debt Conversion Agreement (collectively, the “Restructuring Agreements”).
The intention of the Restructuring Agreements was to restructure the Company’s capitalization. As a result of the transactions
contemplated by the Restructuring Agreements: (i) WJ Energy (including its assets and liabilities) became a wholly-owned subsidiary
of the Company, (ii) loans amounting to $21,150,000 and $3,150,000 that were owed by WJ Energy to Maderic and HFO, respectively,
were converted for nominal value into ordinary shares of the Company and (iii) the Company issued an aggregate of 15,999,000 ordinary
shares to Maderic and HFO. The above mentioned transaction is accounted for as a nominal share issuance (the “Nominal Share
Issuance”).
On
November 8, 2019, the Company implemented a one-for-zero point three seven five (1 for 0.375) stock split of the Company’s
ordinary shares by way of share consolidation under Cayman Islands law (the “Reverse Stock Split”), which in turn
decreased the total of 16,000,000 issued and outstanding ordinary shares to a total of 6,000,000 issued and outstanding ordinary
shares for the purpose of achieving a certain share price as part of certain listing requirements of the NYSE American. Any fractional
ordinary share that would have otherwise resulted from the Reverse Stock Split was rounded up to the nearest full share. The Reverse
Stock Split maintained the shareholders’ percentage ownership interests in the Company at 87.04% owned by Maderic (5,222,222
ordinary shares) and 12.96% owned by HFO (777,778 ordinary shares), out of a total of 6,000,000 issued ordinary shares. The Reverse
Stock Split also increased the par value of the ordinary shares from $0.001 to $0.00267 and decreased the number of authorized
ordinary shares of the Company from 100,000,000 to 37,500,000 and authorized preferred shares from 10,000,000 to 3,750,000. The
Reverse Stock Split did not alter the total dollar amount of the ordinary shares of the Company. All number of shares and per
share data presented in the consolidated financial statements and related notes have been retroactively restated to reflect the
Nominal Share Issuance and the Reverse Stock Split stated above.
On
December 19, 2019, the Company listed its ordinary shares on the NYSE American in the IPO. As a result, the Company issued a total
of 1,363,637 ordinary shares at a price to the public of $11.00 per share in connection with its IPO and received net proceeds
of approximately US$12.5 million, after deducting underwriting discounts and the offering expenses. Upon the completion of the
IPO, the Company had a total of 7,363,637 ordinary shares.
NOTE
15 – SHARE BASED COMPENSATION EXPENSES
a)
Description of share option plans
On
October 31, 2018, the Company’s board of directors and shareholders adopted a 2018 Omnibus Equity Incentive Plan for the
Company.
On
February 1, 2019, the Company entered into share option agreements, an Incentive Share Option (“Option”) to purchase
ordinary shares of the Company, with the senior management team of the Company, as part of the Company’s equity incentive
plan, granting options to purchase a total number of 1,700,000 ordinary shares of the Company. The option shares were distributed
to the President, Chief Executive Officer, Chief Operating Officer, Chief Business Development Officer and Chief Investment Officer
of the Company, with the exercise price per share equal to the price per ordinary share paid by public investors in the Company’s
registered IPO.
In
connection with the Reverse Stock Split described in Note 14, the total number of stock options granted on February 1, 2019, decreased
from 1,700,000 to 637,500.
On
December 19, 2019, associated the Company’s registered IPO, a mutual understanding between the Company and the executive
management, about the nature of the compensatory and equity relationships established by the Option award were established. 637,500
share options were granted to the executive management with an exercise price of $11.00.
b)
Valuation assumptions
The
estimated fair value of each share option granted is estimated on the date of grant using the Black-Scholes option-pricing model
with the following assumptions:
SCHEDULE OF BLACK SCHOLES STOCK OPTION PRICING VALUATION ASSUMPTIONS
| |
Date
of grant | |
Expected volatility | |
| 96.49%-99.62 | % |
Risk-free interest
rate | |
| 1.79 | % |
Expected term from grant date
(in years) | |
| 3.50-6.00 | |
Dividend rate | |
| - | |
Dilution factor | |
| 0.9203 | |
Fair value | |
| $7.01-$8.26 | |
The
expected volatility at each grant date was estimated based on the annualized standard deviation of the daily return embedded in
historical share prices of comparable peer companies with a time horizon close to the expected expiry of the term of the share
options. The weighted average volatility is the expected volatility at the grant date weighted by the number of the share options.
The Company has
never declared or paid any cash dividends on its capital stock, and the Company does
not anticipate any dividend payments in the foreseeable future. Contractual term is the remaining contract life of the share options.
The Company estimated the risk-free interest rate based on the yield to maturity of U.S. treasury bonds denominated in US
dollars at the share option grant date.
c)
Share options activities
SCHEDULE OF SHARE OPTIONS ACTIVITIES
|
|
Options
Outstanding |
|
|
Weighted
Average
Exercise
Price |
|
|
Weighted
Average
Remaining
Contractual
Life |
|
|
Aggregate
Intrinsic
Value |
|
|
|
|
|
|
|
|
|
(In
years) |
|
|
|
|
Outstanding
as of January 1, 2019 |
|
|
- |
|
|
|
- |
|
|
|
- |
|
|
|
- |
|
Granted |
|
|
637,500 |
|
|
$ |
11.00 |
|
|
|
8.82 |
|
|
|
- |
|
Exercised |
|
|
- |
|
|
|
- |
|
|
|
- |
|
|
|
- |
|
Forfeited |
|
|
- |
|
|
|
- |
|
|
|
- |
|
|
|
- |
|
Outstanding
as of December 31, 2019 |
|
|
637,500 |
|
|
$ |
11.00 |
|
|
|
8.80 |
|
|
|
- |
|
Granted |
|
|
- |
|
|
|
- |
|
|
|
- |
|
|
|
- |
|
Exercised |
|
|
- |
|
|
|
- |
|
|
|
- |
|
|
|
- |
|
Forfeited |
|
|
- |
|
|
|
- |
|
|
|
- |
|
|
|
- |
|
Outstanding
as of December 31, 2020 |
|
|
637,500 |
|
|
$ |
11.00 |
|
|
|
7.80 |
|
|
|
- |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Vested
and expected to vest as of December 31, 2020 |
|
|
637,500 |
|
|
$ |
11.00 |
|
|
|
7.80 |
|
|
|
- |
|
Vested
as of December 31, 2020 |
|
|
237,500 |
|
|
$ |
11.00 |
|
|
|
7.92 |
|
|
|
- |
|
For
the years ended December 31, 2020 and 2019, share-based compensation expenses recognized associated with share options granted
by the Company were $3,007,081 and $247,817, respectively. As of December 31, 2020, there was $1,815,078 of unrecognized share-based
compensation related to the share options granted to the Company’s executive management.
Furthermore,
on April 15, 2020, the Company issued 31,818 ordinary shares to ARC Group Ltd. as a compensation for the advisory services provided
in connection with the Company’s initial public offering, the fair market value of the shares was $3.51 on the issuance
date; On the same date, the Company also issued 12,500 ordinary shares to TraDitigal Marketing Group, Inc. as a compensation for
the marketing services provided in connection with the Company’s initial public offering, the fair market value of the shares
was also $3.51. Total share-based compensation expenses
for such shares granted and issued on April 15, 2020 were $155,556.
NOTE
16 – (LOSS) EARNINGS PER SHARE
The
computation of basic and diluted (loss) earnings per ordinary share is as follows:
SCHEDULE OF COMPUTATION OF BASIC AND DILUTED NET INCOME PER ORDINARY SHARE
| |
Years
Ended December 31, | |
| |
2020 | | |
2019 | | |
2018 | |
Numerator: | |
| | |
| | |
| |
Net
(loss) income attributable to the Company | |
$ | (6,951,698 | ) | |
$ | (1,673,735 | ) | |
$ | 145,723 | |
| |
| | | |
| | | |
| | |
Denominator: | |
| | | |
| | | |
| | |
Basic and
diluted weighted average number of ordinary shares outstanding | |
| 7,395,120 | | |
| 6,048,568 | | |
| 6,000,000 | |
| |
| | | |
| | | |
| | |
Basic and
diluted net (loss) income per ordinary share | |
$ | (0.94 | ) | |
$ | (0.28 | ) | |
$ | 0.02 | |
Due
to the loss for the year ended December 31, 2020 and 2019, 637,500 options to purchase the Company’s ordinary shares were
excluded from the calculation of diluted net loss per share, because the effect would be anti-dilutive.
NOTE
17 – COMMITMENTS AND CONTINGENCIES
Litigation
From
time to time, the Company may be subject to routine litigation, claims, or disputes in the ordinary course of business. The Company
defends itself vigorously in all such matters. In the opinion of management, no pending or known threatened claims, actions or
proceedings against the Company are expected to have a material adverse effect on its financial position, results of operations
or cash flows. However, the Company cannot predict with certainty the outcome or effect of any such litigation or investigatory
matters or any other pending litigation or claims. There can be no assurance as to the ultimate outcome of any such lawsuits and
investigations. The Company has no significant pending litigation as of December 31, 2020.
Commitments
As
a requirement to acquire and maintain the operatorship of oil and gas blocks in Indonesia, the Company follows a work program
and budget that includes firm capital commitments.
The
Kruh block covers a 258 km2 area with a TAC contract until May 20, 2020, continued with a KSO contract until May 20, 2030. The
Company has material commitments in regards to Kruh Block and material commitments in regards to the exploration activity in the
Citarum block and development and exploration activities in Kruh Block following the extension of the operatorship in May 2020.
The Company has also entered into a joint study program for the Rangkas area to evaluate the oil and gas potential of the area.
The following table summarizes future commitments amounts on an undiscounted basis as of December 31, 2020 for all the planned
expenditures to be carried out in Kruh, Citarum and Rangkas blocks:
SUMMARY OF FUTURE COMMITMENTS AMOUNTS ON AN UNDISCOUNTED FOR ALL THE PLANNED EXPENDITURES
| |
| | |
Future
commitments | |
| |
Nature
of commitments | | |
2021 | | |
2022 | | |
2023
and beyond | |
Citarum Block PSC | |
| | | |
| | | |
| | | |
| | |
Environmental
Permits | |
| (c) | | |
| 34,653 | | |
| - | | |
| - | |
G&G studies | |
| (c) | | |
| - | | |
| 150,000 | | |
| 950,000 | |
2D seismic | |
| (c) | | |
| - | | |
| 3,384,727 | | |
| 2,750,000 | |
3D seismic | |
| (c)
| | |
| - | | |
| - | | |
| 2,100,000 | |
Exploratory
Well | |
| (c)
| | |
| - | | |
| - | | |
| 30,000,000 | |
Total
commitments -Citarum PSC | |
| | | |
$ | 34,653 | | |
$ | 3,534,727 | | |
$ | 35,800,000 | |
Kruh Block KSO | |
| | | |
| | | |
| | | |
| | |
Operating lease
commitments | |
| (a) | | |
$ | 1,364,917 | | |
$ | 3,131,019 | | |
$ | 21,864,512 | |
Production facility | |
| (c)
| | |
| 349,726 | | |
| 1,500,000 | | |
| 2,500,000 | |
G&G studies | |
| (c) | | |
| - | | |
| 200,000 | | |
| 1,300,000 | |
2D seismic | |
| (c) | | |
| 1,153,163 | | |
| - | | |
| - | |
3D seismic | |
| (c) | | |
| 1,119,816 | | |
| - | | |
| - | |
Drilling and
sand fracturing | |
| (c) | | |
| 7,500,000 | | |
| 9,000,000 | | |
| 10,500,000 | |
Workover | |
| (c) | | |
| 292,376 | | |
| - | | |
| - | |
Re-opening | |
| (c) | | |
| 63,200 | | |
| - | | |
| - | |
Abandonment and
Site Restoration | |
| (b) | | |
| 32,125 | | |
| 32,125 | | |
| 240,939 | |
Total
commitments - Kruh KSO | |
| | | |
$ | 11,875,323 | | |
$ | 13,863,144 | | |
$ | 36,405,451 | |
Total Commitments | |
| | | |
$ | 11,909,976 | | |
$ | 17,397,871 | | |
$ | 72,205,451 | |
Nature
of commitments:
(a) | | Operating lease
commitments are contracts that allow for the use of an asset but does not convey rights of ownership of the asset. An operating lease
represents an off-balance sheet financing of assets, where a leased asset and associated liabilities of future rent payments are not
included on the balance sheet of a company. An operating lease represents a rental agreement for an asset from a lessor under the terms.
Most of the operating leases are related with the equipment and machinery used in oil production. Rental expenses under operating leases
for the years ended December 31, 2020, 2019 and 2018 were $1,167,097,
$1,184,831,
and $901,106,
respectively. |
(b) | | Abandonment and
site restoration are primarily upstream asset removal costs at the completion of a field life related to or associated with site clearance,
site restoration, and site remediation, based on government rules. |
(c) | | Firm capital commitments
represent legally binding obligations with respect to the KSO of Kruh Block or the PSC of the Citarum Block in which the contract specifies
the minimum exploration or development work to be performed by the Company within the first three years of the contract. In certain cases
where the Company executes contracts requiring commitments to a work scope, those commitments have been included to the extent that the
amounts and timing of payments can be reliably estimated. |
(d) | | Bank guarantee
is a requirement for the assignment and securing of an oil block operatorship contract to guarantee the performance of the Company with
respect to the firm capital commitments. |
NOTE
18 – GOING CONCERN
The
Company experienced net loss of $6,951,698 and $1,673,735, and net cash used in operating activities of $5,186,048 and $439,794
for the years ended December 31, 2020 and 2019, respectively. As of December 31, 2020, the Company had net current assets of $9,413,594,
however, considering the planned level of capital expenditures expected during the next twelve months, there will be an expected
capital deficit to occur. These conditions raise substantial doubt about the Company’s ability to continue as
a going concern.
When
preparing the consolidated financial statements as of December 31, 2020 and for the year then ended, the Company’s
management concluded that a going concern basis of preparation was appropriate after analyzing the cash flow forecast for the
next twelve months. In preparing the cash flow analysis, management took into account the Company’s ability to reduce
capital expenditures when there is lack of available cash, and the Company’s ability to obtain financial support to
fund any shortfall in cash requirements from potential public and private issuances of its securities, funding
from its principal shareholder and through bank debt with banks in Indonesia with which
the Company has pre-existing relationships.
If
the Company fails to achieve these goals, the Company will likely need additional financing to execute its business plan. If
additional financing is required, the Company cannot predict whether this additional financing will be in the form of equity,
debt, or another form, and the Company may not be able to obtain the necessary additional capital on a timely basis, on
acceptable terms, or at all. In the event that financing sources are not available from any source, or that the Company is unsuccessful in
increasing its gross profit margin and reducing operating losses, the Company may be unable to implement its current plans
for expansion, repay debt obligations or respond to competitive pressures, any of which would have a material adverse effect
on the Company’s business, prospects, financial condition and results of operations.
Management
prepared the consolidated financial statements assuming the Company will continue as a going concern. However, there is no assurance
that the measures above can be achieved as planned. The consolidated financial statements do not include any adjustments that
might result from the outcome of this uncertainty. If the Company is unable to continue as a going concern, it may have to liquidate
its assets and may receive less than the value at which those assets are carried on the financial statements.
NOTE
19 – SUBSEQUENT EVENTS
In
March 2020, the World Health Organization declared the COVID-19 as a pandemic. There is ongoing impact of COVID-19, which has
spread rapidly to many parts of the world. The pandemic has resulted in quarantines, travel restrictions, and the temporary closure
of stores and business facilities worldwide for the year. Given the rapidly expanding nature of the COVID-19 pandemic, the Company
believes there is a substantial risk that the Company’s business, results of operations, and financial condition will be
adversely affected. Potential impact to the Company’s results of operations will also depend on future developments and
new information that may emerge regarding the duration and severity of the COVID-19 and the actions taken by government authorities
and other entities to contain the COVID-19 or mitigate its impact, almost all of which are beyond the Company’s control.
The
COVID-19 pandemic has caused the Company to modify its business practices, including restricting employee travel, requiring employees
to work remotely and cancelling physical participation in meetings, events and conferences. Since the COVID-19 outbreak, crude
oil prices have been negatively impacted due to low oil demand, increased production and disputes between the Organization of
the Petroleum Exporting Countries (“OPEC”) and Russia on production cuts. As a consequence, the Company’s revenue
and profit could decrease due to the factors discussed above, and other unforeseen and unpredictable consequences of the COVID-19
outbreak. Besides, the COVID-19 pandemic may disrupt the Company’s ability to raise additional capital to finance the operations
in the future, which could materially and adversely affect the Company’s business, financial condition and prospects.
The
COVID-19 pandemic may also affect our business, financial condition and results of operations for the full year 2021 to some extent.
Except for the impact discussed above, we do not anticipate any prolonged material adverse impact on our business, results of
operations and financial condition from the COVID-19 pandemic. We are nonetheless closely monitoring the development of the COVID-19
pandemic and continuously evaluating any potential impact on our business, results of operations and financial condition.
The
Company has evaluated subsequent events through the issuance of the consolidated financial statements and no other subsequent
event is identified that would have required adjustment or disclosure in the consolidated financial statements.
SUPPLEMENTARY INFORMATION FOR OIL AND GAS PRODUCING ACTIVITIES (UNAUDITED)
The
following supplemental unaudited information regarding the Company’s oil and gas activities is presented pursuant to the
disclosure requirements of ASC 932. All oil and gas operations are located in Indonesia.
All
of the Company’s operations are directly related to oil and natural gas producing activities from the Kruh Block in Indonesia.
Capitalized
Costs Relating to Oil and Gas Producing Activities
SCHEDULE OF CAPITALIZED COSTS
| |
As
of December 31, | |
| |
2020 | | |
2019 | |
Proved properties | |
| | | |
| | |
Mineral
interests | |
$ | 15,084,658 | | |
$ | 15,084,658 | |
Wells,
equipment and facilities | |
| 5,827,383 | | |
| 5,261,139 | |
Total proved properties | |
| 20,912,041 | | |
| 20,345,797 | |
| |
| | | |
| | |
Unproved properties | |
| | | |
| | |
Mineral interests | |
| 1,113,494 | | |
| 958,133 | |
Uncompleted
wells, equipment and facilities | |
| - | | |
| - | |
Total unproved properties | |
| 1,113,494 | | |
| 958,133 | |
| |
| | | |
| | |
Less accumulated
depletion and impairment | |
| (19,573,054 | ) | |
| (18,918,311 | ) |
Net
Capitalized Costs | |
$ | 2,452,481 | | |
$ | 2,385,619 | |
Costs
Incurred in Oil and Gas Property Exploration, and Development
Amounts
reported as costs incurred include both capitalized costs for exploration and development activities and costs charged to expense
for normal maintenance operational activities under TAC and KSO of Kruh Block. Exploration costs presented below include the costs
of drilling and equipping successful and unsuccessful exploration wells during the year, geological and geophysical expenses,
and the costs of retaining undeveloped leaseholds. Development costs include the costs of drilling and equipping development wells,
and construction of related production facilities.
SCHEDULE OF COSTS INCURRED IN OIL AND GAS PROPERTY EXPLORATION, AND DEVELOPMENT
|
|
Years
Ended December 31, |
|
|
|
2020 |
|
|
2019 |
|
|
2018 |
|
GWN
(Kruh) |
|
|
|
|
|
|
|
|
|
|
|
|
Exploration |
|
$ |
- |
|
|
$ |
- |
|
|
$ |
- |
|
Development |
|
|
566,244 |
|
|
|
245,202 |
|
|
|
166,871 |
|
|
|
$ |
566,244 |
|
|
$ |
245,202 |
|
|
$ |
166,871 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
HNE
(Citarum) |
|
|
|
|
|
|
|
|
|
|
|
|
Exploration |
|
$ |
155,362 |
|
|
$ |
142,207 |
|
|
$ |
64,056 |
|
Development |
|
|
- |
|
|
|
- |
|
|
|
- |
|
|
|
$ |
155,362 |
|
|
$ |
142,207 |
|
|
$ |
64,056 |
|
GWN
(Rangkas) |
|
|
|
|
|
|
|
|
|
|
|
|
Exploration |
|
$ |
4,943 |
|
|
$ |
276,810 |
|
|
$ |
87,306 |
|
Development |
|
|
- |
|
|
|
- |
|
|
|
- |
|
|
|
$ |
4,943 |
|
|
$ |
276,810 |
|
|
$ |
87,306 |
|
Results
of Operations from Oil and Gas Producing Activities
Results
of operations for producing activities consist of all activities within the operating reporting segment. Revenues are generated
from entitlement of Oil & Gas Property –Kruh Block Proven and profit sharing of the sale of the crude oil under the
TAC and KSO. Production costs are costs to operate and maintain the Company’s wells, related equipment, and supporting facilities
used in oil and gas operations, including expenditures made and obligations incurred in the exploration, development, extraction,
production, transportation, marketing, abandonment and site restoration; and production-related general and administrative expense.
The results of operations exclude general office overhead and interest expense attributable to oil and gas activities.
SCHEDULE OF RESULTS OF OPERATIONS FROM OIL AND GAS PRODUCING ACTIVITIES
| |
Years
Ended December 31, | |
| |
2020 | | |
2019 | | |
2018 | |
Oil and gas revenues | |
$ | 1,980,773 | | |
$ | 4,183,354 | | |
$ | 5,856,341 | |
Production costs | |
| (2,017,856 | ) | |
| (2,474,230 | ) | |
| (2,540,353 | ) |
Depletion,
depreciation, and amortization | |
| (698,851 | ) | |
| (876,676 | ) | |
| (1,156,494 | ) |
Result of oil and gas producing operations
before income taxes | |
$ | (735,934 | ) | |
$ | 832,448 | | |
$ | (2,159,494 | ) |
Provision
for income taxes | |
| - | | |
| - | | |
| - | |
Results of
oil and gas producing operations | |
$ | (735,934 | ) | |
$ | 832,448 | | |
$ | (2,159,494 | ) |
Proved
Reserves the Company Expects to Lift in Kruh Block
The
Company’s proved oil reserves have not been estimated or reviewed by independent petroleum engineers. The estimate of the
proved reserves for the Kruh Block was prepared by IEC representatives, a team consisting of engineering, geological and geophysical
staff based on the definitions and disclosure guidelines of the United States Securities and Exchange Commission (SEC) contained
in Title 17, Code of Federal Regulations, Modernization of Oil and Gas Reporting, Final Rule released January 14, 2009 in the
Federal Register (SEC regulations).
The
Company’s estimates of the proven reserves are made using available geological and reservoir data as well as production
performance data. These estimates are reviewed annually by internal reservoir engineers, and Pertamina, and revised as warranted
by additional data. Revisions are due to changes in, among other things, development plans, reservoir performance, TAC and KSO
effective period and governmental restrictions.
Kruh
Block’s general manager, Mr. Denny Radjawane, and the Company’s chief operating officer, Mr. Charlie Wu, have reviewed
the reserves estimate to ensure compliance to SEC guidelines for (1) the appropriateness of the methodologies employed; (2) the
adequacy and quality of the data relied upon; (3) the depth and thoroughness of the reserves estimation process; (4) the classification
of reserves appropriate to the relevant definitions used; and (5) the reasonableness of the estimated reserve quantities. The
estimate of reserves was also reviewed by the Company’s chief business development officer and chief executive officer.
The
table below shows the individual qualifications of the Company’s internal team that prepares the reserves estimation:
SCHEDULE OF INDIVIDUAL QUALIFICATIONS OF RESERVES ESTIMATION
|
|
|
|
|
|
|
|
Total |
|
|
|
|
Reserve |
|
University |
|
|
|
|
|
professional |
|
|
Field
of professional experience (years) |
|
Estimation
Team* |
|
|
degree
major |
|
|
|
Degree
level |
|
|
|
experience
(years) |
|
|
|
Drilling
&
Production |
|
|
|
Petroleum
Engineering |
|
|
|
Production
Geology |
|
|
|
Reserve
Estimation |
|
Charlie
Wu |
|
|
Geosciences |
|
|
|
Ph.D. |
|
|
|
43 |
|
|
|
12 |
|
|
|
- |
|
|
|
33 |
|
|
|
22 |
|
Djoko
Martianto |
|
|
Petroleum
Engineering |
|
|
|
B.S. |
|
|
|
42 |
|
|
|
31 |
|
|
|
12 |
|
|
|
- |
|
|
|
10 |
|
Denny
Radjawane |
|
|
Geophysics |
|
|
|
M.S. |
|
|
|
30 |
|
|
|
12 |
|
|
|
- |
|
|
|
20 |
|
|
|
12 |
|
Fransiska
Sitinjak |
|
|
Petroleum
Engineering |
|
|
|
M.S. |
|
|
|
17 |
|
|
|
7 |
|
|
|
12 |
|
|
|
- |
|
|
|
8 |
|
Yudhi
Setiawan |
|
|
Geology |
|
|
|
B.S. |
|
|
|
18 |
|
|
|
12 |
|
|
|
4 |
|
|
|
6 |
|
|
|
3 |
|
Oni
Syahrial |
|
|
Geology |
|
|
|
B.S. |
|
|
|
14 |
|
|
|
- |
|
|
|
- |
|
|
|
14 |
|
|
|
8 |
|
Juan
Chandra |
|
|
Geology |
|
|
|
B.S. |
|
|
|
15 |
|
|
|
- |
|
|
|
- |
|
|
|
15 |
|
|
|
9 |
|
* | | The individuals from the
reserves estimation team are member of at least one of the following professional associations: American Association of Petroleum
Geologists (AAPG), Indonesian Association of Geophysicist (HAGI), Indonesian Association of Geologists (IAGI), Society of Petroleum
Engineers (SPE), Society of Indonesian Petroleum Engineers (IATMI) and Indonesian Petroleum Association (IPA). |
In
a “cost recovery” system, such as the TAC or KSO, in which Kruh Block operates or will operate, the production share
and net reserves entitlement to the Company reduces in periods of higher oil price and increases in periods of lower oil price.
This means that the estimated net proved reserves quantities are subject to oil price related volatility due to the method in
which the revenue is derived throughout the contract period. Therefore, the net proved reserves are estimated based on the revenue
generated by the Company according to the TAC and KSO economic models.
As
of December 31, 2020 and 2019, the Company estimates that it will be entitled to approximately 43.57% and 42.72% of the revenues
from the sales of the crude oil produced throughout the operatorship in Kruh Block. The estimates are based on the extension of
the Kruh Block operatorship to May 2030 and the cost recovery balance reset to nil in May 2020.
Following
the confirmation of the Kruh Block extension, the Company approved a development plan for a drilling program of 18 Proved Undeveloped
Reserves (or PUD) wells, according to the schedule below:
SCHEDULE OF PROVED UNDEVELOPED RESERVES WELLS
| |
UnitYear | |
2021 | | |
2022 | | |
2023 | | |
Total | |
Planned PUD wells | |
Gross well | |
| 5 | | |
| 6 | | |
| 7 | | |
| 18 | |
Future wells costs
(1) | |
US$ | |
| 3,824,061 | | |
| 9,000,000 | | |
| 10,500,000 | | |
| 23,324,061 | |
Total gross PUD added | |
Bbls | |
| 1,299,469 | | |
| 1,219,638 | | |
| 1,551,413 | | |
| 4,070,520 | |
Total net PUD added | |
Bbls | |
| 794,392 | | |
| 745,589 | | |
| 948,410 | | |
| 2,488,391 | |
(1) |
Future
wells costs are the capital expenditures associated with the new wells costs and do not include other capital expenditures
such as production facilities. |
For
Proved Developed (“PDP”) reserves, as a result of a more effective reservoir management, the Company produced a total
of 322,887 bbls for the year ended December 31, 2020, a decrease of 231,898bbls compared to previous year estimates of 2020 production.
Such recovery also brings reduction of PDP reserves forecast of 10,879 bbls as the revision of previous estimates for future production
as of December 31, 2020. However, the net PDP was increase of 21,938 bbls due to the loss of net share (43.57%) from the non-shareable
oil (NSO) of 234,116 bbls in the new KSO contract despite the upward revision of net ratio increase (from 42.72% to 43.57%) of
beginning total gross PDP and upward revision of PDP reserves estimate in 2020. As a result of rescheduling of development plan,
the gross PUD estimate is revised downward by168,461bbls and net PUD estimate is revised downward by 642,170 bbls. No amounts
have been incurred during the year ended December 31, 2020 to convert PUD reserves to PDP reserves. Beginning on May 22, 2020,
when the Kruh Block operatorship is renewed under the KSO contract, the Company will begin the drilling program to convert PUD
reserves to PDP reserves.
The
fiscal 2020 and 2019 proved developed and undeveloped reserves are summarized in the tables below:
SCHEDULE OF PROVED DEVELOPED AND UNDEVELOPED RESERVES
| |
Crude
Oil (Bbls) as of December 31, | |
| |
2020 | | |
Note | | |
2019 | | |
Note | |
Total Proved Developed (PDP) and
Undeveloped Reserves (PUD) | |
| | | |
| | | |
| | | |
| | |
Beginning of the period | |
| 4,619,992 | | |
| | | |
| 4,997,305 | | |
| | |
Revisions of
previous estimates | |
| (226,585 | ) | |
| (a) | | |
| (290,165 | ) | |
| (k) | |
Improved recovery | |
| (11,006 | ) | |
| (b) | | |
| 3,841 | | |
| | |
Purchase of minerals
in place | |
| - | | |
| | | |
| - | | |
| | |
Extensions and
discoveries | |
| - | | |
| | | |
| - | | |
| | |
Production | |
| (72,524 | ) | |
| (c) | | |
| (90,989 | ) | |
| (l) | |
Sale
of minerals in place | |
| - | | |
| | | |
| - | | |
| | |
End of the
period | |
| 4,309,877 | | |
| | | |
| 4,619,992 | | |
| | |
Net Proved Developed Reserves (PDP)
and Undeveloped Reserves (PUD) | |
| | | |
| | | |
| | | |
| | |
Beginning of the period | |
| 1,965,577 | | |
| | | |
| 2,134,685 | | |
| | |
Revisions of
previous estimates | |
| 618,421 | | |
| (d) | | |
| (131,134 | ) | |
| (m) | |
Improved recovery | |
| (6,728 | ) | |
| (e) | | |
| 1,673 | | |
| | |
Purchase of minerals
in place | |
| - | | |
| | | |
| - | | |
| | |
Extensions and
discoveries | |
| - | | |
| | | |
| - | | |
| | |
Production | |
| (44,335 | ) | |
| (f) | | |
| (39,647 | ) | |
| (n) | |
Sale
of minerals in place | |
| - | | |
| | | |
| - | | |
| | |
End of the
period | |
| 2,532,934 | | |
| | | |
| 1,965,577 | | |
| | |
Total Proved developed reserves (PDP) | |
| | | |
| | | |
| | | |
| | |
Beginning of the period | |
| 387,154 | | |
| | | |
| 398,708 | | |
| | |
Revisions of
previous estimates | |
| (64,267 | ) | |
| (g) | | |
| 75,594 | | |
| (k) | |
Improved recovery | |
| (11,006 | ) | |
| (b) | | |
| 3,841 | | |
| | |
Purchase of minerals
in place | |
| - | | |
| | | |
| - | | |
| | |
Extensions and
discoveries | |
| - | | |
| | | |
| - | | |
| | |
Production | |
| (75,524 | ) | |
| (c) | | |
| (90,989 | ) | |
| (l) | |
Sale
of minerals in place | |
| - | | |
| | | |
| - | | |
| | |
End of the
period | |
| 239,357 | | |
| | | |
| 387,154 | | |
| | |
Total Proved undeveloped reserves
(PUD) | |
| | | |
| | | |
| | | |
| | |
Beginning of the period | |
| 4,232,838 | | |
| | | |
| 4,598,597 | | |
| | |
Revisions of
previous estimates | |
| (162,318 | ) | |
| (h) | | |
| (365,759 | ) | |
| (k) | |
Improved recovery | |
| - | | |
| | | |
| - | | |
| | |
Purchase of minerals
in place | |
| - | | |
| | | |
| - | | |
| | |
Extensions and
discoveries | |
| - | | |
| | | |
| - | | |
| | |
Production | |
| - | | |
| | | |
| - | | |
| | |
Sale
of minerals in place | |
| - | | |
| | | |
| - | | |
| | |
End of the
period | |
| 4,070,521 | | |
| | | |
| 4,232,838 | | |
| | |
Net Proved developed
reserves (PDP) | |
| | | |
| | | |
| | | |
| | |
Beginning of the period | |
| 121,182 | | |
| | | |
| 170,315 | | |
| | |
Revisions of
previous estimates | |
| (25,576 | ) | |
| (i) | | |
| (11,159 | ) | |
| (m) | |
Improved recovery | |
| (6,728 | ) | |
| (e) | | |
| 1,673 | | |
| | |
Purchase of minerals
in place | |
| - | | |
| | | |
| - | | |
| | |
Extensions and
discoveries | |
| - | | |
| | | |
| - | | |
| | |
Production | |
| (44,335 | ) | |
| (f) | | |
| (39,647 | ) | |
| (n) | |
Sale
of minerals in place | |
| - | | |
| | | |
| - | | |
| | |
End of the
period | |
| 44,542 | | |
| | | |
| 121,182 | | |
| | |
Net Proved undeveloped
reserves (PUD) | |
| | | |
| | | |
| | | |
| | |
Beginning of the period | |
| 1,844,395 | | |
| | | |
| 1,964,370 | | |
| | |
Revisions of
previous estimates | |
| 643,997 | | |
| (j) | | |
| (119,975 | ) | |
| (m) | |
Improved recovery | |
| - | | |
| | | |
| - | | |
| | |
Purchase of minerals
in place | |
| - | | |
| | | |
| - | | |
| | |
Extensions and
discoveries | |
| - | | |
| | | |
| - | | |
| | |
Production | |
| - | | |
| | | |
| - | | |
| | |
Sale
of minerals in place | |
| - | | |
| | | |
| - | | |
| | |
End of the
period | |
| 2,488,392 | | |
| | | |
| 1,844,395 | | |
| | |
(a) |
The
revision of previous estimates in the amount of negative 226,585 bbls refers to the sum of 1) revision of previous PDP reserves
estimates of negative 64,267 bbls (g) and 2) revision of previous PUD reserves estimates of negative 162,318 bbls (h); |
|
|
(b) |
The
improved recovery amount of negative 11,006 bbls refers to the additional crude oil production compared to previous estimates
for Kruh block as a result of an improvement in reservoir management; |
|
|
(c) |
The
production of negative 72,524 bbls refers to the amount of total gross crude oil produced from Kruh block in 2020; |
|
|
(d) |
The
revision of previous estimates in the amount of 618,421 bbls refers to the total amount of 1) net PDP reserves revision of
previous estimates in the amount of negative 25,576 bbls (i) and 2) net PUD reserves revision of previous estimates in the
amount of 643,997 bbls (j); |
|
|
(e) |
The
improved recovery in the amount of negative 6,728 bbls refers to the net share (61.13%) of crude oil production increase from
the Kruh block compared to previous estimates as a result of effective reservoir management; |
|
|
(f) |
The
production of negative 44,335 bbls is the amount of net share (61.13%) of the total crude oil production in the amount of
negative 72,524 bbls in 2020 (c); |
|
|
(g) |
The
revision of previous estimates in the amount of negative 64,267 bbls refers to the total gross amount of PDP reserves increase
as a result of improved reservoir management which has increased oil production in 2020; |
(h) |
The
revision of previous estimates in the amount of negative 162,318 bbls refers to the amount of PUD reserves decrease from 2019
to 2020 due to the revision of the drilling schedule; |
|
|
(i) |
The
revision of previous estimates of net PDP reserves in the amount of negative 25,576 bbls refers to the sum of 1) net share
difference (61.13% in 2020 as compared with 43.57% in 2019) of the beginning total PDP reserves in the amount of 387,154 bbls,
2) net share (61.13%) of revision of previous estimates of total PDP reserves estimates in the amount of negative 64,267 bbls
(g), and 3) net share (61.13%) of the transfer of Non-shareable oil (NSO) to Pertamina in the amount of 88,771 bbls according
to the KSO contract; |
(j) |
The
revision of previous estimates of net PUD reserves in the amount of 643,997 bbls refers to the sum of 1) net share difference
(61.13% in 2020 as compared with 43.57% in 2019) of the beginning total PUD reserves in the amount of 4,232,838 bbls and 2)
net share (61.13%) of revision of previous PUD reserves estimates in the amount of negative 162,318 bbls; |
(k) |
The
revision of previous estimates in the amount of negative 290,165 bbls refers to the sum
of 1) revision of previous PDP reserves estimates of 75,594 bbls and 2) revision
of previous PUD reserves estimates of negative 365,759 bbls; |
(l) |
The
amount of negative 90,989 bbls is the total gross amount of crude oil produced from the Kruh Block in 2019; |
|
|
(m) |
The
revision of previous estimates in the amount of negative 131,134 bbls refers to the total
amount of 1) net PDP reserves revision of previous estimates in the amount of negative
11,159 bbls and 2) net PUD reserves revision of previous estimates in the amount
of negative 119,975 bbls; |
(n) |
The
amount of negative 39,647 bbls is the total net amount of crude oil produced from the Kruh Block in 2019 that the Company
is entitled to, calculated as approximately 43.57% of the total gross amount of crude oil produced (m); |
Standardized
Measure of Discounted Future Net Cash Flows Relating to Proved Oil and Gas Reserves
The
following information is based on the Company’s best estimate of the required data for the Standardized Measure of Discounted
Future Net Cash Flows as of December 31, 2020 and 2019, respectively, in accordance with SFAS No. 69, “Disclosures About
Oil and Gas Producing Activities” which requires the use of a 10% discount rate. This information is not the fair market
value, nor does it represent the expected present value of future cash flows of the Company’s proved oil and gas reserves.
SCHEDULE OF STANDARDIZED MEASURE OF DISCOUNTED FUTURE NET CASH FLOWS RELATING TO PROVED OIL AND GAS RESERVES
| |
| | | |
| | |
| |
As
of December 31, | |
| |
2020 | | |
2019 | |
Future cash inflows | |
$ | 100,920,387 | | |
$ | 121,755,908 | |
Future production
costs (1) | |
| (43,360,461 | ) | |
| (46,394,506 | ) |
Future development costs | |
| (41,056,457 | ) | |
| (41,867,500 | ) |
Future income
tax expenses | |
| (5,571,112 | ) | |
| (15,593,639 | ) |
Future net cash flows | |
$ | 10,932,358 | | |
$ | 17,900,262 | |
10% annual
discount for estimated timing of cash flows | |
| (5,352,516 | ) | |
| (7,736,291 | ) |
Standardized
measure of discounted future net cash flows at the end of the year | |
$ | 5,579,842 | | |
$ | 10,163,971 | |
(1) |
Production
costs include oil and gas operations expense, production ad valorem taxes, transportation costs and general and administrative
expense supporting the Company’s oil and gas operations. |
Future
cash inflows are computed by applying the ICP previous 12 months average monthly price, to year-end quantities of proved reserves.
ICP is determined by the Directorate General of Oil and Gas (“DGOG”) of The Ministry of Energy and Mineral Resources
of Indonesia (“MEMR”) on a monthly basis and presented as the monthly price of the crude oil according to the region
where the oil is produced. The discounted future cash flow estimates do not include the effects of the Company’s derivative
instruments, if any. See the following table for average prices.
SCHEDULE OF AVERAGE PRICES
| |
Years
ended December 31, | |
| |
2020 | | |
2019 | | |
2018 | |
Average
crude oil price per Bbl | |
$ | 37.58 | | |
$ | 61.89 | | |
$ | 66.12 | |
Future
production and development costs, which include abandonment and site restoration expense, are computed by estimating the expenditures
to be incurred in developing and producing the Company’s proved crude oil reserves at the end of the year, based on year-end
costs, and assuming continuation of existing economic conditions.
Sources
of Changes in Discounted Future Net Cash Flows
Principal
changes in the aggregate standardized measure of discounted future net cash flows attributable to the Company’s proved crude
oil and natural gas reserves at year end are set forth in the table below.
SCHEDULE OF SOURCES OF CHANGES IN DISCOUNTED FUTURE NET CASH FLOWS
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Year
ended December 31, |
|
|
|
2020 |
|
|
2019 |
|
|
2018 |
|
Standardized
measure of discounted future net cash flows at the beginning of the year |
|
$ |
10,120,562 |
|
|
$ |
14,513,446 |
|
|
$ |
4,222,805 |
|
Extensions,
discoveries and improved recovery, less related costs |
|
|
500,000 |
|
|
|
500,000 |
|
|
|
(7,000,000 |
) |
Revisions
of previous quantity estimates |
|
|
6,073,161 |
|
|
|
(3,431,073 |
) |
|
|
85,790,320 |
|
Changes
in estimated future development costs |
|
|
811,043 |
|
|
|
752,299 |
|
|
|
(42,865,000 |
) |
Purchases
(sales) of minerals in place |
|
|
- |
|
|
|
- |
|
|
|
- |
|
Net
changes in prices and production costs |
|
|
(21,967,808 |
) |
|
|
(4,090,493 |
) |
|
|
3,655,533 |
) |
Accretion
of discount |
|
|
2,377,063 |
|
|
|
1,384,269 |
|
|
|
(8,462,229 |
|
Sales
of oil and gas produced, net of production costs |
|
|
(2,536,006 |
)) |
|
|
(2,166,491 |
) |
|
|
(2,946,923 |
) |
Development
costs incurred during the period |
|
|
201,946 |
|
|
|
245,202 |
|
|
|
103,337 |
|
Change
in timing of estimated future production and other |
|
|
- |
|
|
|
- |
|
|
|
- |
|
Net
change in income taxes |
|
|
9,999,882 |
|
|
|
2,413,403 |
|
|
|
(17,984,397 |
) |
Standardized
measure of discounted future net cash flows at the end of the year |
|
$ |
5,579,842 |
|
|
$ |
10,120,562 |
|
|
$ |
14,513,446 |
|
Up
to 9,100,574
Ordinary
Shares
PROSPECTUS
,
2022
PART
II
INFORMATION
NOT REQUIRED IN PROSPECTUS
ITEM
6. Indemnification of Directors and Officers
We
are a Cayman Islands exempted company limited by shares. Cayman Islands law does not limit the extent to which a company’s articles
of association may provide for indemnification of officers and directors, except to the extent any such provision may be held by the
Cayman Islands courts to be contrary to public policy, such as to provide indemnification against civil fraud or the consequences of
committing a crime. Our amended articles of association provide, to the extent permitted by law, for the indemnification of each existing
or former director (including alternate director), secretary and any of our other officers (including an investment adviser or an administrator
or liquidator) and their personal representatives against:
(a)
all actions, proceedings, costs, charges, expenses, losses, damages or liabilities incurred or sustained by the existing or former director
(including alternate director), secretary or officer in or about the conduct of our business or affairs or in the execution or discharge
of the existing or former director’s (including alternate director’s), secretary’s or officer’s duties, powers,
authorities or discretions; and
(b)
without limitation to paragraph (a) above, all costs, expenses, losses or liabilities incurred by the existing or former director (including
alternate director), secretary or officer in defending (whether successfully or otherwise) any civil, criminal, administrative or investigative
proceedings (whether threatened, pending or completed) concerning us or our affairs in any court or tribunal, whether in the Cayman Islands
or elsewhere.
No
such existing or former director (including alternate director), secretary or officer, however, shall be indemnified in respect of any
matter arising out of his own dishonesty.
To
the extent permitted by law, we may make a payment, or agree to make a payment, whether by way of advance, loan or otherwise, for any
legal costs incurred by an existing or former director (including alternate director), secretary or any of our officers in respect of
any matter identified in above on condition that the director (including alternate director), secretary or officer must repay the amount
paid by us to the extent that it is ultimately found not liable to indemnify the director (including alternate director), secretary or
that officer for those legal costs.
Insofar
as indemnification for liabilities arising under the Securities Act may be permitted to directors, officers or persons controlling us
pursuant to the foregoing provisions, we have been informed that in the opinion of the Securities and Exchange Commission such indemnification
is against public policy as expressed in the Securities Act and is therefore unenforceable.
ITEM
7. Recent Sales of Unregistered Securities
During
the past three years, we issued and sold the securities described below without registering the securities under the Securities Act.
None of these transactions involved any underwriters’ underwriting discounts or commissions, or any public offering. We believe
that each of the following issuances to private placement investors was exempt from registration under the Securities Act in reliance
on Regulation S under the Securities Act or pursuant to Section 4(a)(2) of the Securities Act regarding transactions not involving a
public offering. We believe that our issuances of incentive shares and options to our employees, directors, officers and consultants
were exempt from registration under the Securities Act in reliance on Rule 701 under the Securities Act.
We
were incorporated on April 24, 2018 as an exempted company with limited liability under the laws of the Cayman Islands and are a holding
company for WJ Energy Group Limited (or WJ Energy), which in turn owns our Indonesian holding and operating subsidiaries. We presently
have two shareholders: MADERIC Holding Limited (or Maderic) and HFO Investment Group (or HFO).
On
June 30, 2018, we entered into two agreements with Maderic and HFO (the two then shareholders of WJ Energy): a Sale and Purchase of Shares
and Receivables Agreement and a Debt Conversion Agreement (which we refer to collectively as the Restructuring Agreements). The intention
of the Restructuring Agreements was to restructure our capitalization in anticipation of our initial public offering which was concluded
in December 2019. As a result of the transactions contemplated by the Restructuring Agreements: (i) WJ Energy (including its assets and
liabilities) became a wholly-owned subsidiary of our company, (ii) loans amounting to $21,150,000 and $3,150,000 that were owed by WJ
Energy to Maderic and HFO, respectively, were converted for nominal value into ordinary shares of our company and (iii) we issued an
aggregate of 15,999,000 ordinary shares to Maderic and HFO.
As
of the date of this prospectus, Maderic owns 68.29% of our issued and outstanding shares, while HFO owns approximately 8.47%
of our issued and outstanding shares. As of the date of this prospectus, we have 7,647,214 ordinary shares issued and outstanding.
On
January 23, 2020, pursuant to the terms of his employment agreement with us, we granted Frank Ingriselli 35,000 ordinary shares as an
equity incentive award which vested as follows: 18,750 vested on December 19, 2019, 9,375 vested on June 16, 2020, and 9,375 vested on
December 19, 2020.
On
February 25, 2021, we issued 5,000 ordinary shares to a consultant in consideration of consulting services.
On
January 23, 2022, pursuant to the terms of his employment agreement with us, we granted Frank Ingriselli 60,000 ordinary shares as an
equity incentive award which vested as follows: 30,000 shares vest on July 1, 2022 and 30,000 vest on January 1, 2023.
On
January 21, 2022, we entered into a convertible note and warrant financing transaction with L1 Capital (subsequently amended on
March 4, 2022) as described in the accompanying prospectus.
ITEM
8. Exhibits and Financial Statement Schedules
(a)
Exhibits
The
following exhibits are filed as part of this registration statement:
|
|
|
|
Incorporated
Herein by Reference |
|
|
Exhibit
Number |
|
Exhibit
Title |
|
Form |
|
File
No. |
|
Exhibit |
|
Filing
Date |
|
Filed
Herewith |
3.1 |
|
Amended and Restated Memorandum of Association of the Registrant |
|
F-1 |
|
333-232894 |
|
3.1 |
|
November
12, 2019 |
|
|
3.2 |
|
Amended and Restated Articles of Association of the Registrant |
|
F-1 |
|
333-232894 |
|
3.2 |
|
November
12, 2019 |
|
|
5.1 |
|
Opinion of Ogier regarding the validity of the ordinary shares being registered |
|
|
|
|
|
|
|
|
|
X |
10.1 |
|
Sale and Purchase of Shares and Receivables Agreement, dated June 30, 2018, by and between the Registrant, Maderic Holding Limited, HFO Investment Group Limited, Opera Cove International Limited and WJ Energy Group Limited. |
|
F-1 |
|
333-232894 |
|
10.1 |
|
July
30, 2019 |
|
|
10.2 |
|
Debt Conversion Agreement, dated June 30, 2018, by and between the Registrant, Maderic Holding Limited and HFO Investment Group Limited |
|
F-1 |
|
333-232894 |
|
10.2 |
|
July
30, 2019 |
|
|
10.3 |
|
Debt Acknowledgement Note, dated June 30, 2018 (Maderic Holding Limited) |
|
F-1 |
|
333-232894 |
|
10.3 |
|
July
30, 2019 |
|
|
10.4 |
|
Debt Acknowledgement Note, dated June 30, 2018 (HFO Investment Group) |
|
F-1 |
|
333-232894 |
|
10.4 |
|
July
30, 2019 |
|
|
10.5 |
|
Contract regarding acquisition of Citarum Block and/or the 2016 joint study regarding the Citarum Block (Joint Study Agreement) |
|
F-1 |
|
333-232894 |
|
10.5 |
|
November
12, 2019 |
|
|
10.6 |
|
Technical Assistance Contract with PT Pertamina in regards to the Kruh Block |
|
F-1 |
|
333-232894 |
|
10.6 |
|
July
30, 2019 |
|
|
10.7 |
|
Letter extending Kruh contract |
|
F-1 |
|
333-232894 |
|
10.7 |
|
August
21, 2019 |
|
|
10.8 |
|
Employment
Agreement, dated February 1, 2019, between the Registrant and Dr. Wirawan Jusuf+ |
|
F-1 |
|
333-232894 |
|
10.8 |
|
July
30, 2019 |
|
|
10.9 |
|
Share
Option Agreement, dated February 1, 2019, between the Registrant and Dr. Wirawan Jusuf+ |
|
F-1 |
|
333-232894 |
|
10.9 |
|
July
30, 2019 |
|
|
10.10 |
|
Employment
Agreement, dated February 1, 2019, between the Registrant and Frank C. Ingriselli+ |
|
F-1 |
|
333-232894 |
|
10.10 |
|
July
30, 2019 |
|
|
10.11 |
|
Share
Option Agreement, dated February 1, 2019, between the Registrant and Frank C. Ingriselli+ |
|
F-1 |
|
333-232894 |
|
10.11 |
|
July
30, 2019 |
|
|
10.12 |
|
First
Amendment to Employment Agreement, dated January 23. 2020, between the Company and Frank Ingriselli+ |
|
6-K |
|
001-39164 |
|
10.1 |
|
January
29, 2020 |
|
|
10.13 |
|
Employment
Agreement, dated February 1, 2019, between the Registrant and Chia Hsin “Charlie” Wu+ |
|
F-1 |
|
333-232894 |
|
10.12 |
|
July
30, 2019 |
|
|
10.14 |
|
Share
Option Agreement, dated February 1, 2019, between the Registrant and Chia Hsin “Charlie” Wu+ |
|
F-1 |
|
333-232894 |
|
10.13 |
|
July
30, 2019 |
|
|
10.15 |
|
Employment
Agreement, dated February 1, 2019, between the Registrant and Mirza F. Said+ |
|
F-1 |
|
333-232894 |
|
10.14 |
|
July
30, 2019 |
|
|
10.16 |
|
Share
Option Agreement, dated February 1, 2019, between the Registrant and Mirza F. Said+ |
|
F-1 |
|
333-232894 |
|
10.15 |
|
July
30, 2019 |
|
|
10.17 |
|
Employment
Agreement, dated February 1, 2019, between the Registrant and James J. Huang+ |
|
F-1 |
|
333-232894 |
|
10.16 |
|
July
30, 2019 |
|
|
10.18 |
|
Share
Option Agreement, dated February 1, 2019, between the Registrant and James J. Huang+ |
|
F-1 |
|
333-232894 |
|
10.17 |
|
July
30, 2019 |
|
|
10.19 |
|
Employment
Agreement, dated February 1, 2019, between the Registrant and Gregory L. Overholtzer+ |
|
F-1 |
|
333-232894 |
|
10.18 |
|
July
30, 2019 |
|
|
10.20 |
|
First
Amendment to Employment Agreement, dated January 29. 2020, between the Company and Gregory Overholtzer+ |
|
6-K |
|
001-39164 |
|
10.2 |
|
January
29, 2020 |
|
|
10.21 |
|
Indonesian
Energy Corporation Limited 2018 Equity Incentive Plan+ |
|
F-1 |
|
333-232894 |
|
10.19 |
|
July
30, 2019 |
|
|
10.22 |
|
Securities Purchase Agreement, dated January 21, 2022, between the Company and the Selling Shareholder |
|
6-K |
|
001-39164 |
|
10.1 |
|
January
25, 2022 |
|
|
10.23 |
|
Senior Convertible Promissory Note issued to the Selling Shareholder, dated January 21, 2022 |
|
6-K |
|
001-39164 |
|
10.2 |
|
January
25, 2022 |
|
|
10.24 |
|
Form of Ordinary Share Purchase Warrant issued to the Selling Shareholder |
|
6-K |
|
001-39164 |
|
10.3 |
|
January
25, 2022 |
|
|
10.25 |
|
Guaranty, dated January 21, 2022, by WJ Energy Group Limited favor of the Selling Shareholder |
|
6-K |
|
001-39164 |
|
10.4 |
|
January
25, 2022 |
|
|
10.26 |
|
Second
Amendment to Employment Agreement, dated January 21, 2022, between the Company and Frank Ingriselli+ |
|
6-K |
|
001-39164 |
|
10.5 |
|
January
25, 2022 |
|
|
10.27 |
|
Second
Amendment to Employment Agreement, dated January 21, 2022, between the Company and Gregory Overholtzer+ |
|
6-K |
|
001-39164 |
|
10.6 |
|
January
25, 2022 |
|
|
10.28 |
|
First Amendment to Securities Purchase Agreement, dated March 4, 2022, between the Company and the Selling Shareholder |
|
6-K |
|
001-39164 |
|
10.1 |
|
March 9, 2022 |
|
|
10.29 |
|
Amended and Restated Senior Convertible Promissory Note issued to the Selling Shareholder, dated March 4, 2022 |
|
6-K |
|
001-39164 |
|
10.2 |
|
March 9, 2022 |
|
|
21.1 |
|
Subsidiaries of the registrant |
|
F-1 |
|
333-232894 |
|
21.1 |
|
July
30, 2019 |
|
|
23.1 |
|
Consent of Marcum Bernstein & Pinchuk LLP |
|
|
|
|
|
|
|
|
|
X |
23.2 |
|
Consent of Ogier (included in Exhibit 5.1) |
|
|
|
|
|
|
|
|
|
X |
101 |
|
Interactive
Data File (XBRL)# |
|
|
|
|
|
|
|
|
|
X |
107 |
|
Filing Fee Table |
|
|
|
|
|
|
|
|
|
X |
+ |
Management
contract or compensatory plan or arrangement. |
# |
Pursuant
to Rule 406T of Regulation S-T, these interactive data files are deemed not filed or part of a registration statement or prospectus
for purposes of Sections 11 or 12 of the Securities Act of 1933, as amended, are deemed not filed for the purposes of Section 18
of the Securities and Exchange Act of 1934, as amended, and otherwise are not subject to liability under those sections. |
ITEM
9. Undertakings
The
undersigned registrant hereby undertakes that:
|
(1) |
Insofar
as indemnification for liabilities arising under the Securities Act may be permitted to directors, officers and controlling persons
of the registrant pursuant to the provisions described in Item 6, or otherwise, the registrant has been advised that in the opinion
of the Securities and Exchange Commission such indemnification is against public policy as expressed in the Securities Act and is
therefore unenforceable. In the event that a claim for indemnification against such liabilities (other than the payment by the registrant
of expenses incurred or paid by a director, officer or controlling person of the registrant in the successful defense of any action,
suit or proceeding) is asserted by such director, officer or controlling person in connection with the securities being registered,
the registrant will, unless in the opinion of its counsel the matter has been settled by controlling precedent, submit to a court
of appropriate jurisdiction the question whether such indemnification by it is against public policy as expressed in the Securities
Act and will be governed by the final adjudication of such issue. |
|
(2) |
For
purposes of determining any liability under the Securities Act of 1933, the information omitted from the form of prospectus filed
as part of this registration statement in reliance upon Rule 430A and contained in a form of prospectus filed by the registrant pursuant
to Rule 424(b) (1) or (4) or 497(h) under the Securities Act shall be deemed to be part of this registration statement as of the
time it was declared effective. |
|
(3) |
For
the purpose of determining any liability under the Securities Act of 1933, each post-effective amendment that contains a form of
prospectus shall be deemed to be a new registration statement relating to the securities offered therein, and the offering of such
securities at that time shall be deemed to be the initial bona fide offering thereof. |
|
(4) |
For
the purpose of determining liability under the Securities Act to any purchaser, each prospectus filed pursuant to Rule 424(b) as
part of a registration statement relating to an offering, other than registration statements relying on Rule 430B or other than prospectuses
filed in reliance on Rule 430A, shall be deemed to be part of and included in the registration statement as of the date it is first
used after effectiveness. Provided, however, that no statement made in a registration statement or prospectus that is part of the
registration statement or made in a document incorporated or deemed incorporated by reference into the registration statement or
prospectus that is part of the registration statement will, as to a purchaser with a time of contract of sale prior to such first
use, supersede or modify any statement that was made in the registration statement or prospectus that was part of the registration
statement or made in any such document immediately prior to such date of first use. |
|
(5) |
For
the purpose of determining any liability of the registrant under the Securities Act to any purchaser in the initial distribution
of the securities, the undersigned registrant undertakes that in an offering of securities of the undersigned registrant pursuant
to this registration statement, regardless of the underwriting method used to sell the securities to the purchaser, if the securities
are offered or sold to such purchaser by means of any of the following communications, the undersigned registrant will be a seller
to the purchaser and will be considered to offer or sell such securities to such purchaser: |
|
(i) |
Any
preliminary prospectus or prospectus of the undersigned registrant relating to the offering required to be filed pursuant to Rule
424; |
|
(ii) |
Any
free writing prospectus relating to the offering prepared by or on behalf of the undersigned registrant or used or referred to by
the undersigned registrant; |
|
(iii) |
The
portion of any other free writing prospectus relating to the offering containing material information about the undersigned registrant
or its securities provided by or on behalf of the undersigned registrant; and |
|
(iv) |
Any
other communication that is an offer in the offering made by the undersigned registrant to the purchaser. |
SIGNATURES
Pursuant
to the requirements of the Securities Act of 1933, the registrant certifies that it has reasonable grounds to believe that it meets all
of the requirements for filing on Form F-1 and has duly caused this registration statement to be signed on its behalf by the undersigned,
thereunto duly authorized, in the city of Jakarta, Indonesia, on March 9, 2022.
|
INDONESIA
ENERGY CORPORATION LIMITED |
|
|
|
|
By: |
/s/
Wirawan Jusuf |
|
Name: |
Wirawan
Jusuf |
|
Title: |
Chief
Executive Officer |
|
|
(principal
executive officer) |
POWER
OF ATTORNEY
KNOW
ALL PERSONS BY THESE PRESENTS, that each person whose signature appears below hereby constitutes and appoints each of Wirawan Jusuf and
James Huang as his or her true and lawful attorney-in-fact and agent, with full power of substitution and re-substitution, for him or
her and in his name or her name, place and stead, in any and all capacities, in connection with this registration statement, including
to sign and file in the name and on behalf of the undersigned as director or officer of the registrant, any and all amendments or supplements
(including any and all prospectus supplements, stickers and post-effective amendments) to this registration statement with all exhibits
thereto, and sign any registration statement for the same offering covered by this registration statement that is to be effective upon
filing pursuant to Rule 462(b) under the Securities Act of 1933, as amended, and all post-effective amendments thereto and to file the
same, with all exhibits thereto, and other documents in connection therewith, with the Securities and Exchange Commission, and any applicable
securities exchange, securities self-regulatory body or other regulatory authority, granting unto said attorney-in-fact and agent full
power and authority to do and perform each and every act and thing requisite or necessary to be done in connection therewith and in and
about the premises, as fully to all intents and purposes as he or she might or could do in person, hereby ratifying and confirming that
said attorney-in-fact and agent, or his substitute or substitutes, may lawfully do or cause to be done by virtue hereof.
Pursuant
to the requirements of the Securities Act of 1933, this registration statement has been signed by the following persons on behalf of
the registrant and in the capacities and on the dates indicated.
Signature |
|
Title |
|
Date |
|
|
|
|
|
/s/
Dr. Wirawan Jusuf |
|
Director,
Chairman of the Board |
|
March
9, 2022 |
Dr.
Wirawan Jusuf |
|
and
Chief Executive Officer |
|
|
|
|
|
|
|
/s/
Mirza F. Said |
|
Chief
Business Development Officer and Director |
|
March
9, 2022 |
Mirza
F. Said |
|
|
|
|
|
|
|
|
|
/s/
James J. Huang |
|
Chief
Investment Officer and Director |
|
March
9, 2022 |
James
J. Huang |
|
|
|
|
|
|
|
|
|
/s/
Gregory L. Overholtzer |
|
Chief
Financial Officer |
|
March
9, 2022 |
Gregory
L. Overholtzer |
|
|
|
|
|
|
|
|
|
/s/
Mochtar Hussein |
|
Director |
|
March
9, 2022 |
Mochtar
Hussein |
|
|
|
|
|
|
|
|
|
/s/
Benny Dharmawan |
|
Director |
|
March
9, 2022 |
Benny
Dharmawan |
|
|
|
|
|
|
|
|
|
/s/
Tamba P. Hutapea |
|
Director |
|
March
9, 2022 |
Tamba
P. Hutapea |
|
|
|
|
|
|
|
|
|
/s/
Michael L. Peterson |
|
Director |
|
March
9, 2022 |
Michael
L. Peterson |
|
|
|
|
Indonesia Energy (AMEX:INDO)
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