Black Stone Minerals, L.P. (NYSE: BSM) ("Black Stone Minerals,"
"Black Stone," or "the Company") today announces its financial and
operating results for the second quarter of 2021.
Financial and Operational Highlights
- Mineral and royalty production for the second quarter of 2021
equaled 32.5 MBoe/d, an increase of 5% over the prior quarter;
total production, including working interest volumes, was 38.2
MBoe/d for the quarter.
- Net income and Adjusted EBITDA for the quarter totaled $15.4
million and $78.4 million, respectively.
- Distributable cash flow was $72.1 million for the second
quarter, an increase of 34% over the first quarter of 2021.
- Announced a distribution of $0.25 per unit with respect to the
second quarter of 2021, composed of a base distribution of $0.20
per unit and a special distribution of $0.05 per unit reflecting
the benefit of certain positive, one-time items during the second
quarter. Distribution coverage for all units on the base
distribution of $0.20 per unit is 1.7x and distribution coverage on
the combined base and special distribution of $0.25 per unit is
1.4x.
- Total debt at the end of the second quarter was $96.0 million;
total debt to trailing twelve-month Adjusted EBITDA was 0.4x at
quarter-end. As of July 30, 2021, total debt had been reduced to
$81 million.
- As previously disclosed, entered into agreements promoting
Haynesville and Bossier development of certain of the Company’s
acreage in San Augustine County, Texas, and Austin Chalk
development in East Texas.
- Subsequent to the end of the quarter, announced a new
sustainability initiative in which Black Stone will use proceeds
from surface use waivers on its mineral acreage supporting solar
development to purchase carbon credits in an effort to offset part
of the CO2 emissions associated with its mineral production.
Management Commentary
Thomas L. Carter, Jr., Black Stone Minerals’ Chief Executive
Officer and Chairman commented, “We posted robust operational and
financial performance for the second quarter, with increases in
production and realized prices. In addition to better fundamentals,
our results for the quarter were bolstered by strong lease bonus
payments and higher gas price realizations stemming from the
February Texas storms. Most importantly, the positive results
combined with our low debt levels allowed us to prioritize
returning cash flow to our unitholders in the form of increased
distributions. We look forward to building on this positive
momentum into 2022.”
Quarterly Financial and Operating Results
Production
Black Stone Minerals reported mineral and royalty volume was
32.5 MBoe/d (73% natural gas) for the second quarter of 2021,
compared to 31.1 MBoe/d for the first quarter of 2021. Mineral and
royalty production for the second quarter of 2020 was 34.0
MBoe/d.
Working interest production for the second quarter of 2021 was
5.7 MBoe/d, and represents a decrease of 1% from the levels
generated in the quarter ended March 31, 2021 and a decrease of 34%
from the quarter ended June 30, 2020. The continued decline in
working interest volumes is consistent with the Company's decision
to farm out its working-interest participation to third-party
capital providers.
Total reported production averaged 38.2 MBoe/d (85% mineral and
royalty, 75% natural gas) for the second quarter of 2021. Total
production was 36.8 MBoe/d and 42.6 MBoe/d for the quarters ended
March 31, 2021 and June 30, 2020, respectively.
Realized Prices, Revenues, and Net Income
The Company’s average realized price per Boe, excluding the
effect of derivative settlements, was $31.79 for the quarter ended
June 30, 2021. This is an increase of 21% from $26.27 per Boe from
the first quarter of 2021 and a 121% increase compared to $14.37
for the second quarter of 2020. Contributing to this increase was
approximately $5.6 million in additional natural gas revenue
recognized in the second quarter of 2021 due to realized price
differentials during February of 2021 exceeding original Company
projections.
Black Stone reported oil and gas revenue of $110.4 million (49%
oil and condensate) for the second quarter of 2021, an increase of
27% from $87.1 million in the first quarter of 2021. Oil and gas
revenue in the second quarter of 2020 was $55.7 million.
The Company reported a loss on commodity derivative instruments
of $59.5 million for the second quarter of 2021, composed of a
$17.4 million loss from realized settlements and a non-cash $42.1
million unrealized loss due to the change in value of Black Stone’s
derivative positions during the quarter. Black Stone reported
losses of $27.9 million and $19.2 million on commodity derivative
instruments for the quarters ended March 31, 2021 and June 30,
2020, respectively.
Lease bonus and other income was $7.5 million for the second
quarter of 2021, primarily related to leasing activity in the
Austin Chalk and proceeds from surface use waivers on Black Stone’s
mineral acreage supporting solar development. Lease bonus and other
income for the quarters ended March 31, 2021 and June 30, 2020 was
$2.4 million and $2.0 million, respectively.
There was no impairment for the quarters ended June 30, 2021,
March 31, 2021, and June 30, 2020.
The Company reported net income of $15.4 million for the quarter
ended June 30, 2021, compared to net income of $16.2 million in the
preceding quarter. For the quarter ended June 30, 2020, the Company
reported a net loss of $8.4 million.
Adjusted EBITDA and Distributable Cash Flow
Adjusted EBITDA for the second quarter of 2021 was $78.4
million, which compares to $60.0 million in the first quarter of
2021 and $72.4 million in the second quarter of 2020. Distributable
cash flow for the quarter ended June 30, 2021 was $72.1 million.
For the quarters ended March 31, 2021 and June 30, 2020,
distributable cash flow was $53.8 million and $64.4 million,
respectively.
Financial Position and Activities
As of June 30, 2021, Black Stone Minerals had $1.0 million in
cash and $96.0 million outstanding under its credit facility. The
ratio of total debt at June 30, 2021 to trailing twelve-month
Adjusted EBITDA was 0.4x. As of July 30, 2021, $81 million was
outstanding under the credit facility and the Company had $6.6
million in cash.
During the second quarter, Black Stone's borrowing base was
reaffirmed at $400 million. As part of the redetermination process,
the term of the credit facility was extended until November 1,
2024. Black Stone is in compliance with all financial covenants
associated with its credit facility.
During the second quarter of 2021, the Company made no
repurchases of units under the Board-approved $75 million unit
repurchase program and issued no units under its at-the-market
offering program.
Second Quarter 2021 Distributions
As previously announced, the Board approved a cash distribution
of $0.25 for each common unit attributable to the second quarter of
2021. The quarterly distribution coverage ratio attributable to the
second quarter of 2021 was approximately 1.4x. The distribution is
composed of a base distribution of $0.20 per unit and a special
distribution of $0.05 per unit reflecting the benefit of certain
one-time items including the $5.6 million in additional natural gas
revenues discussed above and the $5.0 million of lease bonus in
excess of the Company’s original guidance of $2.5 million per
quarter. Distributions will be payable on August 20, 2021 to
unitholders of record as of the close of business on August 13,
2021.
Activity Update
Rig Activity
As of June 30, 2021, Black Stone had 64 rigs operating across
its acreage position, an increase relative to the 59 rigs on the
Company's acreage as of March 31, 2021 and the 29 rigs operating on
the Company's acreage as of June 30, 2020.
Shelby Trough Development Update
Angelina County Aethon has
successfully turned to sales the initial two program wells and has
commenced operations on four additional wells under the development
agreement covering Angelina County. Under the terms of that
agreement, Aethon must drill a minimum of four wells on Black Stone
acreage in the first program year ending in September 2021,
escalating to a minimum of 15 wells per program year starting with
the third program year.
San Augustine County In May 2021,
Black Stone and Aethon entered into an agreement to develop certain
of the Company’s undeveloped acreage in San Augustine County. The
agreement provides for minimum well commitments by Aethon in
exchange for reduced royalty rates and exclusive access to Black
Stone’s mineral and leasehold acreage in the contract area for the
Haynesville and Bossier formations. The agreement calls for a
minimum of five wells to be drilled in the initial program year,
which begins in the third quarter of 2021, increasing to a minimum
of 10 wells per year beginning with the second program year. The
Company’s development agreement with Aethon and related drilling
commitments covering its San Augustine County acreage is
independent of the development agreement and associated commitments
covering Angelina County.
In May 2021, the Company entered into a new farmout agreement
(the “Second Canaan Farmout”) with Canaan Resource Partners
("Canaan"). The Second Canaan Farmout supersedes and replaces the
original farmout agreement with Canaan with respect to the area in
San Augustine County covered by the Aethon development agreement.
The Second Canaan Farmout covers part of the Company’s share of
working interests under active development by Aethon in San
Augustine County, Texas and continues until May 2031, unless
earlier terminated in accordance to the terms of the agreement.
Canaan will earn 80% of the Company’s working interest in the
partitioned acreage from XTO (up to a maximum of 40% on an 8/8ths
basis) and 50% of the Company’s working interest in other areas (up
to a maximum of 12.5% on an 8/8ths basis) in wells drilled and
operated by Aethon in accordance with the development agreement.
Canaan is obligated to fund the development of all wells drilled by
Aethon in the initial program year and thereafter, Canaan has
certain rights and options to continue funding the Company’s
working interests for the duration of the Second Canaan Farmout. As
of June 30, 2021, no wells had been drilled under the Second Canaan
Farmout. The Company will receive an ORRI before payout and an
increased ORRI after payout on all wells drilled under the Second
Canaan Farmout.
Austin Chalk Update
In April 2021, Black Stone entered into an agreement with
several operators to test and develop areas of the Austin Chalk in
East Texas where the Company has significant acreage positions.
Recent drilling results have shown that advances in fracturing and
other completion techniques can dramatically improve well
performance in existing Austin Chalk fields. Under the terms of the
agreement, the operators will participate in three multi-stage
completion test wells targeting the Austin Chalk formation. Two of
the wells under the test program are currently being drilled, and
the third well has been permitted. In addition to the test program,
Black Stone has entered into a development agreement with one of
the operators and is negotiating separate agreements with each
remaining operator to further develop the acreage.
In April 2021, Black Stone also entered into an agreement with a
large, private independent operator to drill and complete multiple
Austin Chalk wells on Company acreage within East Texas. Black
Stone expects the operator to spud two wells on the acreage in
2021. If the initial wells are successful, the operator has the
option to expand the Austin Chalk development program on additional
Black Stone acreage.
Earlier in the year, Black Stone entered into an agreement with
a large, publicly traded independent operator by which the operator
will undertake a program to drill, test, and complete wells in the
Austin Chalk formation on certain of the Company’s acreage in East
Texas. The first well under this agreement is scheduled to be spud
in the third or fourth quarter of 2021. If the initial wells are
successful, the operator has the option to expand the Austin Chalk
drilling program over a significant acreage position, the majority
of which is owned and controlled by the Company.
Acquisition Update
In May 2021, Black Stone closed on the acquisition of mineral
and royalty acreage in the northern Midland Basin for total
consideration of $20.8 million. The purchase price consisted of
$10.0 million in cash and $10.8 million in Black Stone common
units.
Update to 2021 Guidance
The following table provides the assumptions for Black Stone’s
original and current 2021 guidance. Production through the first
half of 2021 exceeded the Company’s original guidance expectations.
Production is anticipated to trend lower in the second half of
2021, driven in part by declines in mature plays such as the Bakken
and Gulf Coast, and by lower natural gas volumes in the Shelby
Trough as existing production declines in advance of the expected
ramp-up in new drilling activity under the existing development
deals.
Original
Guidance
Revised
Guidance
Mineral and royalty production
(MBoe/d)
28 - 30
29 - 31
Working interest production (MBoe/d)
5.5 - 6.5
5.5 - 6.0
Total production (MBoe/d)
33.5 - 36.5
34.5 - 37.0
Percentage natural gas
~76%
~75%
Percentage royalty interest
~83%
~84%
Lease bonus and other income ($MM)
~$10
$10 - $15
Lease operating expense ($MM)
$12 - $14
$12 - $14
Production costs and ad valorem taxes (as
% of total pre-derivative O&G revenue)
13% - 15%
10% - 12%
G&A - cash ($MM)
$31 - $33
$33 - $34
G&A - non-cash ($MM)
$10 - $12
$10 - $12
G&A - TOTAL ($MM)
$41 - $45
$43 - $46
DD&A ($/Boe)
$5.00 - $6.00
$5.00 - $6.00
Update to Hedge Position
Black Stone has commodity derivative contracts in place covering
portions of its anticipated production for 2021 and 2022. The
Company's hedge position as of July 30, 2021 is summarized in the
following tables:
Oil Hedge Position
Oil Swap
Oil Swap Price
MBbl
$/Bbl
2Q21
220
$38.97
3Q21
660
$38.97
4Q21
660
$38.97
1Q22
480
$60.14
2Q22
480
$60.14
3Q22
480
$60.14
4Q22
480
$60.14
Natural Gas Hedge Position
Gas Swap
Gas Swap Price
BBtu
$/MMbtu
3Q21
10,120
$2.69
4Q21
10,120
$2.69
1Q22
7,920
$2.98
2Q22
8,000
$2.99
3Q22
8,080
$2.99
4Q22
8,080
$2.99
More detailed information about the Company's existing hedging
program can be found in the Quarterly Report on Form 10-Q for the
second quarter of 2021, which is expected to be filed on or around
August 3, 2021.
Conference Call
Black Stone Minerals will host a conference call and webcast for
investors and analysts to discuss its results for the second
quarter of 2021 on Tuesday, August 3, 2021 at 9:00 a.m. Central
Time. Black Stone recommends participants who do not anticipate
asking questions to listen to the call via the live broadcast
available at http://investor.blackstoneminerals.com. Analysts
and investors who wish to ask questions should dial (877) 447-4732
and use conference code 5597384. A recording of the conference call
will be available on Black Stone's website through September 2,
2021.
About Black Stone Minerals, L.P.
Black Stone Minerals is one of the largest owners of oil and
natural gas mineral interests in the United States. The Company
owns mineral interests and royalty interests in 41 states in the
continental United States. Black Stone believes its large,
diversified asset base and long-lived, non-cost-bearing mineral and
royalty interests provide for stable to growing production and
reserves over time, allowing the majority of generated cash flow to
be distributed to unitholders.
Forward-Looking Statements
This news release includes forward-looking statements. All
statements, other than statements of historical facts, included in
this news release that address activities, events or developments
that the Company expects, believes or anticipates will or may occur
in the future are forward-looking statements. Terminology such as
“will,” “may,” “should,” “expect,” “anticipate,” “plan,” “project,”
“intend,” “estimate,” “believe,” “target,” “continue,” “potential,”
the negative of such terms, or other comparable terminology often
identify forward-looking statements. Except as required by law,
Black Stone Minerals undertakes no obligation and does not intend
to update these forward-looking statements to reflect events or
circumstances occurring after this news release. You are cautioned
not to place undue reliance on these forward-looking statements,
which speak only as of the date of this news release. All
forward-looking statements are qualified in their entirety by these
cautionary statements. These forward-looking statements involve
risks and uncertainties, many of which are beyond the control of
Black Stone Minerals, which may cause the Company’s actual results
to differ materially from those implied or expressed by the
forward-looking statements. Important factors that could cause
actual results to differ materially from those in the
forward-looking statements include, but are not limited to, those
summarized below:
- the Company’s ability to execute its business strategies;
- the scope and duration of the COVID-19 pandemic and actions
taken by governmental authorities and other parties in response to
the pandemic;
- the volatility of realized oil and natural gas prices;
- the level of production on the Company’s properties;
- overall supply and demand for oil and natural gas, as well as
regional supply and demand factors, delays, or interruptions of
production;
- conservation measures, technological advances, and general
concern about the environmental impact of the production and use of
fossil fuels;
- the Company’s ability to replace its oil and natural gas
reserves;
- the Company’s ability to identify, complete, and integrate
acquisitions;
- general economic, business, or industry conditions;
- cybersecurity incidents, including data security breaches or
computer viruses;
- competition in the oil and natural gas industry; and
- the level of drilling activity by the Company's operators,
particularly in areas such as the Shelby Trough where the Company
has concentrated acreage positions.
BLACK STONE MINERALS, L.P. AND
SUBSIDIARIES
CONSOLIDATED STATEMENTS OF
OPERATIONS
(Unaudited)
(In thousands, except per unit
amounts)
Three Months Ended June
30,
Six Months Ended June
30,
2021
2020
2021
2020
REVENUE
Oil and condensate sales
$
53,936
$
25,417
$
98,112
$
77,510
Natural gas and natural gas liquids
sales
56,481
30,311
99,370
66,953
Lease bonus and other income
7,505
1,975
9,890
6,283
Revenue from contracts with customers
117,922
57,703
207,372
150,746
Gain (loss) on commodity derivative
instruments
(59,479
)
(19,174
)
(87,361
)
70,837
TOTAL REVENUE
58,443
38,529
120,011
221,583
OPERATING (INCOME) EXPENSE
Lease operating expense
3,837
3,293
6,501
7,120
Production costs and ad valorem taxes
9,296
9,555
21,138
21,931
Exploration expense
3
23
1,076
24
Depreciation, depletion, and
amortization
15,796
19,193
31,428
42,375
Impairment of oil and natural gas
properties
—
—
—
51,031
General and administrative
12,187
11,501
25,039
23,357
Accretion of asset retirement
obligations
298
278
590
550
TOTAL OPERATING EXPENSE
41,417
43,843
85,772
146,388
INCOME (LOSS) FROM OPERATIONS
17,026
(5,314
)
34,239
75,195
OTHER INCOME (EXPENSE)
Interest and investment income
—
3
—
34
Interest expense
(1,628
)
(2,964
)
(2,838
)
(7,391
)
Other income (expense)
31
(96
)
214
(97
)
TOTAL OTHER EXPENSE
(1,597
)
(3,057
)
(2,624
)
(7,454
)
NET INCOME (LOSS)
15,429
(8,371
)
31,615
67,741
Distributions on Series B cumulative
convertible preferred units
(5,250
)
(5,250
)
(10,500
)
(10,500
)
NET INCOME (LOSS) ATTRIBUTABLE TO THE
GENERAL PARTNER AND COMMON UNITS
$
10,179
$
(13,621
)
$
21,115
$
57,241
ALLOCATION OF NET INCOME (LOSS):
General partner interest
$
—
$
—
$
—
$
—
Common units
10,179
(13,621
)
21,115
57,241
$
10,179
$
(13,621
)
$
21,115
$
57,241
NET INCOME (LOSS) ATTRIBUTABLE TO LIMITED
PARTNERS PER COMMON UNIT:
Per common unit (basic)
$
0.05
$
(0.07
)
$
0.10
$
0.28
Per common unit (diluted)
$
0.05
$
(0.07
)
$
0.10
$
0.28
WEIGHTED AVERAGE COMMON UNITS
OUTSTANDING:
Weighted average common units outstanding
(basic)
207,945
206,707
207,695
206,669
Weighted average common units outstanding
(diluted)
207,945
206,707
207,695
206,669
The following table shows the Company’s production, revenues,
pricing, and expenses for the periods presented:
Three Months Ended June 30,
Six Months Ended June 30,
2021
2020
2021
2020
(Unaudited)
(Dollars in thousands, except for
realized prices and per Boe data)
Production:
Oil and condensate (MBbls)
860
864
1,689
2,027
Natural gas (MMcf)1
15,676
18,090
30,586
36,702
Equivalents (MBoe)
3,473
3,879
6,787
8,144
Equivalents/day (MBoe)
38.2
42.6
37.5
44.7
Realized prices, without derivatives:
Oil and condensate ($/Bbl)
$
62.72
$
29.42
$
58.09
$
38.24
Natural gas ($/Mcf)1
3.60
1.68
3.25
1.82
Equivalents ($/Boe)
$
31.79
$
14.37
$
29.10
$
17.74
Revenue:
Oil and condensate sales
$
53,936
$
25,417
$
98,112
$
77,510
Natural gas and natural gas liquids
sales1
56,481
30,311
99,370
66,953
Lease bonus and other income
7,505
1,975
9,890
6,283
Revenue from contracts with customers
117,922
57,703
207,372
150,746
Gain (loss) on commodity derivative
instruments
(59,479
)
(19,174
)
(87,361
)
70,837
Total revenue
$
58,443
$
38,529
$
120,011
$
221,583
Operating expenses:
Lease operating expense
$
3,837
$
3,293
$
6,501
$
7,120
Production costs and ad valorem taxes
9,296
9,555
21,138
21,931
Exploration expense
3
23
1,076
24
Depreciation, depletion, and
amortization
15,796
19,193
31,428
42,375
Impairment of oil and natural gas
properties
—
—
—
51,031
General and administrative
12,187
11,501
25,039
23,357
Other expense:
Interest expense
1,628
2,964
2,838
7,391
Per Boe:
Lease operating expense (per working
interest Boe)
$
7.41
$
4.18
$
6.27
$
4.15
Production costs and ad valorem taxes
2.68
2.46
3.11
2.69
Depreciation, depletion, and
amortization
4.55
4.95
4.63
5.20
General and administrative
3.51
2.96
3.69
2.87
1
As a mineral-and-royalty-interest owner,
Black Stone Minerals is often provided insufficient and
inconsistent data on natural gas liquid ("NGL") volumes by its
operators. As a result, the Company is unable to reliably determine
the total volumes of NGLs associated with the production of natural
gas on its acreage. Accordingly, no NGL volumes are included in
reported production; however, revenue attributable to NGLs is
included in natural gas revenue and the calculation of realized
prices for natural gas.
Non-GAAP Financial Measures
Adjusted EBITDA and distributable cash flow are supplemental
non-GAAP financial measures used by Black Stone's management and
external users of the Company's financial statements such as
investors, research analysts, and others, to assess the financial
performance of its assets and our ability to sustain distributions
over the long term without regard to financing methods, capital
structure, or historical cost basis.
The Company defines Adjusted EBITDA as net income (loss) before
interest expense, income taxes, and depreciation, depletion, and
amortization adjusted for impairment of oil and natural gas
properties, accretion of asset retirement obligations, unrealized
gains and losses on commodity derivative instruments, non-cash
equity-based compensation, and gains and losses on sales of assets.
Black Stone defines Distributable cash flow as Adjusted EBITDA plus
or minus amounts for certain non-cash operating activities, cash
interest expense, and restructuring charges.
Adjusted EBITDA and Distributable cash flow should not be
considered an alternative to, or more meaningful than, net income
(loss), income (loss) from operations, cash flows from operating
activities, or any other measure of financial performance presented
in accordance with generally accepted accounting principles
("GAAP") in the United States as measures of the Company's
financial performance.
Adjusted EBITDA and Distributable cash flow have important
limitations as analytical tools because they exclude some but not
all items that affect net income (loss), the most directly
comparable U.S. GAAP financial measure. The Company's computation
of Adjusted EBITDA and distributable cash flow may differ from
computations of similarly titled measures of other companies.
Three Months Ended June
30,
Six Months Ended June
30,
2021
2020
2021
2020
(Unaudited)
(In thousands, except per unit
amounts)
Net income (loss)
$
15,429
$
(8,371
)
$
31,615
$
67,741
Adjustments to reconcile to Adjusted
EBITDA:
Depreciation, depletion, and
amortization
15,796
19,193
31,428
42,375
Impairment of oil and natural gas
properties
—
—
—
51,031
Interest expense
1,628
2,964
2,838
7,391
Income tax expense (benefit)
7
126
(150
)
162
Accretion of asset retirement
obligations
298
278
590
550
Equity–based compensation
3,071
2,474
6,534
(420
)
Unrealized (gain) loss on commodity
derivative instruments
42,134
55,726
65,493
(25,331
)
Adjusted EBITDA
78,363
72,390
138,348
143,499
Adjustments to reconcile to Distributable
cash flow:
Change in deferred revenue
(5
)
(7
)
(15
)
(309
)
Cash interest expense
(1,001
)
(2,704
)
(1,954
)
(6,872
)
Preferred unit distributions
(5,250
)
(5,250
)
(10,500
)
(10,500
)
Restructuring charges1
—
—
—
4,815
Distributable cash flow
$
72,107
$
64,429
$
125,879
$
130,633
Total units outstanding2
208,643
206,738
Distributable cash flow per unit
$
0.346
$
0.312
1
Restructuring charges include
non-recurring costs associated with broad workforce reduction in
the first quarter of 2020.
2
The distribution attributable to the three
months ended June 30, 2021 is estimated using 208,642,990 common
units as of July 30, 2021; the exact amount of the distribution
attributable to the three months ended June 30, 2021 will be
determined based on units outstanding as of the record date of
August 13, 2021. Distributions attributable to the three months
ended June 30, 2020 were calculated using 206,737,644 common units
as of the record date of May 14, 2020.
View source
version on businesswire.com: https://www.businesswire.com/news/home/20210802005585/en/
Black Stone Minerals, L.P. Contacts Jeffrey P. Wood
President and Chief Financial Officer Evan Kiefer Vice President,
Finance and Investor Relations Telephone: (713) 445-3200
investorrelations@blackstoneminerals.com
Black Stone Minerals (NYSE:BSM)
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