UNITED STATES
SECURITIES AND EXCHANGE COMMISSION
Washington, D.C. 20549
FORM 10-Q
(Mark One)
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þ
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QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934
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For the quarterly period ended September 30, 2007
or
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o
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TRANSITION REPORT PURSUANT TO SECTION 13 OR 15 (d) OF THE SECURITIES EXCHANGE ACT OF 1934
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For the transition period from
to
Commission file number: 001-33631
Quicksilver Gas Services LP
(Exact name of registrant as specified in its charter)
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Delaware
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56-2639586
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(State or other jurisdiction of
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(I.R.S. Employer Identification No.)
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incorporation or organization)
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777 West Rosedale, Fort Worth, Texas
(Address of principal executive offices)
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76104
(Zip Code)
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(817) 665-8620
(Registrants telephone number, including area code)
None
(Former name, former address and former fiscal year, if changed since last report)
Indicate by check mark whether the registrant: (1) has filed all reports required to be filed
by Section 13 or 15(d) of the Securities Exchange Act of 1934 during the preceding 12 months (or
for such shorter period that the registrant was required to file such reports), and (2) has been
subject to such filing requirements for the past 90 days. Yes
þ
No
o
Indicate by check mark whether the registrant is a large accelerated filer, an accelerated
filer, or a non-accelerated filer. See definition of accelerated filer and large accelerated
filer in Rule 12b-2 of the Exchange Act.
Large accelerated filer
o
Accelerated filer
o
Non-accelerated filer
þ
Indicate by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of
the Exchange Act). Yes
o
No
þ
The Registrant has 12,263,625 Common Units, 11,513,625 Subordinated Units and 469,944 General
Partner Units outstanding as of October 31, 2007
.
EXPLANATORY NOTE
On August 10, 2007, we completed our initial public offering, or IPO, of 5,000,000 common units
representing limited partnership interests. On September 7, 2007, we sold an additional 750,000
common units upon the exercise by the underwriters of the IPO of an over-allotment option that we
had previously granted to them.
Upon the completion of the IPO, we succeeded to the assets and operations of Cowtown Pipeline LP,
Cowtown Pipeline Partners LP, Cowtown Gas Processing LP and Cowtown Gas Processing Partners LP,
which we refer to collectively as the Cowtown Entities or the Quicksilver Gas Services Predecessor.
Prior to the completion of the IPO, the Cowtown Entities were owned indirectly by Quicksilver
Resources Inc., which we refer to as Quicksilver or the Parent, and by two private investors, which
we refer to as the Private Investors.
The information contained in this report includes the activity of Quicksilver Gas Services
Predecessor prior to the completion of the IPO on August 10, 2007 and the activity of Quicksilver
Gas Services LP subsequent to the completion of the IPO on August 10, 2007 through September 30,
2007. Consequently, the unaudited condensed consolidated interim financial statements and related discussion
of financial condition and results of operations contained in this report reflect the activity for
the three and nine month periods ended September 30, 2007 without regard to the change of ownership
during the period.
The information contained in this report should be read in conjunction with the information
contained in the prospectus, dated August 6, 2007, relating to the IPO, which we filed with the
Securities and Exchange Commission on August 7, 2007.
2
QUICKSILVER GAS SERVICES LP
INDEX TO FORM 10-Q
For the Period Ended September 30, 2007
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Page
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4
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5
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6
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7
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8
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21
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30
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31
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32
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32
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33
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34
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3
PART I. FINANCIAL INFORMATION
Item 1. Financial Statements
QUICKSILVER GAS SERVICES LP
CONDENSED CONSOLIDATED BALANCE SHEETS
In thousands Unaudited
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September 30,
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December 31,
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2007
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2006
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ASSETS
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Current assets
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Cash and cash equivalents
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$
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18,099
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$
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2,797
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Trade accounts receivable
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925
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67
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Other current assets
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553
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147
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Total current assets
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19,577
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3,011
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Property, plant and equipment net
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227,825
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130,791
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Other assets
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959
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821
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Total assets
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$
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248,361
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$
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134,623
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LIABILITIES, REDEEMABLE PARTNERS CAPITAL AND PARTNERS CAPITAL
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Current liabilities
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Current portion of note payable to parent
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$
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825
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$
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Accounts payable to parent
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10,179
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Accrued additions to property, plant and equipment
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7,180
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6,608
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Accounts payable and other
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2,332
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1,294
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Total current liabilities
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20,516
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7,902
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Repurchase obligations to parent
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64,458
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Note payable to parent
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49,800
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Asset retirement obligations
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1,893
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503
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Deferred income tax liabilities
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151
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135
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Commitments
and contingent liabilities (Note 8)
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Redeemable partners capital
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7,431
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Partners Capital
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Common unitholders (12,263,625 units issued and outstanding
at September 30, 2007)
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110,740
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Subordinated unitholders (11,513,625 units issued and
outstanding at September 30, 2007)
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771
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General partner (469,944 units issued and outstanding
at September 30, 2007)
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32
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Net parent equity
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118,652
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Total partners capital
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111,543
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118,652
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Total liabilities, redeemable partners capital and partners capital
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$
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248,361
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$
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134,623
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The accompanying notes are an integral part of these condensed consolidated interim financial statements.
4
QUICKSILVER GAS SERVICES LP
CONDENSED CONSOLIDATED STATEMENTS OF INCOME
In thousands except per unit data Unaudited
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For the Three Months Ended
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For the Nine Months Ended
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September 30,
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September 30,
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2007
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2006
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2007
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2006
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Revenues:
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Gathering and
transportation revenue parent
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$
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4,102
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$
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1,948
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$
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9,612
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$
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4,663
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Gathering and transportation revenue
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500
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838
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Gas processing revenue parent
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4,892
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2,125
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11,109
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5,327
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Gas processing revenue
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521
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912
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Other revenue parent
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267
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300
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Total revenues
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10,282
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4,073
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22,771
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9,990
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Expenses:
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Operations and maintenance parent
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3,072
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2,409
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8,063
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5,691
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General and administrative parent
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1,217
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489
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2,353
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833
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Depreciation and amortization
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2,188
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1,032
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5,307
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2,119
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Total expenses
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6,477
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3,930
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15,723
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8,643
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|
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Operating income
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3,805
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|
|
|
143
|
|
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|
7,048
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|
|
1,347
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|
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Other income
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|
|
114
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|
|
|
|
|
|
|
149
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|
|
|
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Interest expense
|
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1,728
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|
|
|
|
|
|
1,939
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|
|
|
|
|
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|
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|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
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Income before income taxes
|
|
|
2,191
|
|
|
|
143
|
|
|
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5,258
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|
|
|
1,347
|
|
Income tax provision
|
|
|
92
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|
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|
|
|
|
|
189
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|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
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Net income
|
|
$
|
2,099
|
|
|
$
|
143
|
|
|
$
|
5,069
|
|
|
$
|
1,347
|
|
|
|
|
|
|
|
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|
|
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|
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|
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Allocation of net income for the three and nine
month periods ended September 30, 2007:
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|
|
|
|
|
|
|
|
|
|
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|
Net income attributable to the period from
beginning of period to August 9, 2007
|
|
$
|
474
|
|
|
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|
|
$
|
3,444
|
|
|
|
|
|
Net income attributable to the period from
August 10, 2007 to September 30, 2007
|
|
|
1,625
|
|
|
|
|
|
|
|
1,625
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Net income
|
|
$
|
2,099
|
|
|
|
|
|
|
$
|
5,069
|
|
|
|
|
|
|
|
|
|
|
|
|
|
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|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
General partner interest in net income for the
period from August 10, 2007 to September 30,
2007
|
|
$
|
32
|
|
|
|
|
|
|
$
|
32
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Common and subordinated unitholders interest
in net income for the period from August 10,
2007 to September 30, 2007
|
|
$
|
1,593
|
|
|
|
|
|
|
$
|
1,593
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Basic net income per common and subordinated
unit
|
|
$
|
0.07
|
|
|
|
|
|
|
$
|
0.07
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Diluted net income per common and subordinated
unit
|
|
$
|
0.07
|
|
|
|
|
|
|
$
|
0.07
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Basic average number of common and
subordinated units outstanding
|
|
|
23,777
|
|
|
|
|
|
|
|
23,777
|
|
|
|
|
|
Diluted average number of common and
subordinated units outstanding
|
|
|
23,787
|
|
|
|
|
|
|
|
23,787
|
|
|
|
|
|
The accompanying notes are an integral part of these condensed consolidated interim financial statements.
5
QUICKSILVER GAS SERVICES LP
CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS
In thousands Unaudited
|
|
|
|
|
|
|
|
|
|
|
For the Nine Months Ended
|
|
|
|
September 30,
|
|
|
|
2007
|
|
|
2006
|
|
Operating activities:
|
|
|
|
|
|
|
|
|
Net income
|
|
$
|
5,069
|
|
|
$
|
1,347
|
|
Adjustments to reconcile net income to net cash provided
by operating activities:
|
|
|
|
|
|
|
|
|
Depreciation and amortization
|
|
|
5,253
|
|
|
|
2,104
|
|
Accretion of asset retirement obligations
|
|
|
54
|
|
|
|
15
|
|
Amortization of debt issuance costs
|
|
|
33
|
|
|
|
|
|
Equity-based compensation
|
|
|
45
|
|
|
|
|
|
Deferred income tax expense
|
|
|
16
|
|
|
|
|
|
Non-cash interest expense on repurchase obligations
|
|
|
1,228
|
|
|
|
|
|
Non-cash interest expense on note payable to parent
|
|
|
625
|
|
|
|
|
|
Changes in assets and liabilities:
|
|
|
|
|
|
|
|
|
Accounts receivable
|
|
|
(858
|
)
|
|
|
|
|
Other current assets
|
|
|
(229
|
)
|
|
|
|
|
Accounts payable to parent
|
|
|
(1,095
|
)
|
|
|
|
|
Accounts payable and other
|
|
|
1,038
|
|
|
|
707
|
|
|
|
|
|
|
|
|
Net cash provided by operating activities
|
|
|
11,179
|
|
|
|
4,173
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Investing activities:
|
|
|
|
|
|
|
|
|
Additions to property, plant and equipment
|
|
|
(55,184
|
)
|
|
|
(53,818
|
)
|
|
|
|
|
|
|
|
Net cash used in investing activities
|
|
|
(55,184
|
)
|
|
|
(53,818
|
)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Financing activities:
|
|
|
|
|
|
|
|
|
Proceeds from sale of assets to parent
|
|
|
29,508
|
|
|
|
|
|
Debt issuance costs paid
|
|
|
(715
|
)
|
|
|
|
|
Proceeds from initial public offering
|
|
|
112,298
|
|
|
|
|
|
Costs incurred in connection with initial public offering
|
|
|
(190
|
)
|
|
|
|
|
Distribution of initial public offering proceeds to
partners
|
|
|
(119,806
|
)
|
|
|
|
|
Contributions by parent
|
|
|
38,045
|
|
|
|
45,139
|
|
Contributions by redeemable partners
|
|
|
167
|
|
|
|
4,506
|
|
|
|
|
|
|
|
|
Net cash provided by financing activities
|
|
|
59,307
|
|
|
|
49,645
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Net increase in cash and cash equivalents
|
|
|
15,302
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Cash and cash equivalents at beginning of period
|
|
|
2,797
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Cash and cash equivalents at end of period
|
|
$
|
18,099
|
|
|
$
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Non-cash transactions:
|
|
|
|
|
|
|
|
|
Changes in working capital related to the acquisition of
property, plant and equipment
|
|
$
|
(12,045
|
)
|
|
$
|
(7,582
|
)
|
Prepaid insurance paid by parent
|
|
$
|
(176
|
)
|
|
$
|
|
|
Debt issuance costs paid by parent
|
|
$
|
(277
|
)
|
|
$
|
|
|
Cost in connection with the initial public offering paid
by parent
|
|
$
|
(2,465
|
)
|
|
$
|
|
|
Issuance of subordinated note payable to parent
|
|
$
|
50,000
|
|
|
$
|
|
|
Repurchase obligations to parent acquisition of
property, plant, and equipment by parent
|
|
$
|
(33,722
|
)
|
|
$
|
|
|
The accompanying notes are an integral part of these condensed consolidated interim financial statements.
6
QUICKSILVER GAS SERVICES LP
CONDENSED CONSOLIDATED STATEMENT OF CHANGES IN PARTNERS CAPITAL
In thousands Unaudited
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Partners Capital
|
|
|
|
|
|
|
Redeemable
|
|
Limited Partners
|
|
|
|
|
|
|
Net Parent Equity
|
|
Partners Capital
|
|
Common
|
|
Subordinated
|
|
General Partner
|
|
Total
|
Balance at December 31, 2006
|
|
$
|
118,652
|
|
|
$
|
7,431
|
|
|
$
|
|
|
|
$
|
|
|
|
$
|
|
|
|
$
|
126,083
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Net income attributable to the
period from January 1, 2007 through
August 9, 2007
|
|
|
3,119
|
|
|
|
326
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
3,445
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Contributions
|
|
|
38,045
|
|
|
|
167
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
38,212
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Initial public offering, net of
offering and other costs
|
|
|
|
|
|
|
|
|
|
|
109,643
|
|
|
|
|
|
|
|
|
|
|
|
109,643
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Distribution of initial public
offering proceeds
|
|
|
(112,112
|
)
|
|
|
(7,694
|
)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
(119,806
|
)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Distribution of subordinated note
payable to parent
|
|
|
(50,000
|
)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
(50,000
|
)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Reclass parents equity balance to
receivable from parent
|
|
|
2,296
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
2,296
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Reclass redeemable partners capital
|
|
|
|
|
|
|
(230
|
)
|
|
|
230
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Noncash compensation
|
|
|
|
|
|
|
|
|
|
|
45
|
|
|
|
|
|
|
|
|
|
|
|
45
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Net income attributable to the
period from August 10, 2007 through
September 30, 2007
|
|
|
|
|
|
|
|
|
|
|
822
|
|
|
|
771
|
|
|
|
32
|
|
|
|
1,625
|
|
|
|
|
Balance at September 30, 2007
|
|
$
|
|
|
|
$
|
|
|
|
$
|
110,740
|
|
|
$
|
771
|
|
|
$
|
32
|
|
|
$
|
111,543
|
|
|
|
|
The accompanying notes are an integral part of this condensed consolidated interim financial statement.
7
QUICKSILVER GAS SERVICES LP
NOTES TO CONDENSED CONSOLIDATED INTERIM FINANCIAL STATEMENTS
UNAUDITED
1. ORGANIZATION AND DESCRIPTION OF BUSINESS
Organization
Quicksilver Gas Services LP (the Partnership, KGS, or We,) is a Delaware limited partnership formed in January 2007 for the purpose of
acquiring the assets of Quicksilver Gas Services Predecessor (KGS Predecessor). KGS general
partner is Quicksilver Gas Services GP LLC (the General Partner).
KGS Predecessor, since its inception, was comprised of entities under the common control of
Quicksilver Resources Inc. (Quicksilver or the Parent). The entities under common control,
after having been formed by Quicksilver and giving effect to multiple contemporaneous transactions,
were Cowtown Pipeline LP, Cowtown Pipeline Partners LP, Cowtown Gas Processing LP and Cowtown Gas
Processing Partners LP.
Initial Public Offering
On August 6, 2007, KGS entered into an underwriting agreement (the
Underwriting Agreement) with the General Partner, Quicksilver and Quicksilver Gas Services
Holdings LLC (Holdings) and the underwriters named therein (the Underwriters) for the sale of
5,000,000 common units, representing a 21.3% limited partner interest in KGS sold by KGS at a price
to the public of $21.00 per common unit ($19.53 per common unit, net of underwriting discounts and
structuring fees).
The initial public offering, or IPO, closed on August 10, 2007 and the common units trade
under the ticker symbol KGS. The proceeds, net of underwriting discounts and structuring fees,
received by KGS, before expenses, were approximately $97.7 million. As described in the prospectus,
dated August 6, 2007, and filed by KGS with the SEC on August 7, 2007, KGS has used, or will use,
the net proceeds of the IPO together with cash on hand of $25.1 million to: (i) distribute
approximately $162.1 million (consisting of $112.1 million in cash and a $50.0 million subordinated
promissory note payable) to Quicksilver and approximately $7.7 million in cash to two private
investors the (Private Investors) as a return of investment capital contributed and reimbursement
for capital expenditures advanced, (ii) pay approximately $3.6 million of expenses associated with
the IPO, the credit agreement and certain formation transactions related to the IPO, and (iii)
retain the balance for general partnership purposes.
Additionally, at the completion of the IPO, the following formation transactions occurred:
|
|
|
Quicksilver affiliates contributed to KGS their 95% interest in Cowtown Gas Processing
Partners LP and their 93% interest in Cowtown Pipeline Partners LP,
|
|
|
|
|
The Private Investors contributed to KGS their 5% interests in Cowtown Gas Processing
Partners LP and their 7% interests in Cowtown Pipeline Partners LP;
|
|
|
|
|
KGS issued to Quicksilver 5,696,752 common units and 11,513,625 subordinated units;
|
|
|
|
|
KGS issued to the Private Investors a total of 816,873 common units; and
|
|
|
|
|
KGS issued to the General Partner
|
|
-
|
|
469,944 general partner units, and
|
|
|
-
|
|
all of KGS incentive distribution rights, which entitle the General Partner to
increasing percentages of any cash that KGS distributes in excess of $0.3450 per unit per
quarter.
|
KGS owns all of the ownership interests in Quicksilver Gas Services Operating LLC (Operating
LLC) and its operating subsidiaries, which own and operate KGS assets.
On September 7, 2007, pursuant to the Underwriting Agreement, the Underwriters exercised in
full their option to purchase up to an additional 750,000 common units on the same terms as the
IPO. The proceeds, net of underwriting discounts and structuring fees, received by KGS were
approximately $14.6 million. The proceeds have been, or will be, used for general partnership
purposes.
As of September 30, 2007 the ownership of KGS is as follows:
8
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Percentage
|
|
|
Units
|
|
Ownership
|
Common Unitholders:
|
|
|
|
|
|
|
|
|
Public
|
|
|
6,566,873
|
|
|
|
27.1
|
%
|
Quicksilver
|
|
|
5,696,752
|
|
|
|
23.5
|
%
|
Subordinated Unitholders:
|
|
|
|
|
|
|
|
|
Quicksilver
|
|
|
11,513,625
|
|
|
|
47.5
|
%
|
General Partner Unitholders:
|
|
|
|
|
|
|
|
|
Quicksilver
|
|
|
469,944
|
|
|
|
1.9
|
%
|
|
|
|
Total
|
|
|
24,247,194
|
|
|
|
100
|
%
|
See Note 3 for information related to the distributions rights of the common and subordinated
unitholders and the incentive distribution rights held by the Partner.
The General Partner is a wholly-owned subsidiary of the Parent. Neither KGS nor the General
Partner has any employees. Employees of the Parent have been seconded to the General Partner
pursuant to a services and secondment agreement. The seconded employees, including field operations
personnel, general and administrative personnel, and an operational vice president, operate KGS
pipeline system and natural gas processing facilities.
Description of Business
KGS is engaged in the business of gathering and processing natural
gas and natural gas liquids, also known as NGLs, produced in the Barnett Shale formation of the
Fort Worth Basin located in North Texas. KGS assets consist of a pipeline system in the
Fort Worth Basin, referred to as the Cowtown Pipeline, and a natural gas processing plant in Hood
County, Texas, referred to as the Cowtown Plant. The Cowtown Pipeline consists of natural gas
gathering pipelines that gather natural gas produced by customers and deliver it to the Cowtown
Plant. The Cowtown Plant consists of KGS natural gas processing units that extract, or process,
the NGLs from the natural gas stream and, on behalf of KGS customers, makes their residue gas
available to third party pipelines for transport downstream. The NGLs are sold to intrastate
pipelines on behalf of KGS customers, after transport to an interconnecting third party pipeline
via a pipeline segment owned and operated by KGS. Since our inception
in 2004, we have made substantial capital expenditures. We anticipate
that we will continue to make substantial expansion capital
expenditures as Quicksilver continues to expand its production
efforts in the Fort Worth Basin.
2. SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES
Basis of Presentation
The accompanying unaudited condensed consolidated interim financial statements
and related notes of KGS present the financial position, results of operations and cash flows and
changes in partners capital of KGS Fort Worth Basin natural gas gathering and processing assets.
The
financial statements include historical cost-basis accounts of the
assets of KGS Predecessor, contributed to KGS by Quicksilver in
connection with the IPO for the periods prior to August 10, 2007, the
closing date of the IPO. Both KGS Predecessor and KGS are considered
entities under common control as defined under accounting
principles generally accepted in the United States of America and, as
such, the transfer between entities of the assets and liabilities and
operations has been recorded in a manner similar to that required for
a pooling of interests, whereby the recorded assets and liabilities of
KGS Predecessor are carried forward to the consolidated partnership
at their historical amounts.
The unaudited condensed consolidated interim financial statements include the accounts of KGS and have
been prepared in accordance with accounting principles generally accepted in the United States of
America. All intercompany balances and transactions within KGS have been eliminated. The unaudited
condensed consolidated interim financial statements as of and for the three and nine months ended September
30, 2007 and 2006, have been prepared on the same basis as, and should be read in conjunction with,
the audited combined interim financial statements of KGS Predecessor included in the prospectus,
dated August 6, 2007, and filed by KGS with the SEC on August 7, 2007. In the opinion of
management, the unaudited condensed consolidated interim financial statements contain all adjustments
necessary to present fairly the financial condition of the KGS as of September 30, 2007 and its
results of operations for the three and nine month periods ended September 30, 2007 and 2006 and
its cash flows for the nine month periods ended September 30, 2007 and 2006. All such adjustments
are of a normal recurring nature. Certain disclosures normally included in financial statements
prepared in accordance with accounting principles generally accepted in the United States of
America have been condensed or omitted. The results of operations for an interim period are not
necessarily indicative of annual results.
Use of Estimates
KGS preparation of financial statements in accordance with accounting
principles generally accepted in the United States of America requires management to make estimates
and judgments that affect reported financial condition and results of operations. Management
reviews significant estimates and judgments affecting the condensed consolidated financial statements on a
recurring basis and records the effect of any necessary adjustments prior to their publication.
Estimates and judgments are based on information available at the time such estimates and judgments
are made. Adjustments made with respect to the use of these estimates and judgments often relate to
information not previously available. Uncertainties with respect to such estimates and judgments
are inherent in the preparation of financial statements. Estimates and judgments are used in, among
other things: (1) operating and general and administrative costs; (2) developing fair value
assumptions, including estimates of future cash flows and discount rates; (3) analyzing tangible
and intangible assets for possible impairment; (4) estimating the useful lives of assets; and
(5) determining amounts to accrue for contingencies, guarantees and indemnifications.
Cash and Cash Equivalents
Cash and cash equivalents consist of time deposits and liquid debt
investments with original maturities of three months or less at the time of purchase.
Property, Plant and Equipment
Property, plant and equipment is stated at cost less
accumulated depreciation and accretion. Depreciation is computed using the straight-line method
over the estimated useful lives of the assets.
9
Expenditures for maintenance and repairs are expensed as incurred. Expenditures to refurbish
assets that extend the useful lives or prevent environmental contamination are capitalized and
depreciated over the remaining useful life of the asset. Upon disposition or retirement of
property, plant and equipment, any gain or loss is charged to operations.
Asset Retirement Obligations
KGS records the fair value of the liability for asset
retirement obligations in the period in which it is incurred. Upon initial recognition of the
asset retirement liability, an asset retirement cost is capitalized by increasing the carrying
amount of the long-lived asset by the same amount as the liability. In periods subsequent to the
initial measurement, the asset retirement cost is allocated to expense using a straight line method
over the assets useful life. Changes in the liability for the asset retirement obligation are
recognized for (a) the passage of time and (b) revisions to either the timing or the amount of the
original estimate of undiscounted cash flows.
Repurchase Obligations to Parent
On June 5, 2007, KGS Predecessor sold several pipeline and
gathering assets to Quicksilver. These assets consist of gathering lines that are part of the
Cowtown Pipeline (Cowtown Pipeline Assets), and two new pipeline systems in the Lake Arlington
area of Tarrant County and Hill County (the Lake Arlington Dry System and the Hill County Dry
System respectively). At June 5, 2007, the assets were either constructed and in service or
partially constructed. The selling price for these assets was approximately $29.5 million, which
represented KGS Predecessors historical cost. KGS Predecessor collected the $29.5 million on
August 9, 2007. The assets were conveyed to Quicksilver through a written assignment.
Cowtown Pipeline Assets Repurchase:
In accordance with the Gas Gathering and
Processing Agreement (the Gas Gathering and Processing Agreement) between KGS and Quicksilver,
KGS has the option to purchase the Cowtown Pipeline Assets from Quicksilver at historical cost
within two years after the Cowtown Pipeline Assets commence commercial service. The Cowtown
Pipeline Assets comprised $22.9 million of the total sale price to Quicksilver. Quicksilver
estimates that the total construction costs to complete these
pipelines will be approximately
$40.6 million, of which $31.8 million of costs had been incurred through September 30, 2007. A portion of the Cowtown Pipeline Assets have commenced
commercial service as of September 30, 2007.
Lake Arlington Dry System and Hill County Dry System Repurchases:
In accordance
with the Omnibus Agreement between KGS, the General Partner and Quicksilver, KGS is obligated to
purchase the Lake Arlington Dry System and the Hill County Dry System from Quicksilver at fair
market value within two years after those assets commence commercial service. The Lake Arlington
Dry System and the Hill County Dry System assets comprise
$3.6 million and $3.0 million,
respectively, of the total $29.5 million sale price to Quicksilver. Quicksilver estimates that
the total construction costs to complete the Lake Arlington Dry System and the Hill County Dry
System will be approximately $32.7 million and
$49.4 million, respectively, of which $19.3 and
$12.1 million of costs had been incurred as of September
30, 2007, respectively. A portion of the Hill County Dry System assets have commenced commercial
service as of September 30, 2006. The Lake Arlington Dry System assets have not commenced
commercial service as of September 30, 2007.
As KGS has significant continuing involvement in the operation of the Cowtown Pipeline Assets,
the Lake Arlington Dry System and the Hill County Dry System and intends to exercise its purchase
rights, the conveyance of assets has not been treated as a sale for accounting purposes, such that
the original cost of $29.5 million and subsequently incurred costs of $33.7 million have been
included in both property, plant and equipment and repurchase obligations to parent. Similarly,
KGS results of operations include the revenues and expenses for these operations. Under KGS
credit facility agreement, neither the repurchase obligations nor the imputed interest thereon are
included as indebtedness or interest expense for purposes of covenant compliance. For the period
from June 5, 2007 through September 30, 2007, KGS recognized imputed interest based on the
outstanding repurchase obligations balance at a rate of 8.83%, which was based upon the effective
interest rate on the $50.0 million subordinated note payable to parent. See Note 7 for information
related to the credit facility and the subordinated note payable to parent.
Other Assets
Other assets consist of prepaid insurance, deposits and other miscellaneous
receivables.
Impairment of Long-Lived Assets
Long-lived assets are reviewed by management for impairment
whenever events or circumstances indicate that the carrying amount of such assets may not be
recoverable. The carrying amount of a long-lived asset is not recoverable when it exceeds the
undiscounted sum of the cash flows expected to result from the use and eventual disposition of the
asset. Estimates of expected future cash flows are based on assumptions that management believe are
reasonable and supportable. When the carrying amount of a long-lived asset is determined not to be
recoverable, impairment loss is measured as the excess of the assets carrying value over its fair
value. The fair values of long-lived assets are determined using commonly accepted techniques,
including, but not limited to, recent third party comparable sales, internally developed discounted
cash flow analysis and analysis from outside advisors. There were no indications of asset
impairments at September 30, 2007.
10
Environmental Liabilities
Liabilities for environmental loss contingencies, including
environmental remediation costs, are charged to expense when it is probable that a liability has
been incurred and the amount of the assessment and/or remediation can be reasonably estimated.
Redeemable Partners Capital
KGS Predecessor accounted for partners capital subject to
provisions for redemption outside of its control as mezzanine equity. Redeemable partners capital
was recorded at fair value at the date of issue and was thereafter accreted to the redemption
amount at each balance sheet date. Partners could redeem their redeemable capital at any time at
fair value as defined in the redemption agreement. The resulting increases in the carrying amount
of the redeemable partners capital were reflected through decreases in net parent equity. No
accretion was recorded as the carrying amounts exceeded the redemption amounts for all periods
presented.
Revenue Recognition
KGS primary service activities reported as operating revenue are the
gathering and processing of natural gas. KGS has only fee-based contracts, under which it receives
a fixed fee based on the volume of natural gas gathered and processed. KGS recognizes revenue when
all of the following criteria are met:
|
|
|
persuasive evidence of an exchange arrangement exists;
|
|
|
|
|
delivery has occurred or services have been rendered;
|
|
|
|
|
the price is fixed or determinable; and
|
|
|
|
|
collectibility is reasonably assured
|
Income Taxes
No provision for income taxes related to KGS results of operations is
included in the unaudited condensed consolidated interim financial statements as such income is taxable
directly to the partners holding interests in the Partnership.
The State of Texas enacted a margin tax in May 2006 that KGS will be required to pay beginning
in 2008. The method of calculation for this margin tax is similar to an income tax, requiring KGS
to recognize currently the impact of this new tax on the future tax effects of temporary
differences between the financial statement carrying amounts and the tax basis of existing assets
and liabilities. See Note 9 for information regarding income taxes.
Net Income per Limited Partner Unit
Earnings per unit presented on the statement of income
for the three and nine months ended September 30,2007 reflect only the earnings for the two months
since the closing of KGS initial public offering on August 10, 2007. For convenience, July 31,
2007 has been used as the date of the change in ownership. Accordingly, results for January through
July 2007 have been excluded from the calculation of earnings per unit.
Emerging Issues Task Force (EITF) Issue 03-6,
Participating Securities and the
Two-Class Method Under FASB Statement No. 128
addresses the computation of earnings per share by
entities that have issued securities other than common stock that contractually entitle the holder
to participate in dividends and earnings of the entity when, and if, it declares dividends on its
securities. EITF 03-6 requires that securities that meet the definition of a participating
security be considered for inclusion in the computation of basic earnings per unit using the
two-class method. Under the two-class method, earnings per unit is calculated as if all of the
earnings for the period were distributed under the terms of the partnership agreement, regardless
of whether the general partner has discretion over the amount of distributions to be made in any
particular period, whether those earnings would actually be distributed during a particular period
from an economic or practical perspective, or whether the general partner has other legal or
contractual limitations on its ability to pay distributions that would prevent it from distributing
all of the earnings for a particular period.
EITF 03-6 does not impact KGS overall net income or other financial results; however, in
periods in which aggregate net income exceeds KGS aggregate distributions for such period, it will
have the impact of reducing net income per limited partner unit. This result occurs as a larger
portion of KGS aggregate earnings, as if distributed, is allocated to the incentive distribution
rights of the general partner, even though KGS makes distributions on the basis of available cash
and not earnings. In periods in
which KGS aggregate net income does not exceed its aggregate distributions for such period,
EITF 03-6 does not have any impact on KGS calculation of earnings per limited partner unit.
Segment Information
SFAS No. 131,
Disclosures about Segments of an Enterprise and Related
Information,
establishes standards for reporting information about operating segments. KGS operates
in one segment only, the natural gas gathering, transportation and processing segment, generally
described as midstream operations.
Fair Value of Financial Instruments
The fair value of accounts receivable, accounts payable
and repurchase obligations to the parent is not materially different from their carrying amounts.
11
Equity Based Compensation
SFAS No. 123(R),
Share-Based Payment
, (SFAS 123(R)), requires
companies to recognize stock-based compensations, as an operating expense. Subsequent to the IPO,
awards of phantom units have been granted under KGS 2007 Equity Plan (see Note 10), which permits
the issuance of up to 750,000 units. At time of issuance, KGS determines whether the phantom units
will be settled in cash or settled in KGS common units. For awards payable in cash, KGS amortizes
the expense associated with the award over the vesting period; however, the fair value is
reassessed at every balance sheet date, with the vested portion of awards being adjusted via
expense to reflect revised fair value. Phantom unit awards payable in units are valued at the
closing market price of KGS common units on the date of grant. The unearned compensation is
amortized to compensation expense over the vesting period of the phantom unit award. Additionally,
KGS is affected by the allocation of stock-based compensation cost by the Parent, who has also
adopted SFAS 123(R).
Recently Issued Accounting Standards
In September 2006, the FASB issued SFAS No. 157,
Fair
Value Measurements
(SFAS 157). SFAS 157 defines fair value, establishes a framework for measuring
fair value in generally accepted accounting principles (GAAP), and expands disclosures about fair
value measurements. SFAS 157 applies under other accounting pronouncements that require or permit
fair value measurements, where the FASB concluded that fair value is the relevant measurement
attribute. Accordingly, SFAS 157 does not require any new fair value measurements. SFAS 157
becomes effective for KGS on January 1, 2008. KGS has not yet determined the impact this
pronouncement will have on its financial statements.
In June 2006, the FASB issued Interpretation No. 48,
Accounting for Uncertainty in Income
Taxes an interpretation of FASB Statement No. 109
(FIN 48), which clarifies the accounting and
disclosure for uncertainty in tax provisions. FIN 48 seeks to reduce the diversity in practice
associated with certain aspects of the recognition and measurement related to accounting for income
taxes. This interpretation is effective for fiscal years beginning after December 15, 2006.
Interest and penalties, if incurred, would be recognized as components of interest expense. KGS
Predecessors adoption of FIN 48 on January 1, 2007 had no impact on its financial statements.
In February 2007, the FASB issued SFAS No. 159,
The Fair Value Option for Financial Assets and
Financial Liabilities, including an amendment of FASB Statement No. 115
(SFAS 159). SFAS 159
permits entities to measure many financial instruments and certain other assets and liabilities at
fair value. SFAS 159 is effective for KGS on January 1, 2008. KGS has not yet adopted SFAS 159 or
determined the impact this pronouncement will have on its financial statements.
In April 2007, the FASB issued FASB Staff Position (FSP) No. FIN 39-1,
Amendment of FASB
Interpretation No. 39
. The FSP amends paragraph 3 of FIN No. 39 to replace the terms conditional
contracts and exchange contracts with the term derivative instruments as defined in SFAS
No. 133,
Accounting for Derivative Instruments and Hedging Activities
. It also amends paragraph 10
of Interpretation 39 to permit a reporting entity to offset fair value amounts recognized for
derivative instruments executed with the same counterparty under the same master netting
arrangement that have been offset in accordance with that paragraph. The guidance in this FSP is
effective for KGS on January 1, 2008, at which time KGS will recognize the effects of applying this FSP as
a change in accounting principle through retrospective application for all financial statements
presented. KGS is evaluating the FSPs guidance, but does not believe its adoption will have a
material impact on its financial statements.
3. PARTNERS CAPITAL AND DISTRIBUTIONS
General.
The KGS partnership agreement requires that KGS distribute, within 45 days after
the end of each quarter, all of its Available Cash (discussed below) to unitholders of record on
the applicable record date, as selected by the General Partner.
Available Cash, for any quarter,
consists of the sum of (i) all cash and cash equivalents on
hand at the end of that quarter and (ii) additional cash on hand on the date of determination of
Available Cash for the quarter resulting from working capital borrowings made subsequent to the end
of the quarter less the amount of cash reserves established by the General Partner to:
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provide for the proper conduct of KGS business;
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comply with applicable law, any of KGS debt instruments or other agreements; or
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provide funds for distributions to the unitholders and to the General Partner for
any one or more of the next four quarters.
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Working capital borrowings are generally borrowings that are made under a credit
facility or another arrangement, are used solely for working capital purposes or to pay
distributions to unitholders and are intended to be repaid within 12 months.
For the quarter ended September 30, 2007, KGS declared a pro-rated distribution of
$0.1675 per unit for holders of record on October 31, 2007. The aggregate distribution of
approximately $4.1 million will be paid on November 14, 2007 and recognized as a
distribution upon payment.
General Partner Interest and Incentive Distribution Rights.
The General Partner is
entitled to its pro rata portion of all quarterly distributions that KGS makes prior to its
liquidation. The General Partner has the right, but not the obligation, to contribute a
proportionate amount of capital to us to maintain its current General Partner interest. The
General Partners initial 2% interest in these distributions will be reduced if KGS issues
additional units in the future
12
and the General Partner does not contribute a proportionate
amount of capital to us to maintain a 2% ownership level. The incentive distribution
rights held by the General Partner entitle it to receive increasing percentages, up to a
maximum of 48%, of distributions from operating surplus in excess of pre-defined
distribution targets.
Subordinated
Units.
All of the subordinated units, which represent limited partner
interests, are held by Quicksilver. The partnership agreement provides that, during the
subordination period, the common units have the right to receive distributions of Available
Cash each quarter in an amount equal to $0.30 per common unit, or the Minimum Quarterly
Distribution, plus any arrearages in the payment of the Minimum Quarterly Distribution on
the common units from prior quarters, before any distributions of Available Cash from
operating surplus may be made to the subordinated unit holders. Furthermore, no arrearages
will be paid on the subordinated units. The practical effect of the subordinated units is
to increase the likelihood that, during the subordination period, there will be a higher
likelihood of distribution to the common unit holders. The subordination period will end,
and the subordinated units will convert to common units, on a one for one basis, when
certain distribution requirements defined in the Partnership Agreement have been met. The
subordination period generally will end if KGS has earned and paid at least $0.30 per
quarter on each common unit, subordinated unit and General Partner unit for any three
consecutive, non-overlapping four-quarter periods ending on or after June 30, 2010. Also,
if KGS has earned and paid at least $0.45 per quarter (150% of the minimum quarterly
distribution) on each outstanding common unit, subordinated unit and General Partner unit
for any four-quarter period, the subordination period will terminate automatically and all
of the subordinated units will convert into an equal number of common units. The
subordination period will also terminate automatically if the General Partner is removed
without cause and the units held by the General Partner and its affiliates are not voted in
favor of removal. When the subordination period ends, all remaining subordinated units
will convert into common units on a one-for-one basis, and the common units will no longer
be entitled to arrearages.
Distributions of Available Cash from Operating Surplus during the Subordination
Period.
Assuming KGS does not issue additional classes of equity securities, the Partnership
Agreement requires that KGS make distributions of Available Cash from operating surplus for
any quarter during the subordination period in the following manner:
first
, (x) to the General Partner in accordance with its percentage
interest and (y) to the unitholders holding common units, pro rata,
a percentage equal to 100% less the General Partners percentage
interest, until there has been distributed in respect of each common
unit then outstanding an amount equal to the minimum quarterly
distribution for such quarter;
second
, (x) to the General Partner in accordance with its percentage
interest and (y) to the unitholders holding common units, pro rata,
a percentage equal to 100% less the General Partners percentage
interest, until there has been distributed in respect of each common
unit then outstanding an amount equal to the cumulative common unit
arrearage existing with respect to such quarter;
third
, (x) to the General Partner in accordance with its percentage
interest and (y) to the unitholders holding subordinated units, pro
rata, a percentage equal to 100% less the General Partners
percentage interest, until there has been distributed in respect of
each subordinated unit then outstanding an amount equal to the
minimum quarterly distribution for such quarter;
fourth
, to the General Partner and all unitholders, in accordance
with their respective percentage interests, until there has been
distributed in respect of each unit then outstanding an amount equal
to the excess of the first target distribution over the minimum
quarterly distribution for such quarter;
fifth
, (A) to the General Partner in accordance with its percentage
interest; (B) 13% to the holders of the incentive distribution
rights, pro rata; and (C) to all unitholders, pro rata, a percentage
equal to 100% less the sum of the percentages applicable to
subclauses (A) and (B) of this clause until there has been
distributed in respect of each unit then outstanding an amount equal
to the excess of the second target distribution over the first
target distribution for such quarter;
sixth
, (A) to the General Partner in accordance with its percentage
interest, (B) 23% to the holders of the incentive distribution
rights, pro rata; and (C) to all unitholders, pro rata, a percentage
equal to 100% less the sum of the percentages applicable to
subclauses (A) and (B) of this clause, until there has been
distributed in respect of each unit then outstanding an amount equal
to the excess of the third target distribution over the second
target distribution for such quarter; and
13
thereafter, (A) to the General Partner in accordance with its
percentage interest; (B) 48% to the holders of the incentive
distribution rights, pro rata; and (C) to all unitholders, pro rata,
a percentage equal to 100% less the sum of the percentages described
in the first two bullet points.
Distributions of Available Cash from Operating Surplus after the Subordination
Period.
Assuming we do not issue additional classes of equity securities, the Partnership
Agreement requires that KGS makes distributions of Available Cash from operating surplus
for any quarter after the subordination period in the following manner:
first
, 100% to the General Partner and the unitholders in
accordance with their respective percentage interests, until
there has been distributed in respect of each unit then
outstanding an amount equal to the minimum quarterly
distribution for such quarter;
second
, 100% to the General Partner and the unitholders in
accordance with their respective percentage interests, until
there has been distributed in respect of each unit then
outstanding an amount equal to the excess of the first target
distribution over the minimum quarterly distribution for such
quarter;
third
, (A) to the General Partner in accordance with its
percentage interest; (B) 13% to the holders of the incentive
distribution rights, pro rata; and (C) to all unitholders,
pro rata, a percentage equal to 100% less the sum of the
percentages described in the first two bullet points, until
there has been distributed in respect of each unit then
outstanding an amount equal to the excess of the second
target distribution over the first target distribution for
such quarter;
fourth
, (A) to the General Partner in accordance with its
percentage interest; (B) 23% to the holders of the incentive
distribution rights, pro rata; and (C) to all unitholders,
pro rata, a percentage equal to 100% less the sum of the
percentages described in the first two bullet points, until
there has been distributed in respect of each unit then
outstanding an amount equal to the excess of the third target
distribution over the second target distribution for such
quarter; and
thereafter
, (A) to the General Partner in
accordance with its percentage interest; (B)
48% to the holders of the incentive
distribution rights, pro rata; and (C) to all
unitholders, pro rata, a percentage equal to
100% less the sum of the percentages
described in the first two bullet points.
4. NET INCOME PER COMMON AND SUBORDINATED
KGS net income is allocated to the General Partner and the limited partners,
including the holders of the subordinated units, in accordance with their respective
ownership percentages, after giving effect to incentive distributions paid to the General
Partner. Basic and diluted net income per limited partner unit is calculated by dividing
limited partners interest in net income by the weighted average number of outstanding
limited partner units during the period.
Basic earnings per unit is computed by dividing net earnings attributable to
unitholders by the weighted average number of units outstanding during each period.
However, because the IPO was completed on August 10, 2007, the number of units issued in
connection with the IPO is utilized for the 2007 periods presented. Diluted earnings per
unit reflects the potential dilution of common equivalent units that could occur if
securities or other contracts to issue common units were exercised or converted into common
units. The calculation of the basic and diluted net income per common and subordinated
unit are the same for the current period as distributable cash flow is greater than net
income.
5. PROPERTY, PLANT AND EQUIPMENT AND ASSET RETIREMENT OBLIGATIONS
Property, plant and equipment consist of the following:
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Depreciable
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|
Life
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|
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September 30, 2007
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December 31, 2006
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(in thousands)
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Gathering and transportation systems
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20 years
|
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$
|
89,364
|
|
|
$
|
36,572
|
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Processing plants
|
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20-25 years
|
|
|
104,055
|
|
|
|
53,035
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|
Rights-of-way and easements
|
|
20 years
|
|
|
25,456
|
|
|
|
13,135
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|
Construction in progress
|
|
|
|
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17,766
|
|
|
|
31,612
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|
|
|
|
|
|
|
|
|
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|
|
|
|
|
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|
|
236,641
|
|
|
|
134,354
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Less: accumulated depreciation
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(8,816
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)
|
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|
(3,563
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)
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|
|
|
|
|
|
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|
Net property, plant and equipment
|
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|
|
|
|
$
|
227,825
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|
|
$
|
130,791
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|
|
|
|
|
|
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|
14
Asset Retirement Obligations
A reconciliation of KGS liability for asset retirement
obligations is as follows:
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Nine Months Ended September 30,
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|
|
2007
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|
|
2006
|
|
|
|
(in thousands)
|
|
Beginning asset retirement obligations
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|
$
|
503
|
|
|
$
|
29
|
|
Additional liability incurred
|
|
|
1,336
|
|
|
|
451
|
|
Accretion expense
|
|
|
54
|
|
|
|
15
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Ending asset retirement obligations
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|
$
|
1,893
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|
|
$
|
495
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|
|
|
|
|
|
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As of September 30, 2007, no assets are legally restricted for use in settling asset
retirement obligations.
6. RELATED PARTY TRANSACTIONS
Upon completion of the IPO, KGS entered into a number of agreements with related parties. A
description of those agreements follows.
Omnibus Agreement
On August 10, 2007, in connection with the closing of the IPO, KGS entered
into an omnibus agreement (the Omnibus Agreement) with the General Partner and Quicksilver. The
Omnibus Agreement addresses, among other matters, the following:
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restrictions on Quicksilvers ability to engage in certain midstream business
activities or own certain related assets in eight specified counties in North Texas
referred to in our Registration Statement on Form S-1 (No. 333-140599) as the Quicksilver
Counties;
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Quicksilvers right to construct and operate pipeline assets in the Lake Arlington
area of Tarrant County, Texas and in Hill County, Texas, and KGS obligation to purchase
those assets from Quicksilver at their fair market value within two years after the assets
commence commercial service;
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KGS obligation to reimburse Quicksilver for all expenses incurred by Quicksilver (or
payments made on KGS behalf) in conjunction with Quicksilvers provision of general and
administrative services to KGS, including salary and benefits of Quicksilver personnel,
KGS public company expenses, general and administrative expenses and salaries and benefits
of KGS executive management who are Quicksilvers employees;
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KGS obligation to reimburse Quicksilver for all insurance coverage expenses it
incurs or payments it makes with respect to KGS assets; and
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Quicksilvers obligation to indemnify KGS for certain liabilities and KGS obligation
to indemnify Quicksilver for certain liabilities.
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Services and Secondment Agreement
On August 10, 2007, in connection with the closing of the
IPO, Quicksilver and the General Partner entered into a services and secondment agreement (the
Secondment Agreement) pursuant to which specified employees of Quicksilver are seconded to the
General Partner to provide operating, routine maintenance and other services with respect to the
gathering and processing assets that are owned and operated by KGS, under the direction,
supervision and control of the General Partner. Under the Secondment Agreement, the General Partner
will reimburse Quicksilver for the services provided by the seconded employees. The initial term of
the Secondment Agreement will be 10 years. The term will extend for additional twelve month periods
unless either party provides 180 days written notice to the other party prior to the expiration of
the applicable twelve month period. The General Partner may terminate the agreement upon 180 days
written notice.
Gas Gathering and Processing Agreement
On August 10, 2007, Quicksilver, Cowtown Gas
Processing Partners LP (Processing Partners) and Cowtown Pipeline Partners LP (Pipeline
Partners) and together with Processing Partners (the Cowtown Partnerships) entered into the
Fifth Amended and Restated Gas Gathering and Processing Agreement. In connection with the
completion of the IPO, Processing Partners and Pipeline Partners became indirect wholly-owned
subsidiaries of KGS. Under the Gas Gathering and Processing Agreement, Quicksilver has agreed, for
a primary term of 10 years, to dedicate and deliver for processing all of the natural gas owned or
controlled by Quicksilver and lawfully produced from existing and future
15
wells drilled within the Quicksilver Counties or lands pooled therewith. Notwithstanding the ten year dedication,
Quicksilver has made no commitment to KGS that it will develop the reserves subject to the Gas
Gathering and Processing Agreement. However, a memorandum of Quicksilvers obligations under the
Gas Gathering and Processing Agreement will be filed of record in the Quicksilver Counties and
therefore would survive any direct or indirect transfer by Quicksilver of its right, title or
interest associated with its natural gas production in the Quicksilver Counties.
Under the Gas Gathering and Processing Agreement, KGS provides gathering and processing
services, respectively, for a fixed fee. Quicksilver has agreed to pay $0.40 per MMBtu gathered by
the Cowtown Pipeline and $0.50 per MMBtu processed by the Cowtown Plant, each subject to annual
escalation tied to the consumer price index.
As discussed under Repurchase Obligations to Parent in Note 2, KGS has the option to
purchase the Cowtown Pipeline Assets from Quicksilver at historical cost within two years after
those assets commence commercial service.
If KGS determines that the gathering or processing of any natural gas from Quicksilvers
wells is or has become uneconomical, KGS will not be obligated to gather and process Quicksilvers
production from those wells so long as the uneconomical conditions exist. In the event that the
Cowtown Partnerships are unable to provide either gathering or processing services, Quicksilver may
dispose of the natural gas not gathered or processed as it so determines. In the event that the
Cowtown Partnerships are unable to provide either gathering or processing services for a period of
60 consecutive days, for reasons other than force majeure, causing Quicksilvers wells to be
shut-in (in the case of gathering) or resulting in Quicksilvers inability to by-pass the Cowtown
Plant and deliver its natural gas production to an alternative pipeline (in the case of
processing), Quicksilver has the right, upon 30 days prior notice, to terminate the Gas Gathering
and Processing Agreement as it relates to the affected gas.
The Gas Gathering and Processing Agreement has a primary term of 10 years, which expires
in 2017, and will be automatically renewed for one year periods unless the Cowtown Partnerships or
Quicksilver provide written notice of termination on or before 90 days prior to the expiration of
the primary term or the one year renewal period, as applicable. In addition, if the Gas Gathering
and Processing Agreement, or performance under this agreement, becomes subject to FERC
jurisdiction, the agreement would terminate pursuant to its terms, unless the parties agree within
30 days of such termination to continue the agreement.
Contribution, Conveyance and Assumption Agreement
On August 10, 2007, in connection with the
completion of the IPO, KGS entered into a contribution, conveyance, and assumption agreement
(Contribution Agreement) with the General Partner, certain other affiliates of Quicksilver and
the Private Investors. Immediately prior to the completion of the IPO, the following transactions,
among others, occurred pursuant to the Contribution Agreement:
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the transfer of all of the interests in Pipeline Partners and Processing Partners to KGS and its subsidiaries;
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the issuance of the incentive distribution rights to the General Partner and the continuation of its 2.0%
General Partner interest in KGS;
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KGS issuance of 5,696,752 common units, 11,513,625 subordinated units and the right to receive $162.1 million,
to Holdings in exchange for the contributed interests; and
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KGS issuance of 816,873 common units and the right to receive $7.7 million to the Private Investors in exchange
for the contributed interests.
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Centralized cash management
Quicksilver provided certain cash management activities for the
KGS Predecessor since the inception of the KGS Predecessors business in 2004, including the
settlement of revenue and expense transactions with the Parent and payments made to or received
from third parties by the Parent on behalf of KGS Predecessor. Prior to completion of the IPO on
August 10, 2007 revenues settled with the Parent and other customers, net of expenses paid by the
Parent on behalf of KGS Predecessor, are reflected as a reduction of net parent equity on the
Condensed Consolidated Balance Sheets and as a reduction of net cash provided by financing activities on the
Condensed Consolidated Statements of Cash Flows. Subsequent to completion of the IPO, revenues settled and
expenses paid on behalf of KGS are settled in cash on a monthly basis utilizing KGS bank accounts.
Services to affiliates
KGS routinely conducts business with the Parent and its affiliates.
The related transactions result primarily from fee-based arrangements for gathering and processing
of natural gas.
Allocation of costs
The individuals supporting KGS operations are employees of the Parent.
KGS unaudited condensed consolidated interim financial statements include costs allocated to KGS by the
Parent for centralized general and administrative services performed by the Parent, as well as
depreciation of assets utilized by the Parents centralized general and administrative functions.
Costs allocated to KGS are based on identification of the Parents resources which directly benefit
KGS and its estimated usage of shared resources and functions. All of the allocations are based on
assumptions that management believes are reasonable.
16
The following table summarizes the change in net parent equity upon completion of the IPO.
Management believes these transactions are executed on terms comparable to those that would apply
to transactions executed with third parties.
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Nine Months Ended
|
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September 30,
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|
(in thousands)
|
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|
2007
|
|
|
2006
|
|
Net parent equity
|
|
|
|
|
|
|
|
|
Beginning balance
|
|
$
|
118,652
|
|
|
$
|
48,949
|
|
Net change in parent advances:
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|
|
|
|
|
|
|
|
Contribution of property, plant and equipment
|
|
|
45,040
|
|
|
|
53,818
|
|
Distribution to parent
|
|
|
|
|
|
|
(4,506
|
)
|
Settled revenue with parent
|
|
|
(11,760
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)
|
|
|
(9,989
|
)
|
Payments received by parent for trade accounts receivable
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|
|
(625
|
)
|
|
|
|
|
Payments made to settle expenses by parent
|
|
|
4,378
|
|
|
|
5,361
|
|
Allocation of general and administrative overhead
|
|
|
850
|
|
|
|
455
|
|
Contribution of other current assets
|
|
|
162
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Net change in parent advances
|
|
|
38,045
|
|
|
|
45,139
|
|
|
|
|
|
|
|
|
|
|
Parent share of net income
|
|
|
3,119
|
|
|
|
1,255
|
|
Distribution of initial public offering proceeds
|
|
|
(112,112
|
)
|
|
|
|
|
Distribution of subordinated note payable to parent
|
|
|
(50,000
|
)
|
|
|
|
|
Reclassify to receivable from parent
|
|
|
2,296
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Ending balance
|
|
$
|
|
|
|
$
|
95,343
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
General and administrative expense parent
|
|
|
|
|
|
|
|
|
Allocation of general and administrative overhead
|
|
$
|
1,576
|
|
|
$
|
455
|
|
Management fee
|
|
|
|
|
|
|
120
|
|
Audit, insurance expense and other
|
|
|
777
|
|
|
|
258
|
|
|
|
|
Total general and administrative expense parent
|
|
$
|
2,353
|
|
|
$
|
833
|
|
|
|
|
7. LONG-TERM DEBT
Credit Agreement
On August 10, 2007, KGS entered into a five-year $150 million senior
secured revolving credit facility (Credit Agreement), with options exercisable by KGS to extend
the facility for up to two additional years and increase the facility up to $250 million, with the
consent of the lenders. The Credit Agreement provides for revolving credit loans, swingline loans
and letters of credit. Borrowings under the facility are guaranteed by KGS subsidiaries and are
secured by substantially all of the assets of KGS and each of its subsidiaries. KGS interest rate
options under the facility include the London InterBank Offered Rate (LIBOR) and U.S. prime for
revolving loans and a specified rate for swingline loans. Each interest rate option includes a
margin which increases in specified increments in tandem with an increase in KGS leverage ratio.
KGS must maintain certain financial ratios that can limit KGS borrowing capacity. The Credit
Agreement contains certain restrictive covenants which, among other things, require the maintenance
(measured quarterly) of a maximum leverage ratio of debt (which excludes the subordinated note
payable to parent and KGS obligations to repurchase certain pipeline and gathering assets from
Quicksilver, described above) to Consolidated EBITDA (as defined in the Credit Agreement) and a
minimum ratio of Consolidated EBITDA to interest expense (excluding capitalized interest on the
subordinated note payable to parent and non-cash interest expense with respect to KGS obligations
to repurchase the pipeline and gathering assets described above). At October 31, 2007, KGS
borrowing capacity was $66.8 million, as limited by the facilitys leverage ratio test. The Credit
Agreement prohibits the declaration or payment of distributions by KGS if an event of default then
exists or would result therefrom. The Credit Agreement also contains events of default that permit,
among other things, the acceleration of the loans, the termination of the credit facility and
foreclosure on collateral. KGS was in compliance with all such covenants as of September 30, 2007.
As of September 30, 2007, there are no outstanding borrowings under the Credit
Agreement
.
Subordinated Promissory Note to Parent
On August 10, 2007, KGS executed a subordinated
promissory note (the Subordinated Note) payable to Quicksilver in the principal amount of
$50.0 million. The indebtedness outstanding under the
17
Subordinated Note represents a return of
capital to Quicksilver in respect of investments that it previously made in certain subsidiaries of
KGS.
The Subordinated Note accrues interest based upon LIBOR plus (i) the applicable margin for
LIBOR revolving loans (as determined pursuant to the Credit Agreement) and (ii) 1.0% per annum. As
the leverage ratio calculated in accordance with the Credit Agreement increases, the LIBOR margins
increase in specified increments. Such accrued and unpaid interest is payable quarterly on the last
business day of each calendar quarter, beginning on March 31, 2008, and on the Subordinated Notes
maturity date described below. Quarterly interest may be paid in cash or by adding it to the
outstanding principal balance of the Subordinated Note. The aggregate unpaid principal amount of
the Subordinated Note will be due and payable in equal consecutive quarterly installments of
$275,000 on the last business day of each calendar quarter, beginning on March 31, 2008, with the
final payment of the then-remaining balance of the aggregate principal amount of the Subordinated
Note due on the Subordinated Notes maturity date, February 10, 2013. However, if the maturity date
of the Credit Agreement is extended pursuant to the extension options described above, the maturity
date of the Subordinated Note will also be automatically extended to the date that is six months
after the Credit Agreement maturity date as so extended. All amounts payable pursuant to the
Subordinated Note may, at the election of Quicksilver, be paid, in whole or in part, using equity
interests of KGS or the proceeds from the contemporaneous sale of equity interest of KGS. The
Subordinated Note contains events of default that permit, among other things, the acceleration of
the debt (unless otherwise prohibited pursuant to the subordination provisions described below),
such events of default including, but not limited to, payment defaults under the Subordinated Note,
the breach of certain covenants after applicable grace periods, and the occurrence of an event of
default under the Credit Agreement.
Amounts due under the Subordinated Note are subordinated in right of payment to all
obligations of KGS and its subsidiaries under the Credit Agreement and related loan documents.
8. COMMITMENTS AND CONTINGENT LIABILITIES
Litigation
At September 30, 2007, KGS was not subject to any material lawsuits or other
legal proceedings.
Casualties or Other Risks
The Parent maintains coverage in various insurance programs on
KGS behalf, which provides it with property damage, business interruption and other coverages
which are customary for the nature and scope of its operations.
Management believes that the Parent has adequate insurance coverage, although insurance will
not cover every type of loss that might occur. As a result of insurance market conditions, premiums
and deductibles for certain insurance policies have increased substantially and, in some instances,
certain insurance may become unavailable, or available for only reduced amounts of coverage. As a
result, the Parent may not be able to renew existing insurance policies or procure other desirable
insurance on commercially reasonable terms, if at all. KGS is currently considering the purchase of its own
directors and officers insurance policy separate from the policy maintained by the Parent
If KGS were to incur a significant loss for which it was not fully insured, the loss could
have a material impact on its consolidated financial condition and results of operations. In
addition, the proceeds of any available insurance may not be paid in a timely manner and may be
insufficient if such an event were to occur. Any event that interrupts the revenues generated by
KGS, or which causes KGS to make significant expenditures not covered by insurance, could reduce
its ability to meet its financial obligations.
In May 2007, an accident occurred at the Cowtown Plant that resulted in the death of a
Quicksilver employee. Although Quicksilver has agreed to indemnify us for any liability that may
arise out of this accident, similar events could occur in the future and we could be liable for
damages arising out of such events.
Regulatory Compliance
In the ordinary course of business, KGS is subject to various laws and
regulations. In the opinion of management, compliance with these laws and regulations will not have
a material adverse effect on KGS financial condition or results of operations.
Environmental Compliance
The operation of pipelines, plants and other facilities for
gathering, transporting, processing, treating or storing natural gas, NGLs and other products is
subject to stringent and complex laws and regulations pertaining to health, safety, and the
environment. As an owner or operator of these facilities, KGS must comply with United States laws
and regulations at the federal, state and local levels that relate to air and water quality,
hazardous and solid waste management and disposal, and other environmental matters. The cost of
planning, designing, constructing and operating pipelines, plants, and other facilities must
incorporate compliance with environmental laws and regulations and safety standards. Failure to
comply with these laws and regulations may trigger a variety of administrative, civil and
potentially criminal enforcement measures, including citizen suits, which can include the
assessment of monetary penalties, the imposition of remedial requirements, and the issuance of
18
injunctions or restrictions on operation. Management believes that, based on currently known
information, compliance with these laws and regulations will not have a material adverse effect on
KGS consolidated financial condition or results of operations. At September 30, 2007, KGS had no
liabilities recorded for environmental matters.
Commitments
KGS has agreements with the Parent and other third parties to provide gathering
and processing of natural gas and the delivery of natural gas and NGLs for sale in the Fort Worth
Basin. The terms of these agreements range in length from one to 10 years. The Parent has dedicated
to KGS all of the Parents existing and future natural gas production for a period of 10 years from
August 10, 2007, subject to automatic renewal for one year periods unless a party gives notice of
termination at least 90 days prior to the end of the current term, from the Fort Worth Basin
counties in which it currently owns acreage. If KGS is not in operation for 60 consecutive days for
reasons other than force majeure, the Parent would be entitled to elect, upon 30 days prior
notice, to terminate its gas gathering and processing agreement and divert the affected gas to a
third party for gathering and processing.
Additionally, KGS has agreements with a third party providing for the construction of natural
gas processing facilities. Payments are due to the third party upon completion of established
milestones related to the construction of the natural gas processing facilities. During the nine
months ended September 30, 2007, $7.7 million was paid to the third party. KGS estimates
additional payments of $1.3 million during 2007 will be made to the third party related to the
construction of the natural gas processing facilities. See Note 11 regarding Subsequent Events.
9. INCOME TAXES
In May 2006, the State of Texas enacted a margin tax that will become effective in 2007. This
margin tax will require KGS to pay a tax at a maximum effective rate of 0.7% of gross revenue
apportioned to Texas. The margin to which the tax rate will be applied generally will be calculated
as revenues for federal income tax purposes less the cost of the services sold for federal income
tax purposes. The statute limits the amount of revenues subject to tax to 70%. Under the provisions
of SFAS No. 109,
Accounting for Income Taxes
, KGS is required to record the effects on deferred
taxes for a change in tax rates or tax law in the period that includes the enactment date.
Under SFAS No. 109, taxes based on income like the Texas margin tax are accounted for using
the liability method under which deferred income taxes are recognized for the future tax effects of
temporary differences between the financial statement carrying amounts and the tax basis of
existing assets and liabilities using the enacted statutory tax rates in effect at the end of the
period. A valuation allowance for deferred tax assets is recorded when it is more likely than
not that the benefit from the deferred tax asset will not be realized.
As the temporary differences relating to KGS property will affect the Texas margin tax, a
deferred tax liability has been recorded in the amount of $0.1 million and $0.2 million as of
December 31, 2006 and September 30, 2007, respectively. A current tax liability has been recorded
in the amount of $0.2 million as of September 30, 2007 based on revenues for the nine-month period
ended September 30, 2007. KGS derives all of its revenue from operations in Texas.
10. EQUITY PLAN
Awards of phantom units have been granted under KGS 2007 Equity Plan, which permits the
issuance of up to 750,000 units. At time of grant, KGS determines whether the granted units will
be settled in cash or settled in KGS units. For awards payable in cash, KGS amortizes the expense
associated with the award over the vesting period. However the fair value of the phantom unit
grants is reassessed at every balance sheet date, with the vested portion of awards being adjusted
to reflect revised fair value via compensation expense. Phantom unit awards payable in units are
valued at the closing market price of KGS common units on the date of grant. The unearned
compensation is amortized to compensation expense over the vesting period of the phantom award.
The following table summarizes information regarding the phantom unit activity:
19
|
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|
|
|
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|
|
|
|
|
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|
|
Payable in cash
|
|
|
Payable in units
|
|
|
|
|
|
|
|
Weighted
|
|
|
|
|
|
|
Weighted
|
|
|
|
|
|
|
|
Average
|
|
|
|
|
|
|
Average
|
|
|
|
|
|
|
|
Grant Date
|
|
|
|
|
|
|
Grant Date
|
|
|
|
Shares
|
|
|
Fair Value
|
|
|
Shares
|
|
|
Fair Value
|
|
Number of unvested units
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Outstanding January 1, 2007
|
|
|
|
|
|
$
|
|
|
|
|
|
|
|
$
|
|
|
Vested
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Issued
|
|
|
84,961
|
|
|
|
21.36
|
|
|
|
9,833
|
|
|
|
21.36
|
|
Cancelled
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Unvested Phantom Units September 30, 2007
|
|
|
84,961
|
|
|
$
|
21.36
|
|
|
|
9,833
|
|
|
$
|
21.36
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
KGS recognized compensation expense of approximately $0.1 million during the three and nine
months periods ended September 30, 2007. We have unearned compensation of $2.2 million at
September 30, 2007 which will be recognized in expense over the next 2.9 years.
11. SUBSEQUENT EVENTS
On October 11, 2007, KGS entered into a $25.7 million agreement with Exterran Energy Solutions
(Exterran) to engineer, design, construct, install, and test a 125 MMcf/d cryogenic gas
processing and liquid hydrocarbon recovery facility in the Fort Worth Basin. Payments are due to
Exterran upon completion of established milestones related to the construction of the natural gas
processing facility. Additionally, on October 31, 2007, KGS has
entered into a $21.9 million agreement with EFX Compression Enerflex
(Enerflex) to provide natural gas compression equipment
for the natural gas processing facility. Payments are due to Enerflex
upon completion of established milestones related to the
manufacturing and delivery of the natural gas compression equipment. The total cost of the gas processing facility is expected to
be approximately $81.0 million and is scheduled to be placed into operation during
the first quarter of 2009.
******
20
ITEM 2. Managements Discussion and Analysis of Financial Condition and Results of Operations
Forward-Looking Information
Certain statements contained in this report and other materials we file with the SEC, or in
other written or oral statements made or to be made by us, other than statements of historical
fact, are forward-looking statements as defined in the Private Securities Litigation Reform Act
of 1995. Forward-looking statements reflect our current expectations or forecasts of future
events. Words such as may, assume, forecast, position, predict, strategy, expect,
intend, plan, estimate, anticipate, believe, project, budget, potential, or
continue, and similar expressions are used to identify forward-looking statements.
Forward-looking statements can be affected by assumptions used or by known or unknown risks or
uncertainties. Consequently, no forward-looking statements can be guaranteed. Actual results may
vary materially. You are cautioned not to place undue reliance on any forward-looking statements.
You should also understand that it is not possible to predict or identify all such factors and
should not consider the following list to be a complete statement of all potential risks and
uncertainties. Factors that could cause our actual results to differ materially from the results
contemplated by such forward-looking statements include:
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changes in general economic conditions;
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fluctuations in natural gas prices;
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failure or delays in the Parent and third parties achieving expected production from
natural gas projects;
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competitive conditions in our industry;
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actions taken by third-party operators, processors and transporters;
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changes in the availability and cost of capital;
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operating hazards, natural disasters, weather-related delays, casualty losses and other
matters beyond our control;
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construction costs or capital expenditures exceeding estimated or budgeted costs or
expenditures;
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the effects of existing and future laws and governmental regulations;
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the effects of future litigation; and
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factors discussed in our Registration Statement on Form S-1 (No. 333-140599).
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All forward-looking statements are expressly qualified in their entirety by the foregoing
cautionary statements.
Overview
We are a growth-oriented Delaware limited partnership engaged in the business of gathering and
processing natural gas produced from the Barnett Shale geologic formation of the Fort Worth Basin
located in North Texas. We began operations in 2004 to provide these services primarily to
Quicksilver, the owner of our General Partner, as well as other natural gas producers in this area.
During the third quarter of 2007, approximately 75% of our total natural gas gathering and
processing volumes were comprised of natural gas owned or controlled by Quicksilver.
Our Operations
The results of our operations are determined primarily by the volumes of natural gas gathered
and processed through our gathering and processing systems. We gather and process natural gas
pursuant to arrangements generally categorized as fee-based contracts. Under these arrangements,
we are entitled to receive fixed fees for performing the gathering and processing services. We do
not take title to the natural gas and associated natural gas liquids, or NGLs, that we gather and
process and are therefore able to avoid direct commodity price exposure. However, a sustained
decline in commodity prices could result in a decline in volumes produced by our customers and a
resulting decrease in our revenues. These fee-based contracts provide stable cash flows, but
minimal, if any, upside in higher commodity price environments. For the nine month periods ended
September 30, 2007 and September 30, 2006, these arrangements accounted for 100% of our natural gas
volumes.
How We Evaluate Our Operations
Our management uses a variety of financial and operational measurements to analyze our
performance. We view these measurements as important factors affecting our profitability and review
these measurements on a monthly basis for consistency
21
and trend analysis. On a company-wide basis,
these measures include volumes, adjusted gross margin, operating expenses and EBITDA.
Volume
We must continually obtain new supplies of natural gas to maintain or increase
throughput volumes on our gathering and processing systems. Our ability to maintain existing
supplies of natural gas and obtain new supplies is impacted by (1) the level of successful drilling
and production activity in areas currently dedicated to our systems, (2) our ability to compete
with other gas gathering and processing companies for volumes from successful new wells in other
areas, (3) our ability to obtain natural gas that has been released from other commitments and (4)
our pursuit of new opportunities where a limited number of gas gathering and processing companies
conduct business. We routinely monitor producer activity in the areas served by our gathering and
processing systems to pursue new supply opportunities.
Adjusted Gross Margin
We calculate adjusted gross margin as total revenues less operations
and maintenance expense and general and administrative expense. Adjusted gross margin information
is presented as a supplemental disclosure because it is a primary performance measure used by
management to evaluate the relationship between our gathering and processing revenues and our cost
of operating our facilities and our general and administrative overhead. Adjusted gross margin is
not a measure calculated in accordance with GAAP as it does not include deductions for cash
payments such as interest and capital expenditures which are necessary to maintain our business. As
an indicator of our operating performance, adjusted gross margin should not be considered an
alternative to, or more meaningful than, net income or cash flow as determined in accordance with
GAAP. Our adjusted gross margin may not be comparable to a similarly titled measure of another
company because other entities may not calculate adjusted gross margin in the same manner. See the
reconciliation of adjusted gross margin to net income in Results of Operations below.
Operating Expenses
Operating expenses are a separate measure that we use to evaluate
performance of field operations. These expenses are comprised primarily of direct labor, insurance,
property taxes, repair and maintenance expense, utilities and contract services, and are largely
independent of the volumes through our systems, but may fluctuate depending on the scale of our
operations during a specific period.
EBITDA
We calculate EBITDA as earnings before income taxes, interest expense, depreciation
and amortization. EBITDA is not a measure calculated in accordance with GAAP. EBITDA does not
include, among other things, deductions for cash payments such as interest and capital expenditures
which are necessary to maintain our business. EBITDA should not be considered as an alternative to
net income, income before taxes, cash flow from operating activities or any other measure of
financial performance presented in accordance with GAAP. We believe that EBITDA is a widely
accepted financial indicator of a companys ability to incur and service debt, fund capital
expenditures and make distributions. EBITDA calculations may vary among entities, so our
computation of EBITDA may not be comparable to EBITDA or similar measures of other entities. In
evaluating EBITDA, we believe that investors should consider, among other things, the amount by
which EBITDA exceeds interest costs, how EBITDA compares to principal payments on debt and how
EBITDA compares to capital expenditures for each period.
EBITDA is also used as a supplemental performance measure by our management and by external
users of our financial statements such as investors, commercial banks, research analysts and
others, to assess:
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financial performance of our assets without regard to financing methods, capital
structure or historical cost basis;
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|
our operating performance as compared to those of other companies in the midstream energy
industry without regard to financing methods, capital structure or historical cost
basis; and
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the viability of acquisitions and capital expenditure projects and the overall rates of
return on alternative investment opportunities.
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General Trends and Outlook
We expect our business to continue to be affected by the following key trends. Our
expectations are based on assumptions made by us and information currently available to us. To the
extent our underlying assumptions about or interpretations of available information prove to be
incorrect, our actual results may vary materially from our expected results.
Natural Gas Supply, Demand and Outlook
Natural gas continues to be a critical component of energy consumption in the United States.
According to the Energy Information Administration (the EIA), total annual domestic consumption
of natural gas is expected to increase from approximately 22.4 trillion cubic feet, or Tcf, in 2005
to approximately 23.4 Tcf in 2010. During the last three years, the United
22
States has on average consumed approximately 22.3 Tcf per year, while total marketed domestic production averaged
approximately 19.5 Tcf per year during the same period. The industrial and electricity generation
sectors currently account for the largest usage of natural gas in the United States.
We believe that current natural gas prices and the existing strong demand for natural gas will
continue to result in relatively high levels of natural gas-related drilling in the United States
as producers seek to increase their level of natural gas production. Although the natural gas
reserves in the United States have increased overall in recent years, a corresponding increase in
production has not been realized according to data obtained from the EIA. We believe that this lack
of increased production is attributable to insufficient pipeline infrastructure, the continued
depletion of existing wells and a tight labor and equipment market. We believe that an increase in
United States natural gas production, additional sources of supply such as liquid natural gas, and
imports of natural gas will be required for the natural gas industry to meet the expected increased
demand for natural gas in the United States.
The Barnett Shale formation of the Fort Worth Basin, in which we operate, is experiencing
significant drilling activity. Although we anticipate continued high levels of exploration and
production activity in the area in which we operate, fluctuations in energy prices can affect
production rates over time and levels of investment by third parties in exploration for and
development of new natural gas reserves. We have no control over the level of natural gas
exploration, production or development activity in our area of operations.
Impact of Interest Rates and Inflation
Interest rates have recently begun to increase after
reaching 50-year record lows. If interest rates continue to rise, our financing costs would
increase accordingly. Although this could limit our ability to raise funds in the capital markets,
we expect in this regard to remain competitive with respect to acquisitions and capital projects,
as our competitors would face similar circumstances.
Inflation in the United States has been relatively low in recent years and has not had a
material impact on our results of operations. Inflation may, in the future, however, increase the
cost to acquire or replace property, plant and equipment and may increase the costs of labor and
supplies. Our operating revenues and costs are influenced to a greater extent by price changes in
natural gas and NGLs. To the extent permitted by competition, regulation and our existing
agreements, we intend to continue to pass along increased costs to our customers in the form of
higher fees.
Items Impacting Comparability of Our Financial Results
Our historical results of operations for the periods presented may not be comparable, either
from period to period or going forward, for the reasons described below:
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Quicksilvers Barnett Shale operations began in 2004 and have subsequently grown
significantly.
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our facilities and operations have been in a startup phase, and we have incurred expenses
that we do not expect to be recurring.
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expenses are largely independent of gathering and processing volumes and are more
directly related to the capacity of our facilities and operations.
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revenues have been dependent on Quicksilvers ability to connect wells to our system.
|
Critical Accounting Policies and Estimates
Accounting principles generally accepted in the United States require management to make
estimates and judgments that affect the amounts reported in the financial statements and notes.
These estimates and judgments are based on information available at the time such estimates and
judgments are made. For the periods covered by the unaudited condensed consolidated interim financial
statements included in this report, these estimates and judgments affected, among other amounts,
the following:
Depreciation Expense and Cost Capitalization Policies.
Our assets consist primarily of
natural gas gathering pipelines, processing plants, and transmission pipelines. We capitalize all
construction-related direct labor and material costs plus the interest cost associated with
financing the construction of new facilities. These aggregate costs are then expensed over the
estimated useful life of the constructed asset through the recognition of depreciation expense.
23
As discussed in the Notes to the Condensed Consolidated Interim Financial Statements, depreciation of
our assets is generally computed using the straight-line method over the estimated useful life of
the assets. The cost of renewals and betterments that extend the useful life of property, plant and
equipment are also capitalized. The cost of repairs, replacements and maintenance projects are
expensed as incurred.
The computation of depreciation expense requires judgment regarding the estimated useful lives
and salvage value of assets. As circumstances warrant, depreciation estimates are reviewed to
determine if any changes are needed. Such changes could involve an increase or decrease in
estimated useful lives or salvage values which would impact future depreciation expense.
Asset Retirement Obligations
KGS records the fair value of the liability for asset
retirement obligations in the period in which it is legally or contractually incurred. Upon
initial recognition of the asset retirement liability, an asset retirement cost is capitalized by
increasing the carrying amount of the long-lived asset by the same amount as the liability. In
periods subsequent to initial measurement, the asset retirement cost is allocated to expense on a
straight line basis over the assets useful life. Changes in the liability for the asset
retirement obligation are recognized for (a) the passage of time and (b) revisions to either the
timing or the amount of the original estimate of undiscounted cash flows.
Results of Operations
Three Months Ended September 30, 2007 Compared with Three Months Ended September 30, 2006
.
The following table and discussion relates to our condensed consolidated results of operations for the
three months ended September 30, 2006 and 2007:
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|
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|
Three months ended September 30,
|
|
|
|
2007
|
|
|
2006
|
|
|
|
(in thousands)
|
|
Total revenues
|
|
$
|
10,282
|
|
|
$
|
4,073
|
|
Operations and maintenance expense
|
|
|
3,072
|
|
|
|
2,409
|
|
General and administrative expense
|
|
|
1,217
|
|
|
|
489
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Adjusted gross margin
|
|
|
5,993
|
|
|
|
1,175
|
|
|
|
|
|
|
|
|
|
|
Other income
|
|
|
114
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
EBITDA
|
|
|
6,107
|
|
|
|
1,175
|
|
Depreciation and amortization expense
|
|
|
2,188
|
|
|
|
1,032
|
|
Interest expense
|
|
|
1,728
|
|
|
|
|
|
Income tax provision
|
|
|
92
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
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|
|
Net income
|
|
$
|
2,099
|
|
|
$
|
143
|
|
|
|
|
|
|
|
|
|
|
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|
|
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Operating Data:
|
|
|
|
|
|
|
|
|
Daily throughput (MMcf)
|
|
|
98.2
|
|
|
|
40.9
|
|
|
|
|
|
|
|
|
|
|
Total throughput (Mcf)
|
|
|
9,031,571
|
|
|
|
3,762,661
|
|
Total Revenues
Total revenues increased $6.2 million, or 152%, to $10.3 million for the
three months ended September 30, 2007. This increase was due to the increase in Quicksilver and
third party customer production volumes in the Fort Worth Basin that we gathered and processed. At
September 30, 2007, Quicksilver had 193 wells connected to our system compared to 68 wells
connected to our system as of September 30, 2006. As a result,
Quicksilver increased its average daily production in the Fort Worth
Basin by 25.6 Mcf per day, or 93%, to 53.2 Mcf per day for the three
months ended September 30, 2007 compared to the three months ended
September 30, 2006.
Operations and Maintenance Expense
Operations and maintenance expense increased $0.7
million, or 28%, to $3.1 million for the three months ended September 30, 2007. The increase in
operating expenses is mainly due to the additional operating costs related to the natural gas
processing facility placed in service in March 2007 and the continued expansion of our natural gas
gathering system. Operating expense will likely increase in the future based on inflation and
facility expansion.
24
General and Administrative Expense
General and administrative expense increased $0.7
million, or 149%, to $1.2 million for the three months ended September 30, 2007. This increase was
primarily the result of the expansion of our operations and the resulting increase in
administrative and managerial personnel and related expenses to support that growth, as well as
costs attendant to the IPO
.
Adjusted Gross Margin
Adjusted gross margin increased $4.8 million, or more than 400%, to
$6.0 million for the three months ended September 30, 2007, primarily as a result of the increase
in revenues described above. As a percentage of revenues, adjusted gross margin has increased from
29% to approximately 58%, primarily due to the increase in revenues, but was partially offset by
operations and maintenance expense associated with our current scale of operations and higher
general and administrative expense.
Depreciation and Amortization Expense
Depreciation and amortization expense increased $1.2
million, or 112%, to $2.2 million for the three months ended September 30, 2007, primarily as a
result of the higher gross cost of property, plant and equipment as a result of capital
expenditures subsequent to September 30, 2006 made to expand our gathering network.
Interest
Expense
Interest expense of $1.7 million for the three
months ended September 30, 2007 was comprised of $1.0 million
related to the repurchase obligation to Parent and $0.7 million
related to the subordinated note payable to Parent.
Income
Tax Provision
Income tax expense of $0.1 million for the
three months ended September 30, 2007 relates to the State of Texas
margin tax which is generally calculated based on revenues for
federal income tax purposes less the cost of the services sold for
federal income tax purposes multiplied by the applicable rate.
Nine Months Ended September 30, 2007 Compared with Nine Months Ended September 30, 2006
.
The following table and discussion relates to our condensed consolidated results of operations for the
nine months ended September 30, 2006 and 2007:
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Nine months ended September 30,
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2007
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2006
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(in thousands)
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Total revenues
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$
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22,771
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$
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9,990
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Operations and maintenance expense
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8,063
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5,691
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General and administrative expense
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2,353
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833
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Adjusted gross margin
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12,355
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3,466
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Other income
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149
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EBITDA
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12,504
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3,466
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Depreciation and amortization expense
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5,307
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2,119
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Interest expense
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1,939
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Income tax provision
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189
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Net income
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$
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5,069
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$
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1,347
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Operating Data:
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Daily throughput (MMcf)
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73.3
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33.2
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Total throughput (Mcf)
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20,014,673
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9,054,755
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Total Revenues
Total revenues increased $12.8 million, or 128%, to $22.8 million for the
nine months ended September 30, 2007. This increase was due to the increase in Quicksilver and
third party customer production volumes in the Fort Worth Basin that we gathered and processed. At
September 30, 2007, Quicksilver had 188 wells connected to our system compared to 68 wells
connected to our system as of September 30, 2006. As a result,
Quicksilver increased its average daily production in the Fort Worth
Basin by 19.5 Mcf per day, or 85%, to 42.4 Mcf per day for the nine
months ended September 30, 2007 compared to the nine months ended
September 30, 2006.
Operations and Maintenance Expense
Operations and maintenance expense increased $2.4
million, or 42%, to $8.1 million for the nine months ended September 30, 2007. The increase in
operating expenses is mainly due to the additional
operating costs related to the natural gas processing facility placed in service in March 2007
and the continued expansion of our natural gas gathering system. Operating expense will likely
increase in the future based on inflation and facility expansion.
General and Administrative Expense
General and administrative expense increased $1.5
million, or 183%, to $2.4 million for the nine months ended September 30, 2007. This increase was
primarily the result of the expansion of our operations and the resulting increase in
administrative and managerial personnel and related expenses to support that growth, as well as
costs attendant to the IPO
.
25
Adjusted Gross Margin
Adjusted gross margin increased $8.9 million, or over 250%, to $12.4
million for the nine months ended September 30, 2007, primarily as a result of the increase in
revenues described above. As a percentage of revenues, adjusted gross margin has increased from 35%
to approximately 54%, primarily due to the increase in revenue, although partially offset by
increased operations and maintenance expense and general and administrative expense.
Depreciation and Amortization Expense
Depreciation and amortization expense increased $3.2
million, or 150%, to $5.3 million for the nine months ended September 30, 2007, primarily as a result of the higher gross cost of
property, plant and equipment as a result of capital expenditures subsequent to September 30, 2006.
Interest
Expense
Interest expense of $1.9 million for the nine
months ended September 30, 2007 was comprised of $1.2 million
related to the repurchase obligations to Parent and $0.7 million
related to the subordinated note payable to Parent.
Income
Tax Provision
Income tax expense of $0.2 million for the
nine months ended September 30, 2007 relates to the State of Texas
margin tax which is generally calculated based on revenues for
federal income tax purposes less the cost of the services sold for federal income tax purposes multiplied by the applicable rate.
Liquidity and Capital Resources
Historically, our sources
of liquidity have included cash generated from operations and equity
investments by our owners. Our sources of liquidity include:
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cash generated from operations;
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borrowings under our revolving credit facility;
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future debt offerings; and
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issuances of additional partnership units.
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We believe that the cash generated from these sources will be sufficient to meet our minimum
quarterly cash distributions and our requirements for short-term working capital and long-term
capital expenditures for the next twelve months.
Cash Flows
Since the inception of operations in 2004, KGS cash flows have been significantly influenced
by Quicksilvers production in the Fort Worth Basin as discussed below:
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At December 31, 2004, Quicksilver had produced only 103,339 Mcf in the Fort Worth Basin
for the year then ended, and there were only two wells connected to KGS system.
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At December 31, 2005, Quicksilver had produced 3,560,605 Mcf in the Fort Worth Basin for
the year then ended, all of which was gathered, processed and transported on KGS system,
and had 39 wells connected to KGS system. At December 31, 2005, we had invested
$53.8 million in KGS pipeline and plant assets.
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At December 31, 2006, Quicksilver had throughput of 13,495,818 Mcf on KGS system for the
year then ended, and had 88 wells connected to KGS system. The system consisted of
120 miles of gathering pipelines, a 22-mile NGL transportation pipeline and two operating
units which can process 200 MMcf/d of natural gas.
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Working Capital (Deficit)
Working capital is the amount by which current assets exceed
current liabilities and is a measure of our ability to pay our liabilities as they become due. Our
working capital (deficit) was ($.9) million at September 30, 2007 and ($4.9) million at
December 31, 2006. However, excluding liabilities associated with capital expenditures, our
working capital was $6.2 million and $1.7 million at these two dates, respectively.
The net increase in working capital of $4.0 million from December 31, 2006 to September 30,
2007 resulted primarily from cash on hand as a result of the IPO and the subsequent exercise of the
overallotment by the underwriters less the return of capital to Quicksilver and the Private
Investors. The increase was partially offset by an increase in accounts payable and other accrued
expenses.
Cash Flows from Operations
Cash flows from operations were $11.2 million for the nine months
ended September 30, 2007, an increase of $7.0 million, or 168%, from the nine months ended
September 30, 2006. The increase in operating cash flows during the nine months ended September 30,
2007 as compared to the nine months ended September 30, 2006 resulted primarily from increased
revenues and higher profitability associated with the services we provided to the increased
Quicksilver wells connected to our system, as well as the impact of higher non-cash expenses such
as depreciation.
Prior to the IPO, we used cash flows from operating activities together with capital
contributions and borrowings from Quicksilver for our working capital requirements, which include
operating expenses, maintenance capital expenditures and
26
expansion capital expenditures. Subsequent
to the IPO, we have used cash flow from operations and the proceeds from the IPO to fund working
capital requirements.
Cash Flows Used in Investing Activities
Cash flows used in investing activities were $55.2
million for the nine months ended September 30, 2007, an increase of $1.4 million or approximately
3% from the comparable 2006 period. This increase results from the higher capital expenditures
used to expand our transportation network and processing capabilities.
Cash Flows Provided by Financing Activities
Cash flows provided by financing activities were
$59.3 million for the nine months ended September 30, 2007, an increase of $9.7 million or
approximately 19% from the comparable 2006 period.
Cash flows provided by financing activities during the nine months ended September 30, 2007
primarily consisted of the proceeds from our IPO, contributions by Quicksilver and the Private
Investors prior to the IPO, borrowings from Quicksilver and proceeds from the sale of assets to
Quicksilver, offset by distributions to Quicksilver and the Private Investors and the payment of
offering costs and debt issuance costs. Cash flows provided by financing activities during the nine
months ended September 30, 2006 consisted of contributions to us by Quicksilver and by the Private
Investors.
Capital Expenditures
The midstream energy business can be capital intensive, requiring significant investment for
the acquisition or development of new facilities, particularly in emerging production areas such as
the Fort Worth Basin. We categorize our capital expenditures as either:
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expansion capital expenditures, which are made to construct additional assets, to expand
and upgrade existing systems, including compression, and facilities or to acquire additional
assets; or
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maintenance capital expenditures, which are made to replace partially or fully
depreciated assets, to maintain the existing operating capacity of our assets and extend
their useful lives or to maintain existing system volumes and related cash flows.
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Since our inception in 2004, we have made substantial expansion capital expenditures. We
anticipate that we will continue to make substantial expansion capital expenditures as Quicksilver
continues to expand its production efforts in the Fort Worth Basin. Consequently, our ability to
develop and maintain sources of funds to meet our capital requirements is critical to our ability
to meet our growth objectives.
We have budgeted approximately $90 million in capital expenditures for the year ending
December 31, 2007.
Our
budget for 2007 includes over $88.0 million of identified expansion capital expenditures and
approximately $2.0 million related to maintenance capital expenditures. These expenditures relate to
several projects scheduled for 2007, including the connection of approximately 189 new wells to our
gathering and transportation system, the recently completed connection of our 22-mile NGL pipeline
to the Louis Dreyfus pipeline and the progress payments to third parties for the new natural gas
processing unit at the Cowtown Plant. During the nine months ended September 30, 2007, we
recognized an increase of gross property, plant and equipment of $88.9 million, including expansion
capital expenditures of approximately $55.2 million and $33.7 million in capital expenditures
related to assets subject to the repurchase obligations to the Parent. We expect that the remaining
2007 budgeted expansion capital expenditures of $32.8 million will be funded with the remaining
proceeds from the IPO and from borrowings under our revolving credit facility.
Additionally, Quicksilver has the right to complete construction and to operate the new
gathering system for the Lake Arlington Dry System and the Hill County Dry System, which we are
obligated to purchase from Quicksilver at fair market value within two years after those assets
commence commercial service. We anticipate that the Lake Arlington Dry System and the Hill
County Dry System will be completed in 2008. After the Lake Arlington Dry System and the Hill
County Dry System commence commercial service, but prior to our purchase of those assets,
Quicksilver will engage us to operate those assets for a fee.
As
discussed in the Repurchase Obligations to Parent section of this Item 2, KGS has the
option to purchase the Cowtown Pipeline Assets from Quicksilver at historical cost within two years
after those assets commence commercial service. Quicksilver has engaged us to operate those assets
for a fee.
We continually review opportunities for both organic growth projects and acquisitions that
will enhance our financial performance. Since we will distribute most of our available cash to our
unitholders, we will depend on borrowings under our revolving credit facility and the issuance of
debt and equity securities to finance any future growth capital expenditures or acquisitions.
27
Revolving Credit Facility
Upon completion of the IPO, we entered into a $150 million senior secured revolving credit
facility. Our obligations under the credit agreement are secured by first priority liens on
substantially all of our assets, including a pledge of all of the equity interests of each of our
subsidiaries. Our obligations under the credit agreement are also guaranteed by all of our
subsidiaries and secured by first priority liens on substantially all of the assets of our
subsidiaries. The credit agreement requires us to maintain, as of the last day of each fiscal
quarter, a ratio of our Consolidated EBITDA (as defined in our credit agreement) to our net
interest expense, each measured for the preceding quarter, of not less than 2.5 to 1.0; and a ratio
of total indebtedness to Consolidated EBITDA of not more than 5.25 to 1.0 for quarters ending on
June 30, 2007 and September 30, 2007, 5.00 to 1.0 for quarters ending on December 31, 2007 and
March 31, 2008, 4.75 to 1.0 for quarters ending on June 30, 2008 and September 30, 2008, and 4.50
to 1.0 for quarters ending December 31, 2008 and thereafter. Furthermore, the credit agreement
contains various covenants that limit, among other things, our ability to:
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incur further indebtedness;
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grant liens;
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pay distributions; and;
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engage in transactions with affiliates.
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Any replacement of our revolving credit facility or any other new indebtedness could have
similar or greater restrictions.
Neither our repurchase obligations to Quicksilver or our obligations to Quicksilver under the
subordinated note described below, nor the capitalized or non-cash interest thereon, will be
included as indebtedness or interest expense for purposes of determining our compliance with the
covenants described above.
Subordinated Note
In connection with the completion of the IPO, we issued a $50.0 million subordinated note
payable to Quicksilver. The note bears interest at an initial rate of LIBOR plus 3.25% per annum
and is subject to the provisions described below:
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accrued and unpaid interest on the note will be due and payable quarterly on the last
business day of each calendar quarter, beginning on March 31, 2008, and on the maturity date
of the note, provided that such interest payments may be added to the outstanding principal
amount at any time when the payment of interest is prohibited pursuant to the subordination
provisions described below; and
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the principal amount of the note will be due and payable:
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in equal consecutive quarterly installments of $275,000 on the last business day of each
calendar quarter, beginning on March 31, 2008; plus
a final payment of the then-remaining balance of the aggregate principal amount of the note
on February 10, 2013, the maturity date of the note; provided, however, that in the event of
any extension of the maturity of our revolving credit facility, described above, the maturity
date of the note shall be the date that is six months after such revolving credit facilitys
maturity date.
Amounts due under the note will be subordinated in right of payment to all obligations under
the revolving credit facility. We will not be allowed to make any payments (other than interest
paid by adding such interest to the principal balance of the note or amounts paid using our equity
interests or the proceeds of issuance of our equity interests) under the note if any of the
following blockage events exists as of the date of, or would result from, the proposed subordinated
note payment:
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an event of default under the revolving credit facility;
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the existence of a pending judicial proceeding with respect to any event of default under
the revolving credit facility; or
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our ratio of total indebtedness (which includes the $50.0 million subordinated note
payable to Quicksilver) to Consolidated EBITDA (as determined in accordance with our
revolving credit facility) as of the end of the fiscal quarter immediately preceding the
date of such payment was equal to or greater than 3.5 to 1.0 or would be greater than 3.5 to
1.0 after giving pro forma effect to such payment.
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28
In light of these subordination features, we anticipate making all scheduled interest payments
on the subordinated note (by adding the interest to the principal amount); however, because we do
not expect to meet the financial ratio test described above until December 31, 2008, we anticipate
that we will begin making cash payments on the principal and interest after that date.
Repurchase Obligations to Parent
On June 5, 2007, KGS Predecessor sold several pipeline and gathering assets to Quicksilver.
These assets consist of gathering lines that are part of the Cowtown Pipeline Assets, the Lake
Arlington Dry System and the Hill County Dry System. The assets were either constructed and in
service or partially constructed. The selling price for these assets was approximately $29.5
million, which represents KGS Predecessors historical cost. KGS Predecessor collected the $29.5
million on August 9, 2007. The assets were conveyed to Quicksilver through a written assignment.
Cowtown Pipeline Assets Repurchase:
In accordance with the Gas Gathering and
Processing Agreement (the Gas Gathering and Processing Agreement) between KGS and Quicksilver,
KGS has the option to purchase the Cowtown Pipeline Assets from Quicksilver at historical cost
within two years after the Cowtown Pipeline Assets commence commercial service. The Cowtown
Pipeline Assets comprised $22.9 million of the total sale price to Quicksilver. Quicksilver
estimates that the total construction costs to complete these
pipelines will be approximately
$40.6 million, of which $31.8 million of costs had been incurred through September 30, 2007. A portion of the Cowtown Pipeline Assets have commenced commercial
service as of September 30, 2007.
Lake Arlington Dry System and Hill County Dry System Repurchases:
In accordance
with the Omnibus Agreement between KGS, the General Partner, and Quicksilver (the Omnibus
Agreement), KGS is obligated to purchase the Lake Arlington Dry System and the Hill County Dry
System from Quicksilver at fair market value within two years after those assets commence
commercial service. The Lake Arlington Dry System and the Hill County Dry System assets comprised
$3.6 million and $3.0 million, respectively, of the total sale price to Quicksilver of $29.5
million. Quicksilver estimates that the total construction costs to complete the Lake Arlington
Dry System and the Hill County Dry System will be approximately
$32.7 million and $49.4
million, respectively, of which $19.3 and $12.1 million of costs
had been incurred through September 30, 2007, respectively. A portion of the Hill County Dry
System assets has commenced commercial service as of September 30, 2006. The Lake Arlington Dry
System has not commenced commercial service as of
September 30, 2007.
As KGS has significant continuing involvement in the operation of the Cowtown Pipeline Assets,
the Lake Arlington Dry System and the Hill County Dry System and intends to exercise its purchase
rights, the conveyance of assets has not been treated as a sale for accounting purposes, such that
the original cost of $29.5 million and subsequently incurred costs of $33.7 million have been
included in both property, plant and equipment and repurchase obligations. Under the credit
agreement, neither the repurchase obligations, nor the imputed interest thereon, will be included
as indebtedness or interest expense for purposes of our compliance with the covenants. For the
period from June 5, 2007 through September 30, 2007, the imputed interest was calculated at 8.83%,
which was based upon the effective interest rate on the $50.0 million subordinated note payable to
Parent.
Total Contractual Cash Obligations
The following table summarizes our total contractual cash obligations as of September 30, 2007.
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Payments Due by Period
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Contractual Obligations
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Total
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2007
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2008-2010
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2011-2012
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Thereafter
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($ Millions)
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Long-Term Debt (including interest) (1)
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$
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50.6
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$
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1.1
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$
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3.3
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$
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2.2
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$
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44.0
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Repurchase Obligations to Parent (2)
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64.5
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Construction Commitments
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47.6
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3.5
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44.1
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Total Contractual Obligations (3)
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$
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162.7
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$
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4.6
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$
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47.4
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$
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2.2
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$
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44.0
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(1)
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With respect to the revolving credit facility, based on an interest rate of 7.83%, which is
the current LIBOR interest rate of 5.58% plus a margin of 2.25%. With respect to the $50.0
million subordinated note payable to Parent, based on an interest rate 8.83%, which is the
current LIBOR interest rate of 5.58% plus 3.25% per annum.
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(2)
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As described above under Repurchase Obligations to Parent, KGS is obligated to purchase
certain pipeline assets from Quicksilver at their fair market value within two years of their
commencement of commercial operation. The Repurchase
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29
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Obligations to Parent balance, of $64.5
million, includes $31.8 million related to Cowtown Assets that KGS has the option to purchase.
KGS cannot presently predict the deadline for completing the purchase of these assets or the
ultimate purchase price. KGS intends to exercise its purchase rights
related to these assets. The total estimated remaining to complete
the construction of the assets subject to the repurchase obligation
is approximately $59.5 million.
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(3)
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These amounts do not include the $90.0 million that KGS expects to spend in fiscal year 2007
for the construction of additions to its gathering system to connect new wells and the cost to
construct the third processing unit that KGS expects to become operational during the first
quarter of 2009, a portion of which is budgeted for fiscal year 2007 capital expenditures.
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Off-Balance Sheet Arrangements
KGS has no off-balance sheet arrangements.
Recently Issued Accounting Pronouncements
In September 2006, the FASB issued SFAS No. 157,
Fair Value Measurements
(SFAS 157).
SFAS 157 defines fair value, establishes a framework for measuring fair value in generally accepted
accounting principles (GAAP), and expands disclosures about fair value measurements. SFAS 157
applies under other accounting pronouncements that require or permit fair value measurements, where
the FASB concluded that fair value is the relevant measurement attribute. Accordingly, SFAS 157
does not require any new fair value measurements. SFAS 157 becomes effective for KGS on January 1,
2008. KGS has not yet determined the impact this pronouncement will have on its financial
statements.
In June 2006, the FASB issued Interpretation No. 48,
Accounting for Uncertainty in Income
Taxes an interpretation of FASB Statement No. 109
(FIN 48), which clarifies the accounting and
disclosure for uncertainty in tax provisions. FIN 48 seeks to reduce the diversity in practice
associated with certain aspects of the recognition and measurement related to accounting for income
taxes. This interpretation is effective for fiscal years beginning after December 15, 2006.
Interest and penalties, if incurred, would be recognized as components of interest expense. KGS
Predecessors adoption of FIN 48 on January 1, 2007 had no impact on its financial statements.
In February 2007, the FASB issued SFAS No. 159,
The Fair Value Option for Financial Assets and
Financial Liabilities, including an amendment of FASB Statement No. 115
(SFAS 159). SFAS 159
permits entities to measure many financial instruments and certain other assets and liabilities at
fair value. SFAS 159 is effective for KGS on January 1, 2008. KGS has not yet adopted SFAS 159 or
determined the impact this pronouncement will have on its financial statements.
In April 2007, the FASB issued FASB Staff Position (FSP) No. FIN 39-1,
Amendment of FASB
Interpretation No. 39
. The FSP amends paragraph 3 of FIN No. 39 to replace the terms conditional
contracts and exchange contracts with the term derivative instruments as defined in SFAS
No. 133,
Accounting for Derivative Instruments and Hedging Activities
. It also amends paragraph 10
of Interpretation 39 to permit a reporting entity to offset fair value amounts recognized for
derivative instruments executed with the same counterparty under the same master netting
arrangement that have been offset in accordance with that paragraph. The guidance in this FSP is
effective for KGS on January 1, 2008, at which time KGS will recognize the effects of applying this FSP as
a change in accounting principle through retrospective application for all financial statements
presented. KGS is evaluating the FSPs guidance, but does not believe its adoption will have a
material impact on its financial statements.
Item 3. Quantitative and Qualitative Disclosures About Market Risk
We have established policies and procedures for managing risk within our organization,
including internal controls. The level of risk assumed by us is based on our objectives and
capacity to manage risk.
Credit Risk
Our primary risk is that we are dependent on Quicksilver for almost all of our supply of
natural gas volumes, and are consequently subject to the risk of nonpayment or late payment by
Quicksilver for processing and transportation fees. Quicksilvers credit ratings are below
investment grade, and we expect its credit ratings to remain below investment grade for the
foreseeable future. Accordingly, this risk is higher than it would be with a more creditworthy
contract counterparty or with a more diversified group of customers; and, unless and until we
significantly increase our customer base, we expect to continue to be subject to significant and
non-diversified risk of nonpayment or late payment of our fees.
Interest Rate Risk
Interest rates have recently begun to increase after reaching 50-year record lows. If interest
rates continue to rise, our financing costs would increase accordingly. Although this could limit
our ability to raise funds in the capital markets, we expect in this
30
regard to remain competitive
with respect to acquisitions and capital projects, as our competitors would face similar
circumstances.
We are exposed to variable interest rate risk as a result of borrowings we may have under our
revolving credit facility and our Subordinated Note.
Item 4. Controls and Procedures
Conclusion Regarding the Effectiveness of Disclosure Controls and Procedures
We carried out an evaluation, under the supervision and with the participation of management,
including our Chief Executive Officer and Chief Financial Officer, of the effectiveness of the
design and operation of our disclosure controls and procedures as of the end of the period covered
by this report pursuant to Securities Exchange Act Rule 13a-15. Based upon that evaluation, our
Chief Executive Officer and Chief Financial Officer concluded that, as of the end of the third
quarter of 2007, our disclosure controls and procedures were effective to provide reasonable
assurance that material information required to be disclosed by us in reports that we file or
submit under the Securities Exchange Act is recorded, processed, summarized and reported within the
time periods specified in the SECs rules and forms and that information required to be disclosed
by us in the reports we file or submit under the Securities Exchange Act is accumulated and
communicated to our management, including our Chief Executive Officer and Chief Financial Officer,
as appropriate to allow timely decisions regarding required disclosure.
Changes in Internal Control Over Financial Reporting
There has been no change in our internal control over financial reporting during the quarter
ended September 30, 2007 that has materially affected, or is reasonably likely to materially
affect, our internal control over financial reporting.
31
PART II OTHER INFORMATION
Item 1A. Risk Factors
There have been no material changes in our risk factors from those disclosed in the
prospectus, dated August 6, 2007, relating to the IPO and filed with the SEC on August 7, 2007.
Item 2. Unregistered Sales of Equity Securities and Use of Proceeds
The effective date of KGS registration statement filed on Form S-1 under the Securities Act
of 1933 (File No. 333-140599) relating to KGS IPO of common units representing limited partner
interests was August 6, 2007. A total of 5,750,000 common units were registered and sold,
including 750,000 common units sold pursuant to the underwriters option to purchase additional
common units.
The sale of 5,000,000 common units was completed on August 10, 2007 and the sale of 750,000
units was completed on September 7, 2007. The aggregate offering price for the common units
registered and sold was $120.8 million. As of September 30, 2007, the aggregate underwriting
discounts were $7.9 million and KGS incurred $0.6 million of structuring fees and approximately
$2.7 million of other expenses in connection with the IPO, for total expenses of approximately
$11.2 million.
The proceeds to KGS, net of total expenses, were approximately $109.6 million. From August 6,
2007 to September 30, 2007, KGS used net proceeds of the IPO, together with cash on hand of $25.1
million, to: (i) distribute $162.1 million (consisting of $112.1 million in cash and a $50.0
million subordinated promissory note payable) to Quicksilver and $7.7 million in cash to the
Private Investors as a return of investment capital contributed and reimbursement for capital
expenditures advanced, (ii) pay $3.6 million of expenses associated with the IPO, the credit
agreement and certain formation transactions related to the IPO. KGS intends to use the remaining
net proceeds to pay expenses associated with the IPO, the credit agreement and certain formation
transactions related to the IPO and for general partnership purposes.
None of the underwriting discounts or other expenses incurred in connection with the IPO,
including the exercise of the underwriters option, were paid, directly or indirectly, to
directors, officers, general partners of KGS or their associates, to persons owning 10% or more of
any class of equity securities of KGS or to affiliates of KGS.
UBS Securities LLC and Goldman, Sachs & Co. acted as representatives of the underwriters and
as joint book-running managers of the IPO. A.G. Edwards & Sons, Inc., J.P. Morgan Securities Inc.
and Fortis Securities LLC acted as co-managers.
32
Item 6. Exhibits:
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Exhibit No.
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Description
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10.1
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Credit Agreement, dated as of August 10, 2007, among Quicksilver Gas Services LP
and the lenders and agents identified therein (filed as Exhibit 10.1 to the
Companys Form 8-K filed August 16, 2007 and included herein by reference).
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10.2
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Fifth Amended and Restated Gas Gathering and Processing Agreement, dated August
10, 2007, among Quicksilver Resources Inc., Cowtown Pipeline Partners L.P. and
Cowtown Gas Processing Partners L.P. (filed as Exhibit 10.6 to the Companys
Form 8-K filed August 16, 2007 and included herein by reference).
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10.3
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Omnibus Agreement, dated August 10, 2007, among Quicksilver Gas Services LP,
Quicksilver Gas Services GP LLC and Quicksilver Resources Inc. (filed as Exhibit
10.4 to the Companys Form 8-K filed August 16, 2007 and included herein by
reference).
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10.4
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2007 Equity Plan (filed as Exhibit 99.1 to the Companys Form S-8, File No.
333-145326, filed August 10, 2007 and included herein by reference).
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10.5
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Services and Secondment Agreement, dated August 10, 2007, between Quicksilver
Resources Inc. and Quicksilver Gas Services GP LLC (filed as Exhibit 10.5 to the
Companys Form 8-K filed August 16, 2007 and included herein by reference).
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10.6
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Contribution, Conveyance and Assumption Agreement, dated August 10, 2007, among
Quicksilver Gas Services LP, Quicksilver Gas Services GP LLC, Cowtown Gas
Processing L.P., Cowtown Pipeline L.P., Quicksilver Gas Services Holdings LLC,
Quicksilver Gas Services Operating GP LLC, Quicksilver Gas Services Operating
LLC and the private investors named therein (filed as Exhibit 10.3 to the
Companys Form 8-K filed August 16, 2007 and included herein by reference).
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10.7
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Form of Indemnification Agreement by and between Quicksilver Gas Services GP LLC
and its officers and directors (filed as Exhibit 10.7 to the Companys Form
S-1/A, File No. 333-140599, filed July 17, 2007 and included herein by
reference).
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10.8
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Form of Phantom Unit Award Agreement for Directors (3-year) (filed as Exhibit
10.8 to the Companys Form S-1/A, File No. 333-140599, filed July 17, 2007 and
included herein by reference).
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10.9
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Form of Phantom Unit Award Agreement for Directors (1-year) (filed as Exhibit
10.9 to the Companys Form S-1/A, File No. 333-140599, filed July 17, 2007 and
included herein by reference).
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10.10
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Form of Phantom Unit Award Agreement for Non-Directors (Cash) (filed as Exhibit
10.10 to the Companys Form S-1/A, File No. 333-140599, filed July 17, 2007 and
included herein by reference).
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10.11
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Form of Phantom Unit Award Agreement for Non-Directors (Units) (filed as Exhibit
10.11 to the Companys Form S-1/A, File No. 333-140599, filed July 25, 2007 and
included herein by reference).
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10.12
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Subordinated Promissory Note, dated as of August 10, 2007, made by Quicksilver
Gas Services LP payable to the order of Quicksilver Resources Inc. (filed as
Exhibit 10.2 to the Companys Form 8-K filed August 16, 2007 and included herein
by reference).
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*31.1
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Certification Pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.
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*31.2
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Certification Pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.
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*32.1
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Certification Pursuant to 18 U.S.C. Section 1350, as Adopted Pursuant to Section
906 of the Sarbanes-Oxley Act of 2002.
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33
SIGNATURES
Pursuant to the requirements of the Securities Exchange Act of 1934, the registrant has duly
caused this report to be signed on its behalf by the undersigned thereunto duly authorized.
Dated: November 9, 2007
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QUICKSILVER GAS SERVICES LP
By: QUICKSILVER GAS SERVICES GP LLC, its General Partner
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By:
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/s/ Thomas F. Darden
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Thomas F. Darden
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President and Chief Executive Officer
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By:
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/s/ Philip Cook
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Philip Cook
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Senior Vice President Chief Financial Officer
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34
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Exhibit No.
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Description
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10.1
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Credit Agreement, dated as of August 10, 2007, among Quicksilver Gas Services LP
and the lenders and agents identified therein (filed as Exhibit 10.1 to the
Companys Form 8-K filed August 16, 2007 and included herein by reference).
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10.2
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Fifth Amended and Restated Gas Gathering and Processing Agreement, dated August
10, 2007, among Quicksilver Resources Inc., Cowtown Pipeline Partners L.P. and
Cowtown Gas Processing Partners L.P. (filed as Exhibit 10.6 to the Companys
Form 8-K filed August 16, 2007 and included herein by reference).
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10.3
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Omnibus Agreement, dated August 10, 2007, among Quicksilver Gas Services LP,
Quicksilver Gas Services GP LLC and Quicksilver Resources Inc. (filed as Exhibit
10.4 to the Companys Form 8-K filed August 16, 2007 and included herein by
reference).
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10.4
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2007 Equity Plan (filed as Exhibit 99.1 to the Companys Form S-8, File No.
333-145326, filed August 10, 2007 and included herein by reference).
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10.5
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Services and Secondment Agreement, dated August 10, 2007, between Quicksilver
Resources Inc. and Quicksilver Gas Services GP LLC (filed as Exhibit 10.5 to the
Companys Form 8-K filed August 16, 2007 and included herein by reference).
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10.6
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Contribution, Conveyance and Assumption Agreement, dated August 10, 2007, among
Quicksilver Gas Services LP, Quicksilver Gas Services GP LLC, Cowtown Gas
Processing L.P., Cowtown Pipeline L.P., Quicksilver Gas Services Holdings LLC,
Quicksilver Gas Services Operating GP LLC, Quicksilver Gas Services Operating
LLC and the private investors named therein (filed as Exhibit 10.3 to the
Companys Form 8-K filed August 16, 2007 and included herein by reference).
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10.7
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Form of Indemnification Agreement by and between Quicksilver Gas Services GP LLC
and its officers and directors (filed as Exhibit 10.7 to the Companys Form
S-1/A, File No. 333-140599, filed July 17, 2007 and included herein by
reference).
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10.8
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Form of Phantom Unit Award Agreement for Directors (3-year) (filed as Exhibit
10.8 to the Companys Form S-1/A, File No. 333-140599, filed July 17, 2007 and
included herein by reference).
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10.9
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Form of Phantom Unit Award Agreement for Directors (1-year) (filed as Exhibit
10.9 to the Companys Form S-1/A, File No. 333-140599, filed July 17, 2007 and
included herein by reference).
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10.10
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Form of Phantom Unit Award Agreement for Non-Directors (Cash) (filed as Exhibit
10.10 to the Companys Form S-1/A, File No. 333-140599, filed July 17, 2007 and
included herein by reference).
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10.11
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Form of Phantom Unit Award Agreement for Non-Directors (Units) (filed as Exhibit
10.11 to the Companys Form S-1/A, File No. 333-140599, filed July 25, 2007 and
included herein by reference).
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10.12
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Subordinated Promissory Note, dated as of August 10, 2007, made by Quicksilver
Gas Services LP payable to the order of Quicksilver Resources Inc. (filed as
Exhibit 10.2 to the Companys Form 8-K filed August 16, 2007 and included herein
by reference).
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*31.1
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Certification Pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.
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*31.2
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Certification Pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.
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*32.1
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Certification Pursuant to 18 U.S.C. Section 1350, as Adopted Pursuant to Section
906 of the Sarbanes-Oxley Act of 2002.
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