e10vq
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 |
For the quarterly period ended September 30, 2008
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 |
For the transition period from to
Commission file number: 001-33801
APPROACH RESOURCES INC.
(Exact name of registrant as specified in its charter)
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Delaware
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51-0424817 |
(State or other jurisdiction of
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(I.R.S. employer |
incorporation or organization)
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identification number) |
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One Ridgmar Centre |
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6500 W. Freeway, Suite 800 |
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Fort Worth, Texas
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76116 |
(Address of principal executive offices)
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(Zip Code) |
(817) 989-9000
(Registrants telephone number, including area code)
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, a non-accelerated filer or a smaller reporting company. See the definitions of large
accelerated filer, accelerated filer and smaller reporting company in Rule 12b-2 of the
Exchange Act. (Check one):
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Large accelerated filer o
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Accelerated filer o
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Non-accelerated filer þ
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Smaller reporting company o |
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(Do not check if a smaller reporting company) |
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Indicate by a check mark whether the registrant is a shell company (as defined in Rule 12b-2
of the Act). Yes o No þ
The number of shares of the registrants common stock, $0.01 par value, outstanding as of October
31, 2008 was 20,651,591.
TABLE OF CONTENTS
PART I FINANCIAL INFORMATION
Item 1. Financial statements.
APPROACH RESOURCES INC.
UNAUDITED CONSOLIDATED BALANCE SHEETS
(In thousands, except shares and per share amounts)
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September 30, |
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December 31, |
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2008 |
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2007 |
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ASSETS |
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CURRENT ASSETS: |
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Cash and cash equivalents |
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$ |
1,626 |
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$ |
4,785 |
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Accounts receivable: |
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Joint interest owners |
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9,814 |
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5,272 |
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Oil and gas sales |
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9,852 |
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5,524 |
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Unrealized gain on commodity derivatives |
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4,537 |
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793 |
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Prepaid expenses and other current assets |
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254 |
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432 |
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Total current assets |
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26,083 |
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16,806 |
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PROPERTIES AND EQUIPMENT: |
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Oil and gas properties, at cost, using the successful efforts method of accounting |
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338,743 |
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267,246 |
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Furniture, fixtures and equipment |
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890 |
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433 |
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339,633 |
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267,679 |
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Less accumulated depletion, depreciation and amortization |
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(53,082 |
) |
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(36,860 |
) |
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Net properties and equipment |
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286,551 |
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230,819 |
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INVESTMENT |
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917 |
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917 |
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UNREALIZED GAIN ON COMMODITY DERIVATIVES |
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391 |
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75 |
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OTHER ASSETS |
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1 |
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109 |
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Total assets |
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$ |
313,943 |
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$ |
248,726 |
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LIABILITIES AND STOCKHOLDERS EQUITY |
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CURRENT LIABILITIES: |
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Accounts payable |
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$ |
4,341 |
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$ |
5,459 |
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Oil and gas sales payable |
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8,365 |
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1,794 |
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Accrued liabilities |
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15,716 |
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14,764 |
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Total current liabilities |
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28,422 |
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22,017 |
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NON-CURRENT LIABILITIES: |
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Long-term debt |
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23,528 |
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Deferred income taxes |
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36,917 |
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26,342 |
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Asset retirement obligations |
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695 |
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548 |
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Total liabilities |
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89,562 |
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48,907 |
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COMMITMENTS AND CONTINGENCIES |
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STOCKHOLDERS EQUITY : |
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Preferred stock, $0.01 par value, 10,000,000 shares authorized, none outstanding |
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Common stock, $0.01 par value, 90,000,000 shares authorized, 20,683,605 and
20,622,746 shares issued and 20,651,591 and 20,622,746 shares outstanding,
respectively |
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207 |
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206 |
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Additional paid-in capital |
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167,037 |
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166,141 |
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Retained earnings |
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56,905 |
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33,367 |
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Accumulated other comprehensive income |
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232 |
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105 |
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Total stockholders equity |
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224,381 |
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199,819 |
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Total liabilities and stockholders equity |
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$ |
313,943 |
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$ |
248,726 |
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See accompanying notes to these consolidated financial statements.
1
APPROACH RESOURCES INC. AND SUBSIDIARIES
UNAUDITED CONSOLIDATED STATEMENTS OF OPERATIONS
(In thousands, except shares and per share amounts)
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Three Months Ended |
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Nine Months Ended |
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September 30, |
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September 30, |
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2008 |
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2007 |
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2008 |
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2007 |
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REVENUES: |
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Oil and gas sales |
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$ |
22,015 |
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$ |
8,293 |
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$ |
65,177 |
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$ |
27,374 |
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EXPENSES: |
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Lease operating |
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1,842 |
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760 |
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5,095 |
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2,783 |
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Severance and production taxes |
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968 |
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400 |
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2,891 |
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1,148 |
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Exploration |
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1,478 |
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633 |
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General and administrative |
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1,923 |
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1,375 |
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5,686 |
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4,105 |
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Depletion, depreciation and amortization |
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5,016 |
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3,109 |
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16,257 |
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9,217 |
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Total expenses |
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9,749 |
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5,644 |
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31,407 |
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17,886 |
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OPERATING INCOME |
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12,266 |
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2,649 |
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33,770 |
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9,488 |
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OTHER: |
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Interest expense, net |
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(423 |
) |
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(1,108 |
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(914 |
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(3,062 |
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Realized (loss) gain on commodity derivatives |
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(195 |
) |
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1,079 |
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(676 |
) |
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3,323 |
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Unrealized gain (loss) on commodity
derivatives |
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18,611 |
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785 |
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4,060 |
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(2,117 |
) |
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INCOME BEFORE PROVISION FOR
INCOME TAXES |
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30,259 |
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3,405 |
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36,240 |
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7,632 |
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PROVISION FOR INCOME TAXES |
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10,411 |
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1,312 |
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12,702 |
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3,130 |
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NET INCOME |
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$ |
19,848 |
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$ |
2,093 |
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$ |
23,538 |
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$ |
4,502 |
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EARNINGS PER SHARE: |
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Basic |
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$ |
0.96 |
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$ |
0.22 |
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$ |
1.14 |
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$ |
0.47 |
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Diluted |
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$ |
0.95 |
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$ |
0.20 |
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$ |
1.13 |
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$ |
0.41 |
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WEIGHTED AVERAGE SHARES OUTSTANDING: |
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Basic |
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20,651,591 |
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9,538,883 |
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20,640,327 |
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9,507,449 |
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Diluted |
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20,851,848 |
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11,636,944 |
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20,837,166 |
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11,632,889 |
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See accompanying notes to these consolidated financial statements.
2
APPROACH RESOURCES INC. AND SUBSIDIARIES
UNAUDITED CONSOLIDATED STATEMENTS OF CASH FLOWS
(In thousands)
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Nine Months Ended |
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September 30, |
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2008 |
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2007 |
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OPERATING ACTIVITIES: |
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Net income |
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$ |
23,538 |
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$ |
4,502 |
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Adjustments to reconcile net income to net cash provided by
operating activities: |
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Depletion, depreciation and amortization |
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16,257 |
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9,217 |
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Unrealized (gain) loss on commodity derivatives |
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(4,060 |
) |
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2,117 |
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Exploration expense |
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1,478 |
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|
633 |
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Share-based compensation expense |
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800 |
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175 |
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Deferred income taxes |
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11,789 |
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1,867 |
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Changes in operating assets and liabilities: |
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Accounts receivable |
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(9,003 |
) |
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442 |
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Prepaid expenses and other assets |
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285 |
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(675 |
) |
Accounts payable |
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(1,118 |
) |
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(122 |
) |
Oil and gas sales payable |
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6,571 |
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(1,532 |
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Accrued liabilities |
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(641 |
) |
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3,670 |
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Cash provided by operating activities |
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45,896 |
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20,294 |
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INVESTING ACTIVITIES: |
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Additions to oil and gas properties |
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(72,213 |
) |
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(31,469 |
) |
Investments |
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(917 |
) |
Additions to other property and equipment, net |
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(457 |
) |
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(59 |
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Cash used in investing activities |
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(72,670 |
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(32,445 |
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FINANCING ACTIVITIES: |
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Proceeds from issuance of common stock |
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97 |
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240 |
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Loan origination fees |
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(143 |
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Borrowings under credit facility |
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83,878 |
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53,542 |
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Repayment of amounts outstanding under credit facility |
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(60,350 |
) |
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(47,869 |
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Proceeds from issuance of convertible debt |
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20,000 |
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Deferred offering costs |
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(774 |
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Cash provided by financing activities |
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23,625 |
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24,996 |
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CHANGE IN CASH AND CASH EQUIVALENTS |
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(3,149 |
) |
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12,845 |
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EFFECT OF FOREIGN CURRENCY TRANSLATION ON CASH AND CASH
EQUIVALENTS |
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(10 |
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CASH AND CASH EQUIVALENTS, beginning of period |
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4,785 |
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4,911 |
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CASH AND CASH EQUIVALENTS, end of period |
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$ |
1,626 |
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$ |
17,756 |
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SUPPLEMENTAL DISCLOSURE OF CASH FLOW INFORMATION: |
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Cash paid for interest |
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$ |
527 |
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$ |
3,360 |
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Cash paid for income taxes |
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$ |
49 |
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$ |
1,200 |
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SUPPLEMENTAL DISCLOSURE OF NON-CASH TRANSACTION: |
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Adjustment to Neo Canyon acquisition purchase price allocation |
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$ |
509 |
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$ |
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Retirement of loans to stockholders in exchange for shares of
common stock |
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$ |
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$ |
4,184 |
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|
See accompanying notes to these consolidated financial statements.
3
APPROACH RESOURCES INC. AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
September 30, 2008
(Unaudited)
1. Summary of significant accounting policies
Organization and nature of operations
Approach Resources Inc. (Approach, ARI, the Company, we, us or our) is an independent
energy company engaged in the exploration, development, production and acquisition of
unconventional natural gas and oil properties in the United States and British Columbia. We focus
on natural gas and oil reserves in tight sands and shale. We currently operate or have oil and gas
properties or interests in Texas, New Mexico, Kentucky and British Columbia.
Consolidation, basis of presentation and significant estimates
The interim consolidated financial statements of the Company are unaudited and contain all
adjustments (consisting primarily of normal recurring accruals) necessary for a fair statement of
the results for the interim periods presented. Results for interim periods are not necessarily
indicative of results to be expected for a full year or for previously reported periods due in
part, but not limited to, the volatility in prices for crude oil and natural gas, future commodity
prices for commodity derivative contracts, global economic and financial market conditions,
interest rates, estimates of reserves, drilling risks, geological risks, transportation
restrictions, the timing of acquisitions, product demand, market competition and interruptions of
production. You should read these consolidated interim financial statements in conjunction with the
audited consolidated financial statements and notes thereto included in our Annual Report on Form
10-K for the year ended December 31, 2007 and filed with the Securities and Exchange Commission on
March 28, 2008.
The accompanying interim consolidated financial statements have been prepared in accordance with
the accounting principles generally accepted in the United States of America and include the
accounts of the Company and its wholly-owned subsidiaries. Intercompany accounts and transactions
are eliminated. In preparing the accompanying financial statements, we have made certain estimates
and assumptions that affect reported amounts in the financial statements and disclosures of
contingencies. Actual results may differ from those estimates. Significant assumptions are required
in the valuation of proved oil and natural gas reserves, which may affect the amount at which oil
and natural gas properties are recorded, accrual of capital expenditures, asset retirement
obligations and share-based compensation. It is at least reasonably possible these estimates could
be revised in the near term, and these revisions could be material. Certain prior year amounts
have been reclassified to conform to current year presentation. These classifications have no
impact on the net income reported.
Comprehensive income
For the three and nine months ended September 30, 2007, there were no elements of comprehensive
income other than net income. Following is a summary of our comprehensive income for the three and
nine months ended September 30, 2008 (in thousands):
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Three Months Ended |
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Nine Months Ended |
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|
September 30, 2008 |
|
|
September 30, 2008 |
|
Net income |
|
$ |
19,848 |
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|
$ |
23,538 |
|
Other comprehensive income: |
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|
|
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|
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Foreign currency translation adjustments |
|
|
188 |
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|
127 |
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Comprehensive income |
|
$ |
20,036 |
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$ |
23,665 |
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4
APPROACH RESOURCES INC. AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
September 30, 2008
(Unaudited)
Earnings per common share
We report basic earnings per common share, which excludes the effect of potentially dilutive
securities, and diluted earnings per common share, which includes the effect of all potentially
dilutive securities unless their impact is anti-dilutive. The following are reconciliations of the
numerators and denominators of our basic and diluted earnings per share (dollars in thousands,
except per share amounts):
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Three Months Ended September 30, 2008 |
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Income (numerator) |
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Shares (denominator) |
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Per-share amount |
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Basic earnings per share: |
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Net income |
|
$ |
19,848 |
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|
|
20,651,591 |
|
|
$ |
0.96 |
|
Effect of dilutive securities: |
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|
|
|
|
|
|
|
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Stock options, treasury method |
|
|
|
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|
|
172,214 |
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Non-vested restricted shares |
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|
28,043 |
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Net income plus assumed conversions |
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$ |
19,848 |
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|
|
20,851,848 |
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|
$ |
0.95 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Three Months Ended September 30, 2007 |
|
|
|
Income (numerator) |
|
|
Shares (denominator) |
|
|
Per-share amount |
|
|
Basic earnings per share: |
|
|
|
|
|
|
|
|
|
|
|
|
Net income |
|
$ |
2,093 |
|
|
|
9,538,883 |
|
|
$ |
0.22 |
|
Effect of dilutive securities: |
|
|
|
|
|
|
|
|
|
|
|
|
Share-based compensation,
treasury method |
|
|
|
|
|
|
208,514 |
|
|
|
|
|
Non-vested restricted shares |
|
|
|
|
|
|
63,750 |
|
|
|
|
|
Convertible debt, if-converted
method(1) |
|
|
227 |
|
|
|
1,825,797 |
|
|
|
|
|
|
|
|
|
|
|
|
Net income plus assumed conversions |
|
$ |
2,320 |
|
|
|
11,636,944 |
|
|
$ |
0.20 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Nine Months Ended September 30, 2008 |
|
|
|
Income (numerator) |
|
|
Shares (denominator) |
|
|
Per-share amount |
|
|
Basic earnings per share: |
|
|
|
|
|
|
|
|
|
|
|
|
Net income |
|
$ |
23,538 |
|
|
|
20,640,327 |
|
|
$ |
1.14 |
|
Effect of dilutive securities: |
|
|
|
|
|
|
|
|
|
|
|
|
Stock options, treasury method |
|
|
|
|
|
|
184,769 |
|
|
|
|
|
Non-vested restricted shares |
|
|
|
|
|
|
12,070 |
|
|
|
|
|
|
|
|
|
|
|
|
Net income plus assumed conversions |
|
$ |
23,538 |
|
|
|
20,837,166 |
|
|
$ |
1.13 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Nine Months Ended September 30, 2007 |
|
|
|
Income (numerator) |
|
|
Shares (denominator) |
|
|
Per-share amount |
|
|
Basic earnings per share: |
|
|
|
|
|
|
|
|
|
|
|
|
Net income |
|
$ |
4,502 |
|
|
|
9,507,449 |
|
|
$ |
0.47 |
|
Effect of dilutive securities: |
|
|
|
|
|
|
|
|
|
|
|
|
Share-based compensation, treasury
method |
|
|
|
|
|
|
235,893 |
|
|
|
|
|
Non-vested restricted shares |
|
|
|
|
|
|
63,750 |
|
|
|
|
|
Convertible debt, if-converted
method(1) |
|
|
242 |
|
|
|
1,825,797 |
|
|
|
|
|
|
|
|
|
|
|
|
Net income plus assumed conversions |
|
$ |
4,744 |
|
|
|
11,632,889 |
|
|
$ |
0.41 |
|
|
|
|
|
|
|
|
|
|
|
(1) |
|
Upon the consummation of our initial public offering in November 2007, the convertible debt was converted
into shares of common stock. |
5
APPROACH RESOURCES INC. AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
September 30, 2008
(Unaudited)
2. Ozona Northeast deep rights acquisition
On July 1, 2008, we acquired an additional 95% working interest in all depths below the top of the
Strawn formation, compression facilities and rights to approximately 75 miles of gathering lines in
our Ozona Northeast field in Crockett and Schleicher Counties, Texas. The properties were acquired
from J. Cleo Thompson & James Cleo Thompson, Jr., L.P. and certain other sellers. Before the
acquisition, we owned a 100% working interest above the top of the Strawn formation and a 5%
working interest below the top of the Strawn formation in Ozona Northeast. As a result of the
acquisition, we now own substantially all working interests in all depths of the subsurface in
Ozona Northeast.
The purchase price was $12.0 million subject to post-closing adjustments. Of the purchase price,
$500,000 is to be paid no later than one year from closing pending certain right-of-way matters
being cured. Our preliminary purchase price allocation was $9.5 million to oil and gas properties
and $2.0 million to gathering system, compression facilities and related equipment. Funding was
provided through borrowings under our $100.0 million revolving credit facility.
3. Contribution Agreement
On November 14, 2007, the Company acquired all of the outstanding capital stock of Approach Oil &
Gas Inc. (AOG) and acquired the 30% working interest in the Ozona Northeast field (the Neo
Canyon interest) that the Company did not already own from Neo Canyon Exploration, L.P. (Neo
Canyon). Upon the closing of the contribution agreement, Neo Canyon and each of the stockholders
of AOG received shares of Company common stock in exchange for their respective contributions. Neo
Canyon received an aggregate of 4,239,243 shares of Company common stock, of which 2,061,290 shares
were offered in the Companys initial public offering (IPO), 156,805 shares were subject to the
over-allotment option granted to the underwriters and 2,021,148 shares were redeemed by the Company
for cash. The stockholders of AOG received an aggregate of 989,157 shares of Company common stock.
The acquisition cost of the Neo Canyon interest was $60.7 million, representing 4,239,243 shares of
Company common stock at $12.00 per share, our IPO price, and the assumption of related deferred
income tax liabilities and asset retirement obligations at that date along with post-closing
purchase price adjustments resulting from operating results of the properties acquired between the
effective date and the closing date of the acquisition. The existing tax basis assumed from the
acquisition was finalized during the nine months ended September 30, 2008. The adjustment made
during the nine months ended September 30, 2008 resulted in a $376,000 increase in deferred tax
liabilities, $133,000 in additional post-closing purchase price adjustments and an increase in oil
and gas properties of $509,000. The following is a summary of the final purchase price and its
allocation (in thousands):
|
|
|
|
|
Purchase price: |
|
|
|
|
Issuance of 4,239,243 shares of Approach Resources Inc. common
stock valued at $12.00 per share |
|
$ |
50,871 |
|
Deferred tax liabilities assumed |
|
|
9,465 |
|
Asset retirement obligations assumed |
|
|
133 |
|
Post-closing purchase price adjustments |
|
|
265 |
|
|
|
|
|
Total |
|
$ |
60,734 |
|
|
|
|
|
|
|
|
|
|
Allocation: |
|
|
|
|
Wells and equipment and related facilities |
|
$ |
59,936 |
|
Mineral interests in oil and gas properties |
|
|
798 |
|
|
|
|
|
Total |
|
$ |
60,734 |
|
|
|
|
|
6
APPROACH RESOURCES INC. AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
September 30, 2008
(Unaudited)
4. Line of credit
In January 2008 we entered into a new, $200.0 million revolving loan agreement (Loan Agreement)
with the Company as borrower, AOG, Approach Oil & Gas (Canada) Inc. and Approach Resources I, LP as
guarantors, and The Frost National Bank and JPMorgan Chase Bank, NA, as lenders (collectively, the
Lenders). The borrowing base under the Loan Agreement was initially set at $75.0 million and
will be redetermined semi-annually on or before each April 1 and October 1 based on our oil and gas
reserves. We or the Lenders can request one additional borrowing base redetermination each calendar
year. In May 2008, the Lenders increased the borrowing base to $100.0 million. The maturity date
under the Loan Agreement is July 31, 2010. The borrowings bear interest based on the agent banks
prime rate, or the sum of the LIBOR plus an applicable margin ranging from 1.25% to 2.00% based on
the borrowings outstanding compared to the borrowing base (5.0% at September 30, 2008), at our
election. We had outstanding borrowings of $23.5 million at September 30, 2008. Principal payments
are not required until the final maturity date of the Loan Agreement, at which time any outstanding
loan balances shall be due and payable in full. In addition, the Loan Agreement requires payment of
a quarterly fee equal to three eighths of one percent (0.375%) of the unused portion of the
borrowing base. The borrowings are collateralized by substantially all of our oil and gas
properties. The Loan Agreement contains various covenants, the most restrictive of which requires
us to maintain a modified current ratio of at least one. The modified current ratio represents the
quotient of our current assets, less any unrealized gains on commodity derivatives plus amounts
available under the Loan Agreement divided by our current liabilities less unrealized losses on
commodity derivatives. We were in compliance with the covenants at September 30, 2008.
On August 26, 2008, we entered into a third amendment (the Third Amendment) to the Loan
Agreement. The Third Amendment (i) added Fortis Capital Corp. and KeyBank National Association as
Lenders under the Credit Agreement, (ii) allocated the Lenders commitment percentages as The Frost
National Bank 30%, JPMorgan Chase Bank, NA 30%, Fortis Capital Corp. 20% and KeyBank National
Association 20%, (iii) added a covenant that we will not exceed a debt to EBITDAX ratio of 3.5 to
1.0, and (iv) clarified that secured parties under the Loan Agreement (and beneficiaries of Loan
Agreement guarantees) will include affiliates of Lenders who enter into commodity derivatives
transactions with us.
We also have outstanding unused letters of credit under the Loan Agreement totaling $400,000 at
September 30, 2008, which reduce amounts available for borrowing under the Loan Agreement.
7
APPROACH RESOURCES INC. AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
September 30, 2008
(Unaudited)
5. Income taxes
The effective income tax rate for the three and nine months ended September 30, 2008 was 34.4% and
35.1%, respectively. Total income tax expense (benefit) differed from the amounts computed by
applying the U.S. Federal statutory tax rates and estimated state rates to pre-tax income for the
three and nine months ended September 30, 2007 due primarily to adjustments to our valuation
allowance on deferred tax assets.
6. Derivatives
At September 30, 2008, we had the following commodity derivatives positions outstanding:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Period |
|
Volume (MMBtu) |
|
$/MMBtu |
|
|
Monthly |
|
Total |
|
Floor |
|
Ceiling |
|
Fixed |
NYMEX Henry Hub |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Costless collars 2008 |
|
|
173,000 |
|
|
|
520,000 |
|
|
$ |
7.50 |
|
|
$ |
11.45 |
|
|
|
|
|
Costless collars 2008 |
|
|
200,000 |
|
|
|
600,000 |
|
|
$ |
9.00 |
|
|
$ |
12.20 |
|
|
|
|
|
Costless collars 2009 |
|
|
180,000 |
|
|
|
2,160,000 |
|
|
$ |
7.50 |
|
|
$ |
10.50 |
|
|
|
|
|
Costless collars 2009 |
|
|
130,000 |
|
|
|
1,560,000 |
|
|
$ |
8.50 |
|
|
$ |
11.70 |
|
|
|
|
|
Fixed price swaps |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
4th quarter 2008 |
|
|
100,000 |
|
|
|
300,000 |
|
|
|
|
|
|
|
|
|
|
$ |
8.63 |
|
WAHA differential |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Fixed price swaps 2008 |
|
|
173,000 |
|
|
|
520,000 |
|
|
|
|
|
|
|
|
|
|
|
(0.69 |
) |
Fixed price swaps 2008 |
|
|
100,000 |
|
|
|
300,000 |
|
|
|
|
|
|
|
|
|
|
|
(0.67 |
) |
Fixed price swaps 2009 |
|
|
200,000 |
|
|
|
2,400,000 |
|
|
|
|
|
|
|
|
|
|
|
(0.61 |
) |
Unrealized gains and losses, at fair value, are included on our consolidated balance sheets as
current or non-current assets or liabilities based on the anticipated timing of cash settlements
under the related contracts. Changes in the fair value of our commodity derivative contracts are
recorded in earnings as they occur and included in other income (expense) on our consolidated
statements of operations. We estimate the fair values of swap contracts based on the present value
of the difference in exchange-quoted forward price curves and contractual settlement prices
multiplied by notional quantities. We internally valued the collar contracts using
industry-standard option pricing models and observable market inputs. We use our internal
valuations to determine the fair values of the contracts that are reflected on our consolidated
balance sheets. Realized gains and losses are also included in other income (expense) on our
consolidated statements of operations.
We are exposed to credit losses in the event of nonperformance by the counterparty on our commodity
derivatives positions and have considered the exposure in our internal valuations. However, we do
not anticipate nonperformance by the counterparty over the term of the commodity derivatives
positions.
Adoption of Statement of Financial Accounting Standards No. 157 (FAS 157)
Effective January 1, 2008, we adopted FAS 157, which among other things, requires enhanced
disclosures about assets and liabilities carried at fair value. As defined in FAS 157, fair value
is the price that would be received to sell an asset or paid to transfer a liability in an orderly
transaction between market participants at the measurement date (exit price). We utilize market
data or assumptions that market participants would use in pricing the asset or liability, including
assumptions about risk and the risks inherent in the inputs to the valuation technique. These
inputs can be readily observable, market corroborated or generally unobservable. We primarily apply
the market approach for recurring fair value measurements and attempt to utilize the best available
information. FAS 157 establishes a fair value
8
APPROACH RESOURCES INC. AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
September 30, 2008
(Unaudited)
hierarchy that prioritizes the inputs used to measure fair value. The hierarchy gives the highest
priority to unadjusted quoted prices in active markets for identical assets or liabilities (Level 1
measurement) and lowest priority to unobservable inputs (Level 3 measurement). The three levels of
fair value hierarchy defined by FAS 157 are as follows:
|
|
|
Level 1 Quoted prices are available in active markets for identical assets or
liabilities as of the reporting date. At September 30, 2008, we had no Level 1
measurements. |
|
|
|
|
Level 2 Pricing inputs are other than quoted prices in active markets included in
Level 1, which are either directly or indirectly observable as of the reporting date. Level
2 includes those financial instruments that are valued using models or other valuation
methodologies. These models are primarily industry-standard models that consider various
assumptions, including quoted forward prices for commodities, time value, volatility
factors and current market and contractual prices for the underlying instruments, as well
as other relevant economic measures. Our derivatives, which consist primarily of commodity
swaps and collars, are valued using commodity market data which is derived by combining raw
inputs and quantitative models and processes to generate forward curves. Where observable
inputs are available, directly or indirectly, for substantially the full term of the asset
or liability, the instrument is categorized in Level 2. At September 30, 2008, our
commodity derivatives were valued using Level 2 measurements. |
|
|
|
|
Level 3 Pricing inputs include significant inputs that are generally less observable
from objective sources. These inputs may be used with internally developed methodologies
that result in managements best estimate of fair value. At September 30, 2008, our Level 3
measurements were limited to our asset retirement obligation. |
7. Share-based compensation
The following is a summary of stock option activity during the nine months ended September 30,
2008:
|
|
|
|
|
|
|
Shares |
|
|
subject to |
|
|
stock |
|
|
options |
Outstanding at January 1, 2008 |
|
|
479,991 |
|
Granted |
|
|
74,345 |
|
Exercised |
|
|
(28,845 |
) |
Canceled |
|
|
(40,600 |
) |
|
|
|
|
|
|
|
|
|
|
Outstanding at September 30, 2008 |
|
|
484,891 |
|
|
|
|
|
|
During the nine months ended September 30, 2008, we granted 32,014 restricted shares of our common
stock. The total fair market value of these restricted shares on the grant date was $689,000 to be
expensed over a service period of three years.
9
Item 2. Managements discussion and analysis of financial condition and results of operations.
The following discussion is intended to assist in understanding our results of operations and our
financial condition. This section should be read in conjunction with managements discussion and
analysis contained in our Annual Report on Form 10-K for the year ended December 31, 2007 filed
with the Securities and Exchange Commission (SEC) on March 28, 2008. Our consolidated financial
statements and the accompanying notes included elsewhere in this Quarterly Report on Form 10-Q
contain additional information that should be referred to when reviewing this material. Certain
statements in this discussion may be forward-looking. These forward-looking statements involve
risks and uncertainties, which could cause actual results to differ from those expressed in this
report.
Cautionary statement regarding forward-looking statements
Various statements in this report, including those that express a belief, expectation or intention,
as well as those that are not statements of historical fact, are forward-looking statements. The
forward-looking statements may include projections and estimates concerning the timing and success
of specific projects and our future reserves, production, revenues, income and capital spending.
When we use the words will, believe, intend, expect, may, should, anticipate,
could, estimate, plan, predict, project or their negatives, other similar expressions or
the statements that include those words, it usually is a forward-looking statement.
The forward-looking statements contained in this report are largely based on our expectations,
which reflect estimates and assumptions made by our management. These estimates and assumptions
reflect our best judgment based on currently known market conditions and other factors. Although we
believe such estimates and assumptions to be reasonable, they are inherently uncertain and involve
a number of risks and uncertainties that are beyond our control. In addition, managements
assumptions about future events may prove to be inaccurate. We caution all readers that the
forward-looking statements contained in this report are not guarantees of future performance, and
we cannot assure any reader that such statements will be realized or the forward-looking events and
circumstances will occur. Actual results may differ materially from those anticipated or implied in
the forward-looking statements due to the factors detailed below and discussed in our Annual Report
on Form 10-K for the year ended December 31, 2007 filed with the SEC on March 28, 2008. All
forward-looking statements speak only as of the date of this report. We do not intend to publicly
update or revise any forward-looking statements as a result of new information, future events or
otherwise. These cautionary statements qualify all forward-looking statements attributable to us,
or persons acting on our behalf. The risks, contingencies and uncertainties relate to, among other
matters, the following:
|
|
global economic and financial market conditions, |
|
|
|
our business strategy, |
|
|
|
estimated quantities of gas and oil reserves, |
|
|
|
uncertainty of commodity prices in oil and gas, |
|
|
|
continued disruption of credit and capital markets, such as the events that occurred during
the third quarter of 2008, |
|
|
|
our financial position, |
10
|
|
our cash flow and liquidity, |
|
|
|
replacing our gas and oil reserves, |
|
|
|
our inability to retain and attract key personnel, |
|
|
|
uncertainty regarding our future operating results, |
|
|
|
uncertainties in exploring for and producing gas and oil, |
|
|
|
high costs, shortages, delivery delays or unavailability of drilling rigs, equipment, labor
or other services, |
|
|
|
disruptions to, capacity constraints in or other limitations on the pipeline systems which
deliver our gas and other processing and transportation considerations, |
|
|
|
our inability to obtain additional financing necessary to
fund our operations and capital expenditures and to meet our other obligations, |
|
|
|
competition in the oil and gas industry, |
|
|
|
marketing of gas and oil, |
|
|
|
exploitation or property acquisitions, |
|
|
|
technology, |
|
|
|
the effects of government regulation and permitting and other legal requirements, |
|
|
|
plans, objectives, expectations and intentions contained in this report that are not historical,
and |
|
|
|
other factors discussed in our Annual Report on Form 10-K for the year ended December 31,
2007 filed with the SEC on March 28, 2008 and in this Quarterly Report on Form 10-Q. |
11
Overview
We are an independent energy company engaged in the exploration, development, production and
acquisition of unconventional natural gas and oil properties onshore in the United States and
British Columbia. We focus on natural gas and oil reserves in tight sands and shale and have
assembled leasehold interests aggregating approximately 288,454 gross (199,098 net) acres as of
October 31, 2008.
We currently operate or have interests in the following areas:
West Texas
|
|
|
Ozona Northeast (Wolfcamp, Canyon Sands, Strawn and Ellenburger) |
|
|
|
|
Cinco Terry (Wolfcamp, Canyon Sands and Ellenburger) |
East Texas
|
|
|
North Bald Prairie (Cotton Valley Sands, Bossier Sands, Bossier Shale
and Cotton Valley Lime) |
Northeast British Columbia
|
|
|
Montney tight gas and Doig Shale |
Northern New Mexico
|
|
|
El Vado East (Mancos Shale) |
Southwest Kentucky
|
|
|
Boomerang (New Albany Shale) |
At June 30, 2008, we had estimated proved reserves of approximately 193.7 billion cubic feet of
natural gas equivalent, based on internal engineering studies prepared by our reservoir engineers
and reviewed by our independent petroleum engineering firm. At September 30, 2008, we owned
working interests in 439 producing oil and gas wells and were producing 22.6 million cubic feet of
natural gas equivalent per day (MMcfe/d) (based on production for the third quarter of 2008).
Our estimated average daily net production for the month of October 2008 was 30.4 MMcfe/d.
Our financial results depend on many factors, particularly the price of oil and gas. Commodity
prices are affected by changes in global and national market demand, which is impacted by overall
global and national economic and geopolitical conditions, weather, pipeline capacity constraints,
inventory storage levels, gas price differentials and other factors. Recent oil and natural gas
prices have been particularly volatile. As a result, we cannot accurately predict future oil and
gas prices, and therefore, we cannot determine what effect increases or decreases will have on our
capital program, production volumes and future revenues. In addition to production volumes and
commodity prices, finding and developing sufficient amounts of oil and gas reserves at economical
costs are critical to our long-term success. Future finding and development costs are subject to
changes in the industry, including the costs of acquiring, drilling and completing our projects.
Higher oil and gas prices generally increase the demand for drilling rigs and equipment, operating
personnel and field supplies and services and can cause increases in the costs of those goods and
services. While we have benefitted from higher commodity prices through the first nine months of
2008, we also
12
have experienced an increase in operating and capital costs during this time that have partially
offset these higher commodity prices. We endeavor to increase oil and gas reserves and production
while controlling costs at a level that is appropriate for long-term operations. Our future cash
flow from operations will depend on our ability to manage our overall cost structure.
Like all oil and gas production companies, we face the challenge of natural production declines.
Oil and gas production from any given well naturally decreases over time. Additionally, our
reserves have a rapid initial decline, a characteristic of tight gas sands. We attempt to overcome
this natural decline by drilling to develop and identify additional reserves, farm-ins or other
drilling ventures, and by acquisitions. Our future growth will depend upon our ability to continue
to add oil and gas reserves in excess of production at a reasonable cost. We intend to maintain our
focus on the costs of adding reserves through drilling and acquisitions as well as the costs
necessary to produce such reserves.
We also face the challenge of financing future acquisitions. After completion of the initial public
offering of our common stock, we repaid all amounts outstanding on our revolving credit facility.
At September 30, 2008, we had $23.5 million outstanding under our revolving credit facility. At
October 31, 2008, we had $27.1 outstanding under our revolving credit facility. Outstanding
borrowings under the Companys credit facility increased during the third quarter and first month
of the fourth quarter of 2008 primarily as a result of lost revenues from shut-in production and
increased drilling activity in Cinco Terry and North Bald Prairie. We believe we have adequate
unused borrowing capacity under our revolving credit facility for possible acquisitions, temporary
working capital needs and further expansion of our drilling program if market conditions warrant
such activity. Funding for future acquisitions also may require additional sources of financing,
which may not be available given current capital market conditions.
Shut-in of production during third quarter of 2008
As previously reported, production volumes during the third quarter of 2008 were negatively
impacted by shut-in production over a period of 23 days in Ozona Northeast, our largest producing
field, caused by Hurricane Ike and the rupture of a third-party pipeline. As a result of shut-in
of production, we estimate that we experienced decreased production volumes of approximately 340
MMcfe during the third quarter of 2008.
British Columbia asset divestiture
On July 15, 2008, we announced that the operator and non-operating participants in our British
Columbia lease acquisition and drilling project engaged a financial advisor to explore the sale of
the projects oil and gas interests in northeast British Columbia. The project covers
approximately 31,246 (gross) and 7,399 (net) acres in the Monias/Charlie Lake areas. The project
primarily targets Montney tight gas and Doig phosphate shale formations. We hold a 25%
non-operating interest in the project.
On September 30, 2008, the operator and non-operating participants determined not to sell their
interests in the British Columbia project at this time given current commodity price and capital
market conditions. We plan to work with the other participants in the project to create the most
value possible for all parties, including further development of the projects acreage.
13
Results of operations
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Three Months Ended |
|
Nine Months Ended |
|
|
September 30, |
|
September 30, |
|
|
2008 |
|
2007 |
|
2008 |
|
2007 |
|
|
|
Revenues (in thousands): |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Gas |
|
$ |
14,456 |
|
|
$ |
7,194 |
|
|
$ |
47,900 |
|
|
$ |
24,110 |
|
Oil |
|
|
5,973 |
|
|
|
1,010 |
|
|
|
13,223 |
|
|
|
3,075 |
|
NGLs |
|
|
1,586 |
|
|
|
89 |
|
|
|
4,054 |
|
|
|
189 |
|
|
|
|
|
|
Total oil and gas sales |
|
|
22,015 |
|
|
|
8,293 |
|
|
|
65,177 |
|
|
|
27,374 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Realized (loss) gain on commodity derivatives |
|
|
(195 |
) |
|
|
1,079 |
|
|
|
(676 |
) |
|
|
3,323 |
|
|
|
|
|
|
Total oil and gas sales including
derivative impact |
|
$ |
21,820 |
|
|
$ |
9,372 |
|
|
$ |
64,501 |
|
|
$ |
30,697 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Production: |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Gas (MMcf) |
|
|
1,588 |
|
|
|
1,135 |
|
|
|
4,927 |
|
|
|
3,511 |
|
Oil (MBbls) |
|
|
54 |
|
|
|
14 |
|
|
|
120 |
|
|
|
50 |
|
NGLs (MBbls) |
|
|
28 |
|
|
|
2 |
|
|
|
75 |
|
|
|
5 |
|
|
|
|
|
|
Total (MMcfe) |
|
|
2,080 |
|
|
|
1,232 |
|
|
|
6,097 |
|
|
|
3,840 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Average prices: |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Gas (per Mcf) |
|
$ |
9.10 |
|
|
$ |
6.34 |
|
|
$ |
9.72 |
|
|
$ |
6.87 |
|
Oil (per Bbl) |
|
|
110.61 |
|
|
|
72.14 |
|
|
|
110.19 |
|
|
|
61.50 |
|
NGLs (per Bbl) |
|
|
56.64 |
|
|
|
44.50 |
|
|
|
54.05 |
|
|
|
37.80 |
|
|
|
|
|
|
Total (per Mcfe) |
|
$ |
10.58 |
|
|
$ |
6.73 |
|
|
$ |
10.69 |
|
|
$ |
7.13 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Realized (loss) gain on commodity derivatives
(per Mcfe) |
|
|
(0.09 |
) |
|
|
0.88 |
|
|
|
(0.11 |
) |
|
|
0.86 |
|
|
|
|
|
|
Total per Mcfe including derivative impact |
|
$ |
10.49 |
|
|
$ |
7.61 |
|
|
$ |
10.58 |
|
|
$ |
7.99 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Costs and expenses (per Mcfe): |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Lease operating expenses |
|
$ |
0.89 |
|
|
$ |
0.62 |
|
|
$ |
0.84 |
|
|
$ |
0.72 |
|
Severance and production taxes |
|
|
0.47 |
|
|
|
0.32 |
|
|
|
0.47 |
|
|
|
0.30 |
|
Exploration |
|
|
|
|
|
|
|
|
|
|
0.24 |
|
|
|
0.16 |
|
General and administrative |
|
|
0.92 |
|
|
|
1.12 |
|
|
|
0.93 |
|
|
|
1.07 |
|
Depletion, depreciation and amortization |
|
|
2.41 |
|
|
|
2.52 |
|
|
|
2.67 |
|
|
|
2.40 |
|
Equivalent amounts throughout this report are determined by using a ratio of six thousand cubic
feet (Mcf) of gas to one barrel (Bbl) of oil, condensate or natural gas liquids (NGLs).
Three months ended September 30, 2008 compared to three months ended September 30, 2007
Oil and gas sales. Oil and gas sales increased $13.7 million, or 165%, for the three months ended
September 30, 2008 to $22.0 million from $8.3 million for the three months ended September 30,
2007. The increase in oil and gas sales principally resulted from our increased ownership in the
Ozona Northeast field as a result of our acquisition of the 30% working interest in Ozona Northeast
(the Neo Canyon interest) that we did not already own from Neo Canyon Exploration, L.P. in the
fourth quarter of 2007 and increased revenues from our Cinco Terry and North Bald Prairie fields.
We now own substantially all of the working interest in Ozona Northeast. Of the 2,080 million
cubic feet of natural gas equivalent (MMcfe) production reported for the 2008 period,
approximately 373 MMcfe was attributable to the interest acquired from Neo Canyon. The increase in
oil and gas sales also resulted from continued development of our Cinco Terry and North Bald
Prairie fields. Cinco Terry production rose by
14
696 MMcfe compared to the prior year period. Production from North Bald Prairie accounted for 91
MMcfe for the current three-month period. Further, the average price per thousand cubic feet of
natural gas equivalent (Mcfe) we received for our production increased from $6.73 to $10.58 per
Mcfe as oil and gas prices rose sharply between the two periods. Of the $13.7 million increase in
revenues, $10.4 million was attributable to growth in volumes with the remaining $3.3 million due
to oil and gas price increases. Natural gas sales represented 65.7% of the total oil and gas sales
for the three months ended September 30, 2008, compared to 86.7% for the prior year period, as our
Cinco Terry field has a larger component of oil and natural gas liquids in its production.
Commodity derivative activities. Realized gains and losses from our commodity derivative activity
resulted in a loss of $195,000 and a gain of $1.1 million for the three months ended September 30,
2008 and 2007, respectively. Realized gains or losses are derived from the relative movement of gas
prices in relation to the range of prices in our collars or the fixed notional pricing for the
respective time periods. The unrealized gains on commodity derivatives were $18.6 million and
$785,000 for the three months ended September 30, 2008 and 2007, respectively. Both of these
variances are the result of decreases in underlying gas commodity prices. As natural gas commodity
prices increase, the fair value of the open portion of those positions decreases. As natural gas
commodity prices decrease, the fair value of the open portion of those positions increases.
Historically, we have not designated our derivative instruments as cash-flow hedges. We record our
open derivative instruments at fair value on our consolidated balance sheets as either unrealized
gains or losses on commodity derivatives. We record changes in such fair value in earnings on our
consolidated statements of operations under the caption entitled unrealized gain (loss) on
commodity derivatives.
Lease
operating. Our lease operating expenses (LOE) increased $1.1 million, or 142%, for the three months
ended September 30, 2008 to $1.8 million ($0.89 per Mcfe) from $760,000 ($0.62 per Mcfe) for the
three months ended September 30, 2007. The increase in LOE over the prior year quarter was
primarily a result of the acquisition of the Neo Canyon working interest and Strawn/Ellenburger
deep rights in Ozona Northeast, increased ad valorem taxes, including a retroactive adjustment
related to the first six months of 2008, initial startup costs, including increased compression and
treating costs associated with increased development activities in Cinco Terry and North Bald
Prairie, and an increase in general maintenance costs in Ozona Northeast.
Severance and production taxes. Our production taxes increased $568,000, or 142%, for the three
months ended September 30, 2008 to $1.0 million from $400,000 for the three months ended September
30, 2007. The increase in production taxes was a function of the increase in oil and gas sales
between the two periods. Severance and productions taxes amounted to approximately 4.4% and 4.8%
of oil and gas sales for the respective periods. The decrease in the severance and production
taxes as a percentage of oil and gas sales is due to a lower severance tax rate for our North Bald
Prairie field due to tax abatements on gas production in the area.
General and administrative. Our general and administrative expenses increased $548,000, or 40%, to
$1.9 million ($0.92 per Mcfe) for the three months ended September 30, 2008 from $1.4 million
($1.12 per Mcfe) for the three months ended September 30, 2007. The increase in general and
administrative expense on an absolute basis was principally due to increased staffing, salaries,
professional fees, share-based compensation, insurance and travel costs in the 2008 period over the
2007 period, partially offset by bonus payments made during the three months ended September 30,
2007, after the initial filing of our registration statement.
Depletion,
depreciation and amortization (DD&A). Our DD&A expense increased $1.9 million, or 61%,
to $5.0 million for the three months ended September 30, 2008 from $3.1 million for the three
months ended September 30, 2007. Our DD&A expense per Mcfe decreased by $0.11, or 4%, to $2.41 per
Mcfe
15
for the three months ended September 30, 2008, compared to $2.52 per Mcfe for the three months
ended September 30, 2007. The increase in DD&A was primarily attributable to increased production
and higher capital costs in the 2008 period, partially offset by an increase in our estimated
proved reserves at June 30, 2008.
Interest expense, net. Our interest expense decreased $685,000, or 62%, to $423,000 for the three
months ended September 30, 2008 from $1.1 million for the three months ended September 30, 2007.
This decrease was substantially the result of our lower debt level in the 2008 period as well as
lower interest rates during the 2008 period. We had borrowings outstanding under our revolving
credit facility amounting to $23.5 million at September 30, 2008 compared to $53.3 million at
September 30, 2007.
Income taxes. Our provision for income taxes increased to $10.4 million for the three months ended
September 30, 2008, from $1.3 million for the three months ended September 30, 2007. The increase
in income tax expense was due to the increase in our income before income taxes. Our effective
income tax rate for the three months ended September 30, 2008 was 34.4%, compared with 38.5% for
the three months ended September 30, 2007. The higher effective tax rate for the 2007 period was
the result of changes in our valuation allowance on deferred tax assets. Such changes were not
present in the 2008 period.
Nine months ended September 30, 2008 compared to nine months ended September 30, 2007
Oil and gas sales. Oil and gas sales increased $37.8 million, or 138%, for the nine months ended
September 30, 2008 to $65.2 million from $27.4 million for the nine months ended September 30,
2007. The increase in oil and gas sales principally resulted from our increased ownership in the
Ozona Northeast field as a result of our acquisition of the Neo Canyon interest in the fourth
quarter of 2007 and increased revenue from our Cinco Terry and North Bald Prairie fields. We now
own substantially all of the working interest in Ozona Northeast. Of the 6,097 MMcfe production
reported for the 2008 period, approximately 1,266 MMcfe was attributable to the interest acquired
from Neo Canyon. The increase in oil and gas sales also resulted from continued development of our
Cinco Terry and North Bald Prairie fields. Cinco Terry production rose by 1,418 MMcfe compared to
the prior year period. Production from North Bald Prairie accounted for 304 MMcfe in production
for the current nine-month period. Further, the average price per Mcfe we received for our
production increased from $7.13 to $10.69 per Mcfe as oil and gas prices rose sharply between the
two periods. Of the $37.8 million increase in revenues, $26.6 million was attributable to growth in
volumes with the remaining $11.2 million due to oil and gas price increases. Natural gas sales
represented 73.5% of the total oil and gas sales for the nine months ended September 30, 2008,
compared to 88.1% for the prior year period, as our Cinco Terry field has a larger component of oil
and NGLs in its production.
Commodity derivative activities. Realized losses and gains from our commodity derivative activity
decreased our earnings by $676,000 and increased our earnings by $3.3 million for the nine months
ended September 30, 2008 and 2007, respectively. Realized gains and losses are derived from the
relative movement of gas prices in relation to the range of prices in our collars or the fixed
notional pricing for the respective time periods. The unrealized gain on commodity derivatives was
$4.1 million for the nine months ended September 30, 2008 and the unrealized loss on commodity
derivatives was $2.1 million for the nine months ended September 30, 2007. As natural gas
commodity prices increase, the fair value of the open portion of those positions decreases. As
natural gas commodity prices decrease, the fair value of the open portion of those positions
increases. Historically, we have not designated our derivative instruments as cash-flow hedges. We
record our open derivative instruments at fair value on our consolidated balance sheets as either
unrealized gains or losses on commodity derivatives. We record
changes in such fair value in earnings on our consolidated statements of operations under the
caption entitled unrealized loss on commodity derivatives.
16
Lease
operating. Our lease operating expenses (LOE) increased $2.3 million, or 83%, for the nine months
ended September 30, 2008 to $5.1 million ($0.84 per Mcfe) from $2.8 million ($0.72 per Mcfe) for
the nine months ended September 30, 2007. The primary factors in the increase in LOE were the
acquisition of the Neo Canyon working interest and Strawn/Ellenburger deep rights in Ozona
Northeast, increased ad valorem taxes, initial startup costs, including increased compression and
treating costs associated with increased development activities in Cinco Terry and North Bald
Prairie, and an increase in general maintenance costs in Ozona Northeast.
Severance and production taxes. Our production taxes increased $1.7 million, or 152%, for the nine
months ended September 30, 2008 to $2.9 million from $1.1 million for the nine months ended
September 30, 2007. The increase in production taxes was a function of the increase in oil and gas
sales between the two periods. Severance and productions taxes amounted to approximately 4.4% and
4.2% of oil and gas sales for the respective periods. The increase in the severance and production
taxes as a percentage of oil and gas sales is due to the increase in NGL sales in Cinco Terry,
which are taxed at a higher rate.
Exploration. We recorded $1.5 million of exploration expense for the nine months ended September
30, 2008, compared to $633,000 for the nine months ended September 30, 2007. Exploration expense
for the 2008 period resulted from one dry hole drilled in Ozona Northeast and $965,000 of lease
extensions in Ozona Northeast. We incur these costs to maintain our leasehold positions and
accordingly, we expense them as incurred. Exploration expense for the 2007 period resulted from
the drilling of a dry hole test well in our Boomerang project.
General and administrative. Our general and administrative expenses increased $1.6 million, or 39%,
to $5.7 million ($0.93 per Mcfe) for the nine months ended September 30, 2008 from $4.1 million
($1.07 per Mcfe) for the nine months ended September 30, 2007. The increase in general and
administrative expense on an absolute basis was principally due to increased staffing, salaries,
professional fees, share-based compensation, insurance and travel costs in the 2008 period over the
2007 period. The 2008 period increase was partially offset by bonus payments made in the first
nine months of 2007 to cover tax liabilities incurred by management in connection with the
repayment of management notes, bonus payments made upon filing of our initial registration
statement in the third quarter and increased staffing in the 2007 period. Additionally, the 2007
period includes a severance obligation of $350,000 related to a former employee.
Depletion,
depreciation and amortization (DD&A). Our DD&A expense increased $7.0 million, or 76%,
to $16.3 million for the nine months ended September 30, 2008 from $9.2 million for the nine months
ended September 30, 2007. Our DD&A expense per Mcfe increased by $0.27, or 11%, to $2.67 per Mcfe
for the nine months ended September 30, 2008, compared to $2.40 per Mcfe for the nine months ended
September 30, 2007. The increase in DD&A was primarily attributable to increased production and
higher capital costs, partially offset by an increase in our estimated proved reserves at June 30,
2008. The higher DD&A expense per Mcfe was primarily attributable to higher capital costs incurred
in North Bald Prairie and reserve revisions in Ozona Northeast at December 31, 2007. In North Bald
Prairie, we paid capital costs attributable to the 50% working interest owned by our working
interest partner pursuant to our farm-in agreement on the first five wells drilled.
Interest expense, net. Our interest expense decreased $2.1 million, or 70%, to $914,000 for the
nine months ended September 30, 2008 from $3.1 million for the nine months ended September 30,
2007. This decrease was substantially the result of our lower debt level in the 2008 period as well
as lower interest
rates during the 2008 period. We had borrowings outstanding under our revolving credit facility
amounting to $23.5 million at September 30, 2008, compared to $53.3 million at September 30, 2007.
17
Income taxes. Our provision for income taxes increased to $12.7 million for the nine months ended
September 30, 2008, from $3.1 million for the nine months ended September 30, 2007. The increase in
income tax expense was due to the increase in our income before income taxes. Our effective income
tax rate for the nine months ended September 30, 2008 was 35.1%, compared with 41% for the nine
months ended September 30, 2007. The 2008 period included the
realization of a portion of certain net operating loss carryforwards
related to Approach Oil & Gas Inc. The higher effective tax rate for the 2007 period was the result of changes in our
valuation allowance on deferred tax assets. Such changes were not present in the 2008 period.
Liquidity and capital resources
We generally will rely on cash generated from operations, borrowings under our revolving credit
facility and, to the extent that credit and capital market conditions will allow, future public
equity and debt offerings to satisfy our liquidity needs. Our ability to fund planned capital
expenditures and to make acquisitions depends upon our future operating performance, availability
of borrowings under our revolving credit facility, and more broadly, on the availability of equity
and debt financing, which is affected by prevailing economic conditions in our industry and
financial, business and other factors, some of which are beyond our control. Given the current
conditions of credit and capital markets, we cannot predict whether additional liquidity from debt
or equity financings beyond our revolving credit facility will be available on acceptable terms, or
at all, in the foreseeable future. We currently are evaluating capital expenditure and operating
rig scenarios for 2009 to balance development of our core operating areas with internally generated
cash flows in 2009 and preserve liquidity under our revolving credit facility.
Our cash flow from operations is driven by commodity prices and production volumes. Prices for oil
and gas are affected by national and international economic and political environments, national
and global demand for hydrocarbons, seasonal influences of weather and other factors beyond our
control. Our working capital is significantly influenced by changes in commodity prices and
significant declines in prices will cause a decrease in our exploration and development
expenditures and production volumes. Cash flows from operations are primarily used to fund
exploration and development of our mineral interests.
The following table summarizes our sources and uses of funds for the periods noted:
|
|
|
|
|
|
|
|
|
|
|
Nine Months Ended |
|
|
September 30, |
(in thousands) |
|
2008 |
|
2007 |
Cash flows provided by operating
activities |
|
$ |
45,896 |
|
|
$ |
20,294 |
|
Cash flows used in investing activities |
|
|
(72,670 |
) |
|
|
(32,445 |
) |
Cash flows provided by financing
activities |
|
|
23,625 |
|
|
|
24,996 |
|
Effect of Canadian exchange rate |
|
|
(10 |
) |
|
|
|
|
|
|
|
Net (decrease) increase in cash and
cash equivalents |
|
$ |
(3,159 |
) |
|
$ |
12,845 |
|
18
Operating activities
For the nine months ended September 30, 2008, our cash flow from operations, borrowings under our
credit facility and available cash were used for drilling activities. The $45.9 million in cash
flow generated in the 2008 period increased $25.6 million from the same period in 2007 due
primarily to an increase in oil and gas sales. Partially offsetting the increase in oil and gas
sales was a $5.7 million reduction in working capital in the 2008 period as compared to the 2007
period.
Investing
activities
The cash flows used in investing activities in the 2008 period were for the continued development
of Ozona Northeast, Cinco Terry and North Bald Prairie. For the comparable 2007 period, the cash
flows used in investing activities were for the drilling of wells in Ozona Northeast, Cinco Terry
and North Bald Prairie, and the acquisition of the Northern New Mexico leasehold, the drilling of
Boomerang test wells and the investment in our Canadian project including our investment in a
Canadian-based private exploration company.
Capital expenditures for 2008
Our board of directors approved an $80.0 million capital budget for 2008 in May of 2008. The
following table summarizes estimated 2008 capital expenditures and actual capital expenditures
through September 30, 2008. The $80.0 million capital budget approved in May 2008 does not include
the $11.5 million purchase of the deep rights in Ozona Northeast, which closed on July 1, 2008. We
generally expect to meet our capital needs from our internally generated cash flow, borrowings
under our revolving credit facility and, to the extent that credit and capital market conditions
will permit, debt and equity financings.
Commodity prices and economic and financial market conditions have been, and continue to be,
disrupted and volatile. Due to these factors, we currently are evaluating capital expenditure and
operating rig scenarios for 2009 to balance development of our core operating areas with internally
generated cash flows in 2009 and to preserve liquidity under our revolving credit facility. The
estimated capital expenditures below are subject to change depending upon a number of factors,
including the results of our development and exploration efforts, the availability of sufficient
capital resources to us and other participants for drilling prospects, economic and industry
conditions at the time of drilling, including prevailing and anticipated prices for oil and gas and
the availability of drilling rigs and crews, our financial results, the availability of leases on
reasonable terms and our ability to obtain permits for drilling locations.
|
|
|
|
|
|
|
|
|
|
|
Estimated Year Ended |
|
|
Actual Through |
|
|
|
December 31, 2008 |
|
|
September 30, 2008 |
|
(in thousands) |
|
|
|
|
|
|
|
|
Capital Expenditures: |
|
|
|
|
|
|
|
|
Ozona Northeast |
|
$ |
37,500 |
|
|
$ |
22,304 |
|
Ozona Northeast deep rights acquisition |
|
|
|
|
|
|
11,500 |
|
Cinco Terry |
|
|
20,200 |
|
|
|
14,648 |
|
North Bald Prairie |
|
|
14,400 |
|
|
|
14,894 |
|
British Columbia |
|
|
3,000 |
|
|
|
2,951 |
|
El Vado East |
|
|
|
|
|
|
92 |
|
Boomerang |
|
|
1,800 |
|
|
|
290 |
|
Inventory |
|
|
|
|
|
|
2,366 |
|
Lease acquisition, geological,
geophysical and other |
|
|
3,100 |
|
|
|
3,168 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Total capital expenditures |
|
$ |
80,000 |
|
|
$ |
72,213 |
|
19
Financing activities
We borrowed $83.9 million and $53.5 million under our revolving credit facility during nine months
ended September 30, 2008 and 2007, respectively. We repaid $60.4 million and $47.9 million of the
amounts borrowed under the revolving credit facility during the nine months ended September 30,
2008 and 2007, respectively. Additionally, we borrowed $20.0 million in the 2007 period from the
issuance of convertible debt.
Our current goal is to manage our borrowings to help us maintain financial flexibility and
liquidity, and to avoid the problems associated with highly leveraged companies of large interest
costs and possible debt reductions restricting ongoing operations.
We believe that cash flow from operations and borrowings under our revolving credit facility will
finance substantially all of our anticipated drilling, exploration and capital needs through the
remainder of 2008. We may also use our revolving credit facility for possible acquisitions and
temporary working capital needs. We also may determine to access the public equity or debt market
for potential acquisitions, working capital or other liquidity needs, if such financing is
available on acceptable terms. Given the current conditions of credit and capital markets, we
cannot predict whether additional liquidity from debt or equity financings beyond our credit
facility will be available on acceptable terms, or at all, in the foreseeable future.
Credit facility
We have a $200.0 million revolving loan agreement (Loan Agreement) with a borrowing base set at
$100.0 million and which is redetermined semi-annually on or before each April 1 and October 1
based on our oil and gas reserves. We or the lenders can each request one additional borrowing base
redetermination each calendar year. In October 2008, our lender group reconfirmed our $100 million
borrowing base. Our next scheduled redetermination date is April 1, 2009.
Although we believe our internally generated cash from operations and funds available under our
current revolving credit facility are sufficient to meet our working capital needs through the end
of 2008, current credit market conditions have resulted in lenders significantly tightening their
lending practices. To date
20
we have experienced no disruptions in our ability to access our credit facility. However, our
lenders have substantial ability to reduce our borrowing base on the basis of subjective factors,
including the loan collateral value that each lender, in its discretion and using the methodology,
assumptions and discount rates as such lender customarily uses in evaluating oil and gas
properties, assigns to our properties.
We cannot predict with certainty the impact to us of any further disruption in the credit
environment or guarantee that the lenders under our revolving credit facility will not decrease our
borrowing base in the future.
The maturity date under the Loan Agreement is July 31, 2010. The borrowings bear interest based on
the agent banks prime rate, or the sum of the LIBOR plus an applicable margin ranging from 1.25%
to 2.00% based on the borrowings outstanding compared to the borrowing base. We had outstanding
borrowings of $23.5 million at September 30, 2008. The interest rate applicable to our outstanding
borrowings was 5.0% and 6.6% as of September 30, 2008 and December 31, 2007, respectively. We were
in compliance with the covenants in the Loan Agreement at September 30, 2008.
On August 26, 2008, we entered into a third amendment (the Third Amendment) to the Loan
Agreement. The Third Amendment (i) added Fortis Capital Corp. and KeyBank National Association as
lenders under the Credit Agreement, (ii) allocated the lenders commitment percentages as The Frost
National Bank 30%, JPMorgan Chase Bank, NA 30%, Fortis Capital Corp. 20% and KeyBank National
Association 20%, (iii) added a covenant that we will not exceed a debt to EBITDAX ratio of 3.5 to
1.0, and (iv) clarified that secured parties under the Loan Agreement (and beneficiaries of Loan
Agreement guarantees) will include affiliates of lenders who enter into commodity derivatives
transactions with us.
At October 31, 2008, we had $27.1 million outstanding under our Loan Agreement.
We also have outstanding unused letters of credit under the Loan Agreement totaling $400,000 at
September 30, 2008, which reduce amounts available for borrowing under the Loan Agreement.
Contractual obligations
There have been no material changes to our contractual obligations during the nine months ended
September 30, 2008.
Off-balance sheet arrangements
From time to time, we enter into off-balance sheet arrangements and transactions that can give rise
to
off-balance sheet obligations. As of September 30, 2008, the off-balance sheet arrangements and
transactions that we have entered into include undrawn letters of credit, operating lease
agreements and gas transportation commitments. We do not believe that these arrangements are
reasonably likely to materially affect our liquidity or availability of, or requirements for,
capital resources.
21
Item 3. Quantitative and qualitative disclosures about market risk.
Some of the information below contains forward-looking statements. The primary objective of the
following information is to provide forward-looking quantitative and qualitative information about
our potential exposure to market risks. The term market risk refers to the risk of loss arising
from adverse changes in oil and gas prices, and other related factors. The disclosure is not meant
to be a precise indicator of expected future losses, but rather an indicator of reasonably possible
losses. This forward-looking information provides an indicator of how we view and manage our
ongoing market risk exposures. Our market risk sensitive instruments were entered into for
commodity derivative and investment purposes, not for trading purposes.
Commodity price risk
Given the current economic outlook, we expect commodity prices to remain volatile. Even modest
decreases in commodity prices can materially affect our revenues and cash flow. In addition, if
commodity prices remain suppressed for a significant amount of time, we could be required under
successful efforts accounting rules to perform a non-cash write down of our oil and gas properties.
We enter into financial swaps and collars to mitigate portions of the risk of market price
fluctuations. We do not designate such instruments as cash flow hedges. Accordingly, we record
open commodity derivative positions on our consolidated balance sheets at fair value and recognize
changes in such fair values as income (expense) on our consolidated statements of operations as
they occur.
As of September 30, 2008, we had the following commodity derivatives positions outstanding:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Period |
|
Volume (MMBtu) |
|
$/MMBtu |
|
|
Monthly |
|
Total |
|
Floor |
|
Ceiling |
|
Fixed |
NYMEX Henry Hub |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Costless collars 2008 |
|
|
173,000 |
|
|
|
520,000 |
|
|
$ |
7.50 |
|
|
$ |
11.45 |
|
|
|
|
|
Costless collars 2008 |
|
|
200,000 |
|
|
|
600,000 |
|
|
$ |
9.00 |
|
|
$ |
12.20 |
|
|
|
|
|
Costless collars 2009 |
|
|
180,000 |
|
|
|
2,160,000 |
|
|
$ |
7.50 |
|
|
$ |
10.50 |
|
|
|
|
|
Costless collars 2009 |
|
|
130,000 |
|
|
|
1,560,000 |
|
|
$ |
8.50 |
|
|
$ |
11.70 |
|
|
|
|
|
Fixed price swaps |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
4th quarter 2008 |
|
|
100,000 |
|
|
|
300,000 |
|
|
|
|
|
|
|
|
|
|
$ |
8.63 |
|
WAHA differential |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Fixed price swaps 2008 |
|
|
173,000 |
|
|
|
520,000 |
|
|
|
|
|
|
|
|
|
|
|
(0.69 |
) |
Fixed price swaps 2008 |
|
|
100,000 |
|
|
|
300,000 |
|
|
|
|
|
|
|
|
|
|
|
(0.67 |
) |
Fixed price swaps 2009 |
|
|
200,000 |
|
|
|
2,400,000 |
|
|
|
|
|
|
|
|
|
|
|
(0.61 |
) |
At September 30, 2008, the fair value of our open derivative contracts was an asset of $4.9
million. At December 31, 2007, the fair value of our open derivative contracts was an asset of
$868,000.
J.P. Morgan Ventures Energy Corporation is currently the only counterparty to our commodity
derivatives positions. We are exposed to credit losses in the event of nonperformance by the
counterparty on our commodity derivatives positions. However, we do not anticipate nonperformance
by the counterparty over the term of the commodity derivatives positions. JPMorgan Chase Bank, NA
is a participant in our credit facility and the collateral for the outstanding borrowings under our
revolving credit facility is used as collateral for our commodity derivatives.
22
Item 4T. Controls and procedures.
Our management, with the participation of our Chief Executive Officer and Chief Financial Officer,
has evaluated the effectiveness of our disclosure controls and procedures (as defined in Rules
13a-15(e) and 15d-15(e) under the Securities Exchange Act of 1934 (the Exchange Act)) as of
September 30, 2008. Based on this evaluation, our Chief Executive Officer and Chief Financial
Officer have concluded that, as of September 30, 2008, our disclosure controls and procedures were
effective, in that they ensure that information required to be disclosed by us in the reports that
we file or submit under the Exchange Act is (1) recorded, processed, summarized and reported within
the time periods specified in the SECs rules and forms, and (2) accumulated and communicated to
our management, including our Chief Executive Officer and Chief Financial Officer, as appropriate,
to allow timely decisions regarding required disclosure.
No changes to our internal control over financial reporting occurred during the three months ended
September 30, 2008 that have materially affected, or are reasonably likely to materially affect,
our internal control over financial reporting (as defined in Rules 13a-15(f) and 15d-15(f) under
the Exchange Act). The SECs rules under Section 404 of the Sarbanes-Oxley Act of 2002 become
applicable to us beginning with our Annual Report on Form 10-K for the year ending December 31,
2008 to be filed in the first quarter of 2009. We cannot give any assurance, however, that our
internal controls will be effective when Section 404 becomes applicable to us. Ineffective internal
controls could cause investors to lose confidence in our reported financial information and could
result in a lower trading price for our securities.
23
PART II OTHER INFORMATION
Item 1. Legal proceedings.
We are involved in various legal and regulatory proceedings arising in the normal course of
business. We do not believe that an adverse result in any pending legal or regulatory proceeding,
together or in the aggregate, would be material to our consolidated financial condition, results of
operations or cash flows.
Item 1A. Risk factors.
For a discussion of our potential risks and uncertainties, see the information under the heading
Risk Factors in our Annual Report on Form 10-K for the year ended December 31, 2007 filed with
the SEC on March 28, 2008, which is accessible on the SECs website at www.sec.gov and our website
at www.approachresources.com. Except as provided below, there have been no material changes to the
risk factors disclosed in our Annual Report on Form 10-K for the year ended December 31, 2007.
Gas and oil prices are volatile, and a decline in gas or oil prices could significantly affect our
business, financial condition or results of operations and our ability to meet our capital
expenditure requirements and financial commitments.
Our revenues, profitability and cash flow depend substantially upon the prices and demand for gas
and oil. The markets for these commodities are volatile, and even relatively modest drops in prices
can affect significantly our financial results and impede our growth. Prices for gas and oil
fluctuate widely in response to relatively minor changes in the supply and demand for gas and oil,
market uncertainty and a variety of additional factors beyond our control, such as:
|
|
the level of domestic and foreign consumer demand for gas and oil, |
|
|
|
domestic and foreign supply of gas and oil, |
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|
|
overall United States and global economic conditions, |
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|
|
price and quantity of foreign imports, |
|
|
|
commodity processing, gathering and transportation availability and the availability of
refining capacity, |
|
|
|
domestic and foreign governmental regulations, |
|
|
|
political conditions in or affecting other gas producing and oil producing countries, |
|
|
|
the ability of the members of the Organization of Petroleum Exporting Countries to agree to
and maintain oil price and production controls, |
|
|
|
weather conditions, including unseasonably warm winter weather, |
|
|
|
technological advances affecting gas and oil consumption, and |
|
|
|
price and availability of alternative fuels. |
24
Further, gas prices and oil prices do not necessarily fluctuate in direct relationship to each
other. Because more than 85% of our estimated proved reserves as of June 30, 2008 were gas
reserves, our financial results are more sensitive to movements in gas prices. Recent gas prices
have been extremely volatile and we expect this volatility to continue. For example, from January
1, 2008 to October 31, 2008, the NYMEX gas spot price ranged from a high of $13.58 per MMBtu to a
low of $6.12 per MMBtu.
The results of higher investment in the exploration for and production of gas and oil and other
factors, such as global economic and financial conditions discussed below, may cause the price of
gas to fall. Lower gas and oil prices may not only cause our revenues to decrease but also may
reduce the amount of gas and oil that we can produce economically. Substantial decreases in gas and
oil prices would render uneconomic some or all of our drilling locations. This may result in our
having to make substantial downward adjustments to our estimated proved reserves and could have a
material adverse effect on our financial condition, results of operations and cash flow. Further,
if gas and oil prices significantly decline for an extended period of time, we may, among other
things, be unable to maintain or increase our borrowing capacity, repay current or future
indebtedness or obtain additional capital on attractive terms, all of which can affect the value of
our common stock.
The deterioration of global economic and financial conditions and an extended decline in the price
of oil and natural gas would negatively impact our business, financial condition and results of
operations.
The global economic and financial crisis could lead to an extended national or global economic
recession. A slowdown in economic activity caused by a recession would likely reduce national and
worldwide demand for oil and natural gas and result in lower commodity prices. Substantial
decreases in oil and natural gas prices could have a material adverse effect on our business,
financial condition and results of operations, could limit our access to liquidity and credit and
could hinder our ability to fund our development program. The inability to execute our development
program could also lead to low production and reserve growth.
If credit and capital markets worsen, then we may not be able to obtain funding under our current
revolving credit facility or fund on acceptable terms. The inability to obtain funding could deter
or prevent us from meeting our future capital needs to fund our development program.
Capital and credit markets have experienced unprecedented volatility and disruption and continue to
be unpredictable. Given the current levels of market volatility and disruption, the availability
of funds from those markets has diminished substantially. Further, arising from concerns about the
stability of financial markets generally and the solvency of counterparties specifically, the cost
of accessing the credit markets has increased as many lenders have raised interest rates, enacted
tighter lending standards or altogether ceased to provide funding to borrowers. Additionally, even
if lenders are able to provide funding to borrowers, interest rates may rise in the future and
therefore increase the cost of outstanding borrowings that we may incur under our revolving credit
facility.
Moreover, we may be unable to obtain adequate funding under our current credit facility. First,
our lenders may be unwilling or unable to meet their funding commitments. Second, our borrowing
base under our current credit facility is redetermined semiannually. Our lenders have substantial
ability to reduce our borrowing base on the basis of subjective factors. If gas and oil prices
significantly decline for an extended period of time, our lenders could redetermine the borrowing
base by evaluating our reserves and substantially lower gas and oil prices. Such determination
could result in a negative revision to our proved reserve value and reduce our borrowing base.
25
Due to these capital and credit market conditions, we cannot be certain that funding will be
available if needed and to the extent required, on acceptable terms. If funding is not available
when needed, or is
available only on unfavorable terms, we may be unable to meet our obligations as they come due or
be required to post collateral to support our obligations, or we may be unable to implement our
development program, grow our existing business through acquisitions or joint ventures or otherwise
take advantage of business opportunities or respond to competitive pressures, any of which could
have a material adverse effect on our business, financial condition and results of operations.
Item 2. Unregistered sales of equity securities and use of proceeds.
None.
Item 3. Defaults upon senior securities.
None.
Item 4. Submission of matters to a vote of security holders.
None.
Item 5. Other information.
None.
Item 6. Exhibits.
See Index to Exhibits following the signature page of this report for a description of the
exhibits filed as part of this report.
26
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.
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APPROACH RESOURCES INC.
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By: |
/s/ J. Ross Craft
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|
|
J. Ross Craft |
|
|
|
President and Chief Executive Officer |
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|
Date: November 6, 2008
Index to Exhibits
|
|
|
|
|
Exhibit |
|
|
Number |
|
Exhibit |
3.1
|
|
|
|
Restated Certificate of Incorporation of Approach
Resources Inc. (filed as Exhibit 3.1 to the Companys
Quarterly Report on Form 10-Q filed December 13, 2007
and incorporated herein by reference). |
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|
|
3.2
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|
|
|
Restated Bylaws of Approach Resources Inc. (filed as
Exhibit 3.2 to the Companys Quarterly Report on
Form 10-Q filed December 13, 2007 and incorporated
herein by reference). |
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|
|
4.1
|
|
|
|
Specimen Common Stock Certificate (filed as Exhibit
4.1 to the Companys Registration Statement on Form
S-1/A filed October 18, 2007 (File No. 333-144512) and
incorporated herein by reference). |
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|
|
|
10.1
|
|
|
|
Form of Indemnity Agreement between Approach Resources
Inc. and each of its directors and officers (filed as
Exhibit 10.1 to the Companys Registration Statement
on Form S-1/A filed September 13, 2007 (File No.
333-144512) and incorporated herein by reference). |
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|
|
10.2
|
|
|
|
Employment Agreement by and between Approach Resources
Inc. and J. Ross Craft dated January 1, 2003 (filed as
Exhibit 10.3 to the Companys Registration Statement
on Form S-1 filed July 12, 2007 and incorporated
herein by reference). |
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|
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|
|
10.3
|
|
|
|
Employment Agreement by and between Approach Resources
Inc. and Steven P. Smart dated January 1, 2003 (filed
as Exhibit 10.4 to the Companys Registration
Statement on Form S-1 filed July 12, 2007 and
incorporated herein by reference). |
|
|
|
|
|
10.4
|
|
|
|
Employment Agreement by and between Approach Resources
Inc. and Glenn W. Reed dated January 1, 2003 (filed as
Exhibit 10.5 to the Companys Registration Statement
on Form S-1 filed July 12, 2007 and incorporated
herein by reference). |
|
|
|
|
|
10.5
|
|
|
|
Approach Resources Inc. 2007 Stock Incentive Plan,
effective as of June 28, 2007 (filed as Exhibit 10.6
to the Companys Registration Statement on Form S-1
filed July 12, 2007 and incorporated herein by
reference). |
|
|
|
|
|
10.6
|
|
|
|
Form of Business Opportunities Agreement among
Approach Resources Inc. and the other signatories
thereto (filed as Exhibit 10.11 to the Companys
Registration Statement on Form S-1/A filed October 18,
2007 (File No. 333-144512) and incorporated herein by
reference). |
|
|
|
|
|
10.7
|
|
|
|
Form of Option Agreement under 2003 Stock Option Plan
(filed as Exhibit 10.12 to the Companys Registration
Statement on Form S-1 filed July 12, 2007 and
incorporated herein by reference). |
|
|
|
|
|
10.8
|
|
|
|
Restricted Stock Award Agreement by and between
Approach Resources Inc. and J. Curtis Henderson dated
March 14, 2007 (filed as Exhibit 10.13 to the
Companys Registration Statement on Form S-1 filed
July 12, 2007 and incorporated herein by reference). |
|
|
|
|
|
Exhibit |
|
|
Number |
|
Exhibit |
10.9
|
|
|
|
Form of Summary of Stock Option Grant under Approach
Resources Inc. 2007 Stock Incentive Plan (filed as
Exhibit 10.14 to the Companys Registration Statement
on Form S-1/A filed October 18, 2007 (File No.
333-144512) and incorporated herein by reference). |
|
|
|
|
|
10.10*
|
|
|
|
Form of Stock Award Agreement under Approach Resources
Inc. 2007 Stock Incentive Plan. |
|
|
|
|
|
10.11
|
|
|
|
Registration Rights Agreement dated as of November 14,
2007, by and among Approach Resources Inc. and
investors identified therein (filed as Exhibit 10.1 to
the Companys Current Report on Form 8-K/A filed
December 3, 2007 and incorporated herein by
reference). |
|
|
|
|
|
10.12
|
|
|
|
Gas Purchase Contract dated May 1, 2004 between Ozona
Pipeline Energy Company, as Buyer, and Approach
Resources I, L.P. and certain other parties identified
therein (filed as Exhibit 10.18 to the Companys
Registration Statement on Form S-1/A filed September
13, 2007 (File No. 333-144512) and incorporated herein
by reference). |
|
|
|
|
|
10.13
|
|
|
|
Agreement Regarding Gas Purchase Contract dated May
26, 2006 between Ozona Pipeline Energy Company, as
Buyer, and Approach Resources I, L.P. and certain
other parties identified therein (filed as Exhibit
10.19 to the Companys Registration Statement on Form
S-1/A filed September 13, 2007 (File No. 333-144512)
and incorporated herein by reference). |
|
|
|
|
|
10.14
|
|
|
|
Carry and Earning Agreement dated July 13, 2007 by and
between EnCana Oil & Gas (USA) (filed as Exhibit 10.22
to the Companys Registration Statement on Form S-1/A
filed September 13, 2007 (File No. 333-144512) and
incorporated herein by reference). |
|
|
|
|
|
10.15
|
|
|
|
Oil & Gas Lease dated February 27, 2007 between the
lessors identified therein and Approach Oil & Gas
Inc., as successor to Lynx Production Company, Inc.
(filed as Exhibit 10.23 to the Companys Registration
Statement on Form S-1/A filed September 13, 2007 (File
No. 333-144512) and incorporated herein by reference). |
|
|
|
|
|
10.16
|
|
|
|
Specimen Oil and Gas Lease for Boomerang prospect
between lessors and Approach Oil & Gas Inc., as
successor to The Keeton Group, LLC, as lessee (filed
as Exhibit 10.24 to the Companys Registration
Statement on Form S-1/A filed September 13, 2007 (File
No. 333-144512) and incorporated herein by reference). |
|
|
|
|
|
10.17
|
|
|
|
Lease Crude Oil Purchase Agreement dated May 1, 2004
by and between ConocoPhillips and Approach Operating
LLC (filed as Exhibit 10.26 to the Companys
Registration Statement on Form S-1/A filed October 18,
2007 (File No. 333-144512) and incorporated herein by
reference). |
|
|
|
|
|
10.18
|
|
|
|
Gas Purchase Agreement dated as of November 21, 2007
between WTG Benedum Joint Venture, as Buyer, and
Approach Oil & Gas Inc. and Approach Operating, LLC,
as Seller (filed as Exhibit 10.1 to the Companys
Current Report on Form 8-K filed November 28, 2007 and
incorporated herein by reference). |
|
|
|
|
|
|
|
|
|
|
Exhibit |
|
|
Number |
|
Exhibit |
10.19
|
|
|
|
$200,000,000 Revolving Credit Agreement dated as of
January 18, 2008 among Approach Resources Inc., as
borrower, The Frost National Bank, as administrative
agent and lender, and the financial institutions named
therein (filed as Exhibit 10.1 to the Companys
Current Report on Form 8-K filed January 18, 2008 and
incorporated herein by reference). |
|
|
|
|
|
10.20
|
|
|
|
Amendment dated February 19, 2008 to Credit Agreement
among Approach Resources Inc., as borrower, The Frost
National Bank, as administrative agent and lender,
JPMorgan Chase Bank, NA, as lender, and Approach Oil &
Gas Inc., Approach Oil & Gas (Canada) Inc. and
Approach Resources I, LP, as guarantors, dated as of
January 18, 2008 (filed as Exhibit 10.1 to the
Companys Current Report on Form 8-K filed February
22, 2008 and incorporated herein by reference). |
|
|
|
|
|
10.21
|
|
|
|
Amendment dated May 6, 2008 to Credit Agreement among
Approach Resources Inc., as borrower, The Frost
National Bank, as administrative agent and lender,
JPMorgan Chase Bank, NA, as lender, and Approach Oil &
Gas Inc., Approach Oil & Gas (Canada) Inc. and
Approach Resources I, LP, as guarantors, dated as of
January 18, 2008 (filed as Exhibit 99.1 to the
Companys Current Report on Form 8-K filed August 28,
2008 and incorporated herein by reference). |
|
|
|
|
|
10.22
|
|
|
|
Amendment dated August 26, 2008 to Credit Agreement
among Approach Resources Inc., as borrower, The Frost
National Bank, as administrative agent and lender,
JPMorgan Chase Bank, NA, Fortis Capital Corp. and
KeyBank National Association, as lenders, and Approach
Oil & Gas Inc., Approach Oil & Gas (Canada) Inc. and
Approach Resources I, LP, as guarantors, dated as of
January 18, 2008 (filed as Exhibit 10.1 to the
Companys Current Report on Form 8-K filed August 28,
2008 and incorporated herein by reference). |
|
|
|
|
|
31.1*
|
|
|
|
Certification of Chief Executive Officer pursuant to
Section 302 of the Sarbanes-Oxley Act of 2002. |
|
|
|
|
|
31.2*
|
|
|
|
Certification of Chief Financial Officer pursuant to
Section 302 of the Sarbanes-Oxley Act of 2002. |
|
|
|
|
|
32.1*
|
|
|
|
Certification of Chief Executive Officer pursuant to
Section 906 of the Sarbanes-Oxley Act of 2002. |
|
|
|
|
|
32.2*
|
|
|
|
Certification of Chief Financial Officer pursuant to
Section 906 of the Sarbanes-Oxley Act of 2002. |