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8-K - FORM 8-K - Oasis Petroleum Inc. | h82251e8vk.htm |
Exhibit 99.1
Oasis Petroleum Inc. Announces Quarter Ending March 31, 2011 Earnings and Year-over-Year
Production Growth of 146%
Production Growth of 146%
Houston, Texas May 11, 2011 Oasis Petroleum Inc. (NYSE: OAS) (Oasis or the Company) today
announced financial and operational results for the quarter ended March 31, 2011.
Highlights for the three months ended March 31, 2011 include:
| Grew average daily production to 8,090 barrels of oil equivalent (Boe) per day, a 146% increase over the first quarter of 2010 and a sequential increase of 8% over the fourth quarter of 2010. | ||
| Increased Adjusted EBITDA to $41.1 million, an increase of $29.5 million over the first quarter of 2010 and a sequential increase of $9.9 million over the fourth quarter of 2010. For a definition of Adjusted EBITDA and a reconciliation of Adjusted EBITDA to net loss and net cash provided by operating activities, see Non-GAAP Financial Measure below. | ||
| Issued $400 million of 7.25% senior unsecured notes due 2019 on February 2, 2011. |
Our team delivered production growth despite a tough winter, said Thomas B. Nusz, Oasis Chairman
and Chief Executive Officer. We continue to lock-in key contracts and invest infrastructure
capital that will improve our ability to grow our production, increase our revenue, and lower our
operated expenses. We now have six rigs running in West Williston and one in East Nesson, and we
have two full-time frac crews working on behalf of Oasis. We have agreements with third parties
that are building out crude oil and natural gas infrastructure, and are investing our own capital
into salt water disposal systems. Overall, Oasis is taking the right steps to position the Company
for the tremendous growth that is expected to come from executing our resource conversion
strategy.
Operational and Financial Update
Average daily production for the first quarter of 2011 was 8,090 Boe per day (99% was produced from
Williston Basin properties), an increase of 146% as compared to 3,295 Boe per day in the first
quarter of 2010. Sequential quarter-over-quarter production growth was 579 Boe per day, or 8%. In
the first quarter of 2011, 95% of the production was from oil. Average daily production by project
area is listed in the following table:
Average Daily Production for the Three Months Ended (Boepd): | ||||||||||||||||
Project Area | Mar 31, 2011 | Dec 31, 2010 | Change | % Change | ||||||||||||
Williston Basin: |
||||||||||||||||
West Williston |
4,302 | 3,366 | 936 | 28 | % | |||||||||||
East Nesson |
2,158 | 2,295 | (137 | ) | -6 | % | ||||||||||
Sanish |
1,518 | 1,774 | (256 | ) | -14 | % | ||||||||||
Total Williston Basin |
7,978 | 7,435 | 543 | 7 | % | |||||||||||
Other |
112 | 76 | 36 | 47 | % | |||||||||||
Total |
8,090 | 7,511 | 579 | 8 | % | |||||||||||
Average price per barrel of oil, without realized derivatives, was $82.33 in the first quarter
of 2011, compared to $70.21 in the first quarter of 2010 and $73.05 in the fourth quarter of 2010.
The average price differential compared to West Texas Intermediate crude oil index prices was 13%
in the first quarter 2011, compared to 11% in the first quarter of 2010 and 14% in the fourth
quarter of 2010.
Total revenue for the first quarter of 2011 was $58.7 million compared to $20.1 million for the
first quarter of 2010, an increase of 192%. Sequential quarter-over-quarter revenue growth was
$9.6 million, or 20%.
The following tables show the Companys drilling activity by project area in the Williston Basin as
of March 31, 2011:
1
Bakken/Three Forks Wells | ||||||||||||||||
Total Williston | ||||||||||||||||
West Williston | East Nesson | Sanish | Basin | |||||||||||||
Producing Wells |
||||||||||||||||
Producing on or before December 31, 2010: |
||||||||||||||||
Gross Operated (Net) |
20 (17.0 | ) | 31 (25.8 | ) | | 51 (42.8 | ) | |||||||||
Gross Non-Operated (Net) |
33 (3.0 | ) | 35 (3.5 | ) | 123(9.6 | ) | 191(16.1 | ) | ||||||||
Production started in Q1 2011 |
||||||||||||||||
Gross Operated (Net) |
8 (5.5 | ) | 0 | 0 | 8 (5.5 | ) | ||||||||||
Gross Non-Operated (Net) |
0 | 4 (0.3 | ) | 11 (0.6 | ) | 15 (0.9 | ) | |||||||||
Wells Waiting on Completion on 3/31/11: |
||||||||||||||||
Gross Operated (Net) |
19 (14.8 | ) | 4 (2.6 | ) | 0 | 23 (17.4 | ) | |||||||||
Gross Non-Operated (Net) |
3 (0.1 | ) | 4 (0.3 | ) | 9 (0.7 | ) | 16 (1.1 | ) | ||||||||
Wells Drilling on 3/31/11: |
||||||||||||||||
Gross Operated (Net) |
2 (1.4 | ) | 1 (0.5 | ) | 0 | 3 (1.9 | ) | |||||||||
Gross Non-Operated (Net) |
0 | 0 | 5 (0.2 | ) | 5 (0.2 | ) |
Note: 3 rigs were moving to new locations on March 31, 2011 |
Lease operating expenses increased $3.0 million to $5.9 million for the first quarter 2011
compared to the first quarter 2010 and increased by $0.4 million in the first quarter 2011 compared
to the fourth quarter 2010. Lease operating expenses decreased by $1.88 per Boe, or 19%, to $8.16
per Boe in the first quarter 2011 compared to the first quarter 2010. Lease operating expenses
increased by $0.24 per Boe, or 3%, in the first quarter 2011 compared to the fourth quarter 2010 of
$7.92 per Boe.
Production taxes increased by $4.2 million to $6.1 million for the first quarter of 2011
compared to the first quarter of 2010 and increased by $0.4 million in first quarter 2011 compared
to the fourth quarter 2010. Production taxes as a percent of revenue were 10.4% in the first
quarter 2011, 9.5% in the first quarter 2010, and 11.5% in the fourth quarter 2010. Production
taxes were lower in the first quarter of 2011 compared to the fourth quarter of 2010, primarily due to
lower tax rates on wells recently drilled in Montana.
Depreciation, depletion and amortization totaled $13.8 million in the first quarter of 2011, $5.8
million in the first quarter 2010, and $13.4 million in the fourth quarter 2010. Depreciation,
depletion and amortization was $18.97 per Boe in the first quarter of 2011, $19.73 per Boe in the
first quarter 2010, and $19.46 per Boe in the fourth quarter 2010.
The Company recorded non-cash charges related to impairment of oil and natural gas properties of
$1.4 million in the first quarter of 2011 related to unproved property leases that expired during
the period.
General and administrative expenses totaled $6.0 million in the first quarter of 2011, $3.5 million
in the first quarter 2010, and $7.6 million in the fourth quarter 2010. General and administrative
expenses were $8.17 per Boe in the first quarter of 2011, $11.86 per Boe in the first quarter 2010,
and $11.05 per Boe in the fourth quarter 2010.
The sequential decrease in general and administrative expenses was primarily due to decreased costs
related to employee compensation as the fourth quarter of 2010 included the bonuses related to the
full year 2010. Additionally, the Company recorded approximately $0.5 million, or $0.72 per Boe,
for restricted stock based compensation, which is included in general and administrative expenses
for the first quarter of 2011.
Prior to the Companys corporate reorganization, the Company was a limited liability company not
subject to entity-level income tax. Accordingly, no provision for federal or state corporate income
taxes was recorded for the three months ended March 31, 2010 as taxable income was allocated
directly to equity holders. In connection with the closing of the IPO in June 2010, the Company
merged into a corporation and became subject to federal and state entity-level taxation. The
Companys income tax benefit was $4.2 million for the three months ended March 31, 2011, resulting
in an effective tax rate of 37.8%. The Companys effective tax rate is expected to continue to
closely resemble the statutory rate applicable to the federal and the blended state rate of the
states in which the Company conducts business.
2
Adjusted EBITDA for the first quarter of 2011 was $41.1 million, an increase of $29.5 million, or
254%, over the first quarter of 2010 of $11.6 million, and a 32% increase over the fourth quarter
of 2010 of $31.2 million.
The Company reported net loss of $6.8 million, or $0.07 per weighted average diluted share, as
compared to a net loss of $3.2 million for the first quarter of 2010. The first quarter of 2011
included an unrealized loss on derivative instruments of $31.2 million.
Capital Expenditures and Liquidity
Oasis exploration and production capital expenditures were $75.5 million for the first quarter of
2011. The Companys capital expenditures for drilling, development, and acquisition and
undeveloped acreage costs for the first quarter of 2011 are summarized by project area in the
following unaudited table:
(In thousands) | ||||
Project Area | 1Q 11 | |||
West Williston |
$ | 61,314 | ||
East Nesson |
9,787 | |||
Sanish |
4,407 | |||
Other (Barnett shale) |
2 | |||
Total (1) |
$ | 75,510 | ||
(1) | Consolidated capital expenditures reflected in the table above differ from the amounts shown in the statement of cash flows in the Companys condensed consolidated financial statements because amounts reflected in the table include changes in accrued liabilities from the previous reporting period for capital expenditures, while the amounts presented in the statement of cash flows are presented on a cash basis. The capital expenditures amount presented in the statement of cash flows also includes cash paid for other property and equipment as well as cash paid for asset retirement obligations. |
On March 31, 2011, Oasis had total cash and cash equivalents of $355.0 million and short-term
investments of $115.0 million. The Company had no outstanding indebtedness under its $137.5 million
revolving credit facility. On February 2, 2011, the Company issued $400 million of 7.25% senior
unsecured notes (the Notes). The Notes resulted in net proceeds to the Company of approximately
$390 million and will mature on February 1, 2019.
Risk Management
As of May 10, 2011, the Company had the following outstanding commodity derivative contracts,
all of which settle monthly:
3
Critical Prices ($ / Barrel) | ||||||||||||||||||||
Wtd Avg | Barrels of | |||||||||||||||||||
Type | Remaining Term | Sub-Floor | Floor | Ceiling | Oil per Day | |||||||||||||||
Two-Way Collar |
8 Months (May-Dec 2011) | $ | 60.00 | $ | 80.25 | 448 | ||||||||||||||
Two-Way Collar |
8 Months (May-Dec 2011) | $ | 70.00 | $ | 98.85 | 400 | ||||||||||||||
Two-Way Collar |
8 Months (May-Dec 2011) | $ | 75.00 | $ | 92.45 | 1,200 | ||||||||||||||
Two-Way Collar |
8 Months (May-Dec 2011) | $ | 85.00 | $ | 101.62 | 2,500 | ||||||||||||||
Two-Way Collar |
8 Months (May-Dec 2011) | $ | 90.00 | $ | 104.65 | 1,000 | ||||||||||||||
Two-Way Collar |
8 Months (May-Dec 2011) | $ | 95.00 | $ | 123.39 | 2,500 | ||||||||||||||
2011 Total / Weighted Average Two-Way Collars | $ | 85.10 | $ | 106.06 | 8,048 | |||||||||||||||
Three-Way Collar |
8 Months (May-Dec 2011) | $ | 60.00 | $ | 80.00 | $ | 94.98 | 500 | ||||||||||||
2011
Total Collars |
8,548 | |||||||||||||||||||
Two-Way Collar |
12 Months (Jan-Dec 2012) | $ | 75.00 | $ | 93.00 | 500 | ||||||||||||||
Two-Way Collar |
12 Months (Jan-Dec 2012) | $ | 80.00 | $ | 103.25 | 1,000 | ||||||||||||||
Two-Way Collar |
12 Months (Jan-Dec 2012) | $ | 85.00 | $ | 102.42 | 1,000 | ||||||||||||||
Two-Way Collar |
12 Months (Jan-Dec 2012) | $ | 90.00 | $ | 112.62 | 1,500 | ||||||||||||||
Two-Way Collar |
12 Months (Jan-Dec 2012) | $ | 95.00 | $ | 116.30 | 500 | ||||||||||||||
2012 Total / Weighted Average Two-Way Collars | $ | 85.56 | $ | 106.50 | 4,500 | |||||||||||||||
Three-Way Collar |
12 Months (Jan-Dec 2012) | $ | 65.00 | $ | 85.00 | $ | 108.08 | 1,500 | ||||||||||||
Three-Way Collar |
12 Months (Jan-Dec 2012) | $ | 70.00 | $ | 90.00 | $ | 118.30 | 500 | ||||||||||||
2012 Total / Weighted Average Three-Way Collars | $ | 66.25 | $ | 86.25 | $ | 110.64 | 2,000 | |||||||||||||
2012 Total Collars |
6,500 | |||||||||||||||||||
Two-Way Collar |
12 Months (Jan-Dec 2013) | $ | 90.00 | $ | 107.20 | 1,000 | ||||||||||||||
Three-Way Collar |
12 Months (Jan-Dec 2013) | $ | 70.00 | $ | 90.00 | $ | 122.45 | 1,000 | ||||||||||||
2013 Total Collars |
2,000 | |||||||||||||||||||
Conference Call Information
The Company will host a conference call on Thursday, May 12, 2011, at 10:00 a.m. Central Time to
discuss its first quarter 2011 financial and operational results. Investors, analysts and other
interested parties are invited to listen to the conference call via the Companys website at
www.oasispetroleum.com or by dialing (877) 621-0256 (US participants) or (706) 634-0151
(International participants) with the Conference ID of 62640075. A recording of the conference
call will be available by dialing (800) 642-1687 (US participants) or (706) 645-9291 (International
participants) using the Conference ID of 62640075 beginning at 1:00 p.m. Central Time on the day of
the call until Thursday, May 19, 2011. The conference call will also be available for replay for
30 days at www.oasispetroleum.com.
Upcoming Conference
Oasis also announced that management is scheduled on June 7, 2011 to participate in a Williston
Basin panel at 9:30 a.m. Eastern Time and to present at 12:35 p.m. Eastern Time at the 2011 RBC
Capital Markets Global Energy and Power Conference.
Forward-Looking Statements
This press release contains forward-looking statements within the meaning of Section 27A of the
Securities Act of 1933 and Section 21E of the Securities Exchange Act of 1934. All statements,
other than statements of historical facts, included in this press release that address activities,
events or developments that the Company expects, believes or anticipates will or may occur in the
future are forward-looking statements. Without limiting the generality of the foregoing,
forward-looking statements contained in this press release specifically include the expectations of
plans, strategies, objectives and anticipated financial and operating results of the Company,
including the Companys drilling program, production, derivatives activities, capital expenditure
levels and other
4
guidance included in this press release. These statements are based on certain
assumptions made by the Company based on managements experience and perception of historical
trends, current conditions, anticipated future developments and other factors believed to be
appropriate. Such statements are subject to a number of assumptions, risks and uncertainties, many
of which are beyond the control of the Company, which may cause actual results to differ materially
from those implied or expressed by the forward-looking statements. These include changes in oil and
natural gas prices, the timing of planned capital expenditures, availability of acquisitions,
uncertainties in estimating proved reserves and forecasting production results, operational factors
affecting the commencement or maintenance of producing wells, the condition of the capital markets
generally, as well as the Companys ability to access them, the proximity to and capacity of
transportation facilities, and uncertainties regarding environmental regulations or litigation and
other legal or regulatory developments affecting the Companys business and other important factors
that could cause actual results to differ materially from those projected as described in the
Companys reports filed with the SEC.
Any forward-looking statement speaks only as of the date on which such statement is made and the
Company undertakes no obligation to correct or update any forward-looking statement, whether as a
result of new information, future events or otherwise, except as required by applicable law.
About Oasis Petroleum Inc.
Oasis is an independent exploration and production company focused on the acquisition and
development of unconventional oil and natural gas resources, primarily operating in the Williston
Basin. For more information, please visit the Companys website
at www.oasispetroleum.com.
Contact:
Oasis Petroleum Inc.
Richard Robuck, (281) 404-9600
Director Investor Relations
Richard Robuck, (281) 404-9600
Director Investor Relations
5
Oasis Petroleum Inc. Financial Statements
Oasis Petroleum Inc.
Condensed Consolidated Balance Sheet
(Unaudited)
Condensed Consolidated Balance Sheet
(Unaudited)
March 31, | December 31, | |||||||
2011 | 2010 | |||||||
(In thousands, except per share data) | ||||||||
ASSETS |
||||||||
Current assets |
||||||||
Cash and cash
equivalents |
$ | 354,990 | $ | 143,520 | ||||
Short-term investments |
114,974 | | ||||||
Accounts receivable oil and gas revenues |
27,820 | 25,909 | ||||||
Accounts receivable joint interest partners |
33,352 | 28,596 | ||||||
Inventory |
1,008 | 1,323 | ||||||
Prepaid expenses |
11 | 490 | ||||||
Advances to joint interest partners |
2,710 | 3,595 | ||||||
Deferred income taxes |
9,624 | 2,470 | ||||||
Other current assets |
113 | | ||||||
Total current assets |
544,602 | 205,903 | ||||||
Property, plant and equipment |
||||||||
Oil and gas properties (successful efforts method) |
655,759 | 580,968 | ||||||
Other property and
equipment |
2,262 | 1,970 | ||||||
Less: accumulated depreciation, depletion, amortization
and impairment |
(113,048 | ) | (99,255 | ) | ||||
Total property, plant and equipment, net |
544,973 | 483,683 | ||||||
Deferred costs and other assets |
12,018 | 2,266 | ||||||
Total assets |
$ | 1,101,593 | $ | 691,852 | ||||
LIABILITIES AND STOCKHOLDERS EQUITY |
||||||||
Current liabilities |
||||||||
Accounts payable |
$ | 643 | $ | 8,198 | ||||
Advances from joint interest partners |
8,039 | 3,101 | ||||||
Revenues payable and production taxes |
5,622 | 6,180 | ||||||
Accrued liabilities |
37,508 | 58,239 | ||||||
Accrued interest payable |
4,755 | 2 | ||||||
Derivative instruments |
25,497 | 6,543 | ||||||
Total current liabilities |
82,064 | 82,263 | ||||||
Long-term debt |
400,000 | | ||||||
Asset retirement
obligations |
9,287 | 7,640 | ||||||
Derivative instruments |
16,143 | 3,943 | ||||||
Deferred income taxes |
48,425 | 45,432 | ||||||
Other liabilities |
759 | 780 | ||||||
Total liabilities |
556,678 | 140,058 | ||||||
Commitments and contingencies |
||||||||
Stockholders equity |
||||||||
Common stock, $0.01 par value; 300,000,000 shares
authorized; 92,407,800 shares issued and outstanding |
920 | 920 | ||||||
Treasury stock, at cost; 20,595 shares |
(559 | ) | | |||||
Additional paid-in-capital |
644,246 | 643,719 | ||||||
Retained deficit |
(99,692 | ) | (92,845 | ) | ||||
Total stockholders equity |
544,915 | 551,794 | ||||||
Total liabilities and stockholders equity |
$ | 1,101,593 | $ | 691,852 | ||||
6
Oasis Petroleum Inc.
Condensed Consolidated Statement of Operations
(Unaudited)
Condensed Consolidated Statement of Operations
(Unaudited)
Three Months Ended March 31, | ||||||||
2011 | 2010 | |||||||
(In thousands, except per share amount) | ||||||||
Oil and gas revenues |
$ | 58,744 | $ | 20,068 | ||||
Expenses |
||||||||
Lease operating expenses |
5,942 | 2,977 | ||||||
Production taxes |
6,083 | 1,910 | ||||||
Depreciation, depletion and amortization |
13,812 | 5,849 | ||||||
Exploration expenses |
32 | 18 | ||||||
Impairment of oil and gas properties |
1,381 | 3,077 | ||||||
Stock-based compensation expenses |
| 5,200 | ||||||
General and administrative expenses |
5,950 | 3,516 | ||||||
Total expenses |
33,200 | 22,547 | ||||||
Operating income (loss) |
25,544 | (2,479 | ) | |||||
Other income (expense) |
||||||||
Change in unrealized gain (loss) on derivative
instruments |
(31,154 | ) | (391 | ) | ||||
Realized gain (loss) on derivative
instruments |
(512 | ) | (26 | ) | ||||
Interest expense |
(5,198 | ) | (338 | ) | ||||
Other income (expense) |
312 | 3 | ||||||
Total other income (expense) |
(36,552 | ) | (752 | ) | ||||
Income (loss) before income taxes |
(11,008 | ) | (3,231 | ) | ||||
Income tax benefit (expense) |
4,161 | | ||||||
Net income (loss) |
$ | (6,847 | ) | $ | (3,231 | ) | ||
Income (loss) per share: |
||||||||
Basic and diluted |
$ | (0.07 | ) | $ | | |||
Weighted average shares outstanding: |
||||||||
Basic and diluted |
92,047 | |
7
Oasis Petroleum Inc.
Selected Financial and Operational Statistics
(Unaudited)
Selected Financial and Operational Statistics
(Unaudited)
Three Months Ended March 31, | ||||||||
2011 | 2010 | |||||||
Operating results ($ in thousands): |
||||||||
Revenues |
||||||||
Oil |
$ | 57,172 | $ | 18,943 | ||||
Natural gas |
1,572 | 1,125 | ||||||
Total oil and gas revenues |
58,744 | 20,068 | ||||||
Production data (units): |
||||||||
Oil (MBbls) |
694 | 270 | ||||||
Natural gas (MMcf) |
202 | 160 | ||||||
Oil equivalents (MBoe) |
728 | 297 | ||||||
Average daily production (Boe/d) |
8,090 | 3,295 | ||||||
Average sales prices: |
||||||||
Oil, without realized derivatives (per Bbl) |
$ | 82.33 | $ | 70.21 | ||||
Oil, with realized derivatives (1) (per Bbl) |
81.59 | 70.12 | ||||||
Natural gas (per Mcf) |
7.78 | 7.02 | ||||||
Cost and expense (per Boe of production): |
||||||||
Lease operating expenses |
$ | 8.16 | $ | 10.04 | ||||
Production taxes |
8.35 | 6.44 | ||||||
Depreciation, depletion and amortization |
18.97 | 19.73 | ||||||
Stock-based compensation expenses |
| 17.54 | ||||||
General and administrative expenses |
8.17 | 11.86 |
(1) | Realized prices include realized gains or losses on cash settlements for commodity derivatives, which do not qualify for and were not designated as hedging instruments for accounting purposes. |
8
Oasis Petroleum Inc.
Condensed Consolidated Statement of Cash Flows
(Unaudited)
Condensed Consolidated Statement of Cash Flows
(Unaudited)
Three Months Ended March 31, | ||||||||
2011 | 2010 | |||||||
(In thousands) | ||||||||
Cash Flows from Operating Activities: |
||||||||
Net loss |
$ | (6,847 | ) | $ | (3,231 | ) | ||
Adjustments to reconcile net loss to net cash provided by operating activities: |
||||||||
Depreciation, depletion and amortization |
13,812 | 5,849 | ||||||
Impairment of oil and gas properties |
1,381 | 3,077 | ||||||
Deferred income taxes |
(4,161 | ) | | |||||
Derivative instruments |
31,666 | 417 | ||||||
Stock-based compensation expenses |
527 | 5,200 | ||||||
Debt discount amortization and other |
256 | 185 | ||||||
Working capital and other changes: |
||||||||
Change in accounts receivable |
(6,667 | ) | (5,263 | ) | ||||
Change in inventory |
(37 | ) | 269 | |||||
Change in prepaid expenses |
479 | 57 | ||||||
Change in other current assets |
(113 | ) | | |||||
Change in other assets |
(3 | ) | | |||||
Change in accounts payable and accrued liabilities |
(7,448 | ) | 1,153 | |||||
Change in other liabilities |
| (11 | ) | |||||
Net cash provided by operating activities |
22,845 | 7,702 | ||||||
Cash flows from investing activities: |
||||||||
Capital expenditures |
(91,126 | ) | (34,561 | ) | ||||
Derivative settlements |
(512 | ) | (26 | ) | ||||
Purchases of short-term investments |
(114,974 | ) | | |||||
Advances to joint interest partners |
885 | 1,888 | ||||||
Advances from joint interest partners |
4,938 | 458 | ||||||
Net cash used in investing activities |
(200,789 | ) | (32,241 | ) | ||||
Cash flows from financing activities: |
||||||||
Proceeds from credit facility |
| 20,000 | ||||||
Principal payments on credit facility |
| (32,000 | ) | |||||
Proceeds from issuance of senior notes |
400,000 | | ||||||
Purchases of treasury stock |
(559 | ) | | |||||
Debt issuance costs |
(10,027 | ) | (1,413 | ) | ||||
Net cash provided by (used in) financing activities |
389,414 | (13,413 | ) | |||||
Increase (decrease) in cash and cash equivalents |
||||||||
Cash and cash equivalents: |
211,470 | (37,952 | ) | |||||
Beginning of period |
143,520 | 40,562 | ||||||
End of period |
$ | 354,990 | $ | 2,610 | ||||
Supplemental non-cash transactions: |
||||||||
Change in accrued capital expenditures |
$ | (16,644 | ) | $ | 2,433 | |||
Asset retirement obligations |
1,656 | 283 |
9
Non-GAAP Financial Measures
Adjusted EBITDA is a supplemental non-GAAP financial measure that is used by management and
external users of the Companys consolidated financial statements, such as industry analysts,
investors, lenders and rating agencies. The Company defines Adjusted EBITDA as earnings before
interest expense, income taxes, depreciation, depletion and amortization, property impairments,
exploration expenses, unrealized derivative gains and losses and non-cash stock-based compensation
expense. Adjusted EBITDA is not a measure of net income or cash flows as determined by United
States generally accepted accounting principles, or GAAP.
The following tables present a reconciliation of the non-GAAP financial measure of Adjusted EBITDA
to the GAAP financial measures of net loss and net cash provided by operating activities,
respectively.
Adjusted EBITDA Reconciliations
Three Months Ended March 31, | ||||||||
2011 | 2010 | |||||||
(In thousands) | ||||||||
Adjusted EBITDA reconciliation to Net Income /(Loss): |
||||||||
Net income (loss) |
$ | (6,847 | ) | $ | (3,231 | ) | ||
Change in unrealized loss (gain) on derivative instruments |
31,154 | 391 | ||||||
Interest expense |
5,198 | 338 | ||||||
Depreciation, depletion and amortization |
13,812 | 5,849 | ||||||
Impairment of oil and gas properties |
1,381 | 3,077 | ||||||
Exploration expenses |
32 | 18 | ||||||
Stock-based compensation expenses |
527 | 5,200 | ||||||
Income tax expense (benefit) |
(4,161 | ) | | |||||
Adjusted EBITDA |
$ | 41,096 | $ | 11,642 | ||||
Adjusted EBITDA reconciliation to Net Cash Provided by Operating Activities: |
||||||||
Net cash provided by operating activities |
$ | 22,845 | $ | 7,702 | ||||
Realized gain (loss) on derivative instruments |
(512 | ) | (26 | ) | ||||
Interest expense |
5,198 | 338 | ||||||
Exploration expenses |
32 | 18 | ||||||
Debt discount amortization and other |
(256 | ) | (185 | ) | ||||
Changes in working capital |
13,789 | 3,795 | ||||||
Adjusted EBITDA |
$ | 41,096 | $ | 11,642 | ||||
10