Attached files
| file | filename |
|---|---|
| 8-K - FORM 8-K - Approach Resources Inc | d81990e8vk.htm |
| EX-99.2 - EX-99.2 - Approach Resources Inc | d81990exv99w2.htm |
Exhibit 99.1
Approach Resources Inc. Reports First Quarter 2011 Results
Total Production Up 42% to 469 MBoe Over First Quarter 2010
Oil & NGL Production Increases 108% to 193 MBbls
Horizontal Wolfcamp Pilot Program Update
Borrowing Base Increase to $200 Million
Oil & NGL Production Increases 108% to 193 MBbls
Horizontal Wolfcamp Pilot Program Update
Borrowing Base Increase to $200 Million
Fort Worth, Texas, May 4, 2011 — Approach Resources Inc. (NASDAQ: AREX) today reported
financial and operating results for the first quarter of 2011. Highlights for first quarter 2011,
compared to first quarter 2010, include:
| • | Total production increased 42% to 469 MBoe (5.2 MBoe/d) | ||
| • | Oil and NGL production increased 108% to 193 MBbls | ||
| • | Revenues increased 53% to $20.2 million | ||
| • | Net income totaled $1.5 million, or $0.05 per diluted share | ||
| • | Adjusted net income (non-GAAP) totaled $1.2 million, or $0.04 per diluted share | ||
| • | EBITDAX (non-GAAP) increased 55% to $14 million, or $0.49 per diluted share |
Production for first quarter 2011 totaled 469 MBoe (5.2 MBoe/d), compared to 330 MBoe (3.7
MBoe/d) in first quarter 2010, a 42% increase. Oil and NGL production for first quarter 2011
increased 108% to 193 MBbls, compared to 93 MBbls produced in first quarter 2010. Compared to
production for fourth quarter 2010, total production increased 8% and oil and NGL production
increased 20%. Production for first quarter 2011 was 59% natural gas and 41% oil and NGLs,
compared to 72% natural gas and 28% oil and NGLs in first quarter 2010. We expect oil and NGL
production to continue to increase to approximately 55% of total production during 2011 due to
continued development of the Wolffork oil shale resource play and processing gas in the southeast
portion of Project Pangea, which began on April 1, 2011.
First Quarter 2011 Financial Results
Net income for first quarter 2011 was $1.5 million, or $0.05 per diluted share, on revenues of
$20.2 million. This compares to net income for first quarter 2010 of $3.6 million, or $0.17 per
diluted share, on revenues of $13.2 million, which included a $5.1 million unrealized gain on
commodity derivatives. The $7 million increase in revenues in the first quarter of 2011 is
primarily attributable to an increase in oil and NGL production volumes ($7.6 million), partially
offset by a decrease in natural gas prices ($600,000).
First quarter 2011 net income included an unrealized loss on commodity derivatives of $149,000
and a gain on the sale of the Company’s assets in British Columbia of $488,000. Our carrying value
related to our assets in British Columbia previously was written off as an impairment of unproved
properties at year end 2009. Excluding these items and related income taxes, adjusted net income
(non-GAAP) for first quarter 2011 was $1.2 million, or $0.04 per diluted share, compared to
adjusted net income of $200,000, or $0.01 per diluted share, for first quarter 2010. See
“Supplemental Non-GAAP Financial and Other Measures” below for our reconciliation of adjusted net
income to net income.
Net income and adjusted net income were impacted by $4.6 million of exploration expense, of
which $3.2 million was related to lease extensions in our core operating area in the Permian Basin
that we elected to pay in the first quarter of 2011 ahead of the University of Texas Lease Sale in
March 2011. The after-tax impact of the $3.2 million in exploration expense for these lease
extensions was $2.1 million, or $0.07 per diluted share.
EBITDAX (non-GAAP) for first quarter 2011 was $14 million, or $0.49 per diluted share,
compared to $9 million, or $0.43 per diluted share, for first quarter 2010. See “Supplemental
Non-GAAP Financial and Other Measures” below for our reconciliation of EBITDAX to net income.
Average realized prices for first quarter 2011, before the effect of commodity derivatives,
were $4.30 per Mcf of natural gas, $90.67 per Bbl of oil and $48.04 per Bbl of NGLs, compared to
$5.39 per Mcf of natural gas, $75.42 per Bbl of oil and $43.33 per Bbl of NGLs, for first quarter
2010. Our average realized price, including the effect of commodity derivatives, was $43.03 per
Boe for first quarter 2011, compared to $40.02 per Boe for first quarter 2010.
Lease operating expense (“LOE”) for first quarter 2011 was $2.6 million, or $5.64 per Boe,
compared to $1.8 million, or $5.58 per Boe, in first quarter 2010. The increase in total LOE was
primarily attributable to an increase in working interest in our core operating area in the Permian
Basin, Project Pangea. During the first quarter of 2011, we acquired the remaining 38% working
interest in the northwest area of Project Pangea (the “Working Interest Acquisition”), which
increased our working interest to approximately 100%. We also experienced an increase in repair
and maintenance expenses partially due to inclement winter weather in southwest Texas. Higher
production volumes in first quarter 2011, however, resulted in consistent LOE per Boe, compared to
first quarter 2010, and a slight decrease in LOE per Boe compared to fourth quarter 2010.
Severance and production taxes for first quarter 2011 were $1.1 million, or $2.35 per Boe,
compared to $694,000, or $2.10 per Boe, in first quarter 2010. Severance and production taxes were
approximately 5.5% and 5.2% of oil, NGL and gas sales for first quarter 2011 and 2010,
respectively. The increase in severance and production taxes was primarily due to the increase in
oil, NGL and gas sales over first quarter 2010.
Exploration expense for first quarter 2011 was $4.6 million, or $9.87 per Boe, compared to
$1.5 million, or $4.52 per Boe, in first quarter 2010. Higher exploration expense for first
quarter 2011 was primarily the result of the timing of lease extensions and expirations in Project
Pangea. During first quarter 2011, we extended leases for an additional four years for
approximately 9,200 acres in the northwest area of Project Pangea for $3.2 million, or
approximately $350 per acre. As discussed above, we elected to pay the $3.2 million in first
quarter 2011, ahead of the University of Texas Lease Sale that took place on March 30, 2011. The
after-tax impact of the early lease extensions was $2.1 million, or $0.07 per diluted share. In
addition, approximately 5,000 acres in the southeast area of Project Pangea expired during the
first quarter of 2011, resulting in approximately $1.2 million of exploration expense. We expect
to renew this acreage during second quarter 2011.
General and administrative expense (“G&A”) for first quarter 2011 was $3.5 million, or $7.46
per Boe, compared to $2.5 million, or $7.60 per Boe, for first quarter 2010. The increase in G&A
was principally due to higher salaries and benefits, share-based compensation, professional fees
and data processing.
2
Depletion, depreciation and amortization expense (“DD&A”) for first quarter 2011 was $6.1
million, or $12.90 per Boe, compared to $5.8 million, or $17.68 per Boe, for first quarter 2010.
The decrease in DD&A per Boe was primarily attributable to an increase in estimated proved
developed reserves, partially offset by an increase in production and capitalized costs over first
quarter 2010.
Capital expenditures during first quarter 2011 totaled $113.6 million, which included $26.8
million for exploration and development drilling, $70.2 million for the Working Interest
Acquisition and $16.6 million for new acreage acquisitions. During first quarter 2011, we acquired
approximately 17,600 net acres in Crockett and Schleicher Counties, Texas. Average cost for our
total net acreage position in the Permian Basin is approximately $300 per acre, and we have a 100%
working interest in substantially all of our acreage with an average net revenue interest of 76%.
Operations Update
During the first quarter of 2011, we drilled a total of 17 gross (13.2 net) wells and
completed 16 gross (10.7 net) wells, including five gross (3.5 net) wells that were waiting on
completion at year end 2010. At March 31, 2011, six gross (six net) wells were waiting on
completion. We currently have three rigs running in the Permian Basin, including one horizontal
rig and two vertical rigs. During 2011, we plan to drill 11 horizontal wells targeting the
Wolfcamp Shale, 19 vertical wells targeting the Wolffork and Canyon Sands and 26 vertical wells
targeting the Canyon Sands, which we expect to complete in the Wolffork zones in 2012.
Horizontal Wolfcamp Pilot Program
We recently completed our first horizontal pilot well targeting the Wolfcamp Shale. The Cinco
Terry M 901H well flowed at a max rate of 171 Boe per day, consisting of 51 Bbls of oil, 61 Bbls of
NGLs and 355 Mcf of gas (after shrink for NGL processing), from a 5,377-foot lateral, completed
with a total of 15 stages. The well had a stabilized production rate of 166 Boe per day,
consisting of 52 Bbls of oil, 58 Bbls of NGLs and 337 Mcf of gas (after shrink for NGL processing).
The stabilized production rate represents the five-day average daily production after the well
recovered approximately 35% of fracture stimulation fluids.
We also recently completed the University 42 21 1H well with 21 stages. The University 42 21
1H, a 7,037-foot lateral, currently is flowing back fracture stimulation fluids. In addition, we
recently finished drilling the Cinco Terry G 701H well. The Cinco Terry G 701H was drilled to a
total lateral length of 7,609 feet. We expect to complete the well with approximately 24 stages
during the second quarter of 2011. We have begun drilling our fourth horizontal well, the
University 45 7 1H well. We expect to drill the well to a total lateral length of approximately
7,200 feet and complete the well with approximately 22 stages, also during the second quarter of
2011.
We are in the early stage of our pilot program testing the Wolfcamp Shale with horizontal
wells. We are encouraged by our initial results in the play, and we continue to increase our
acreage position in the Permian Basin, which now totals approximately 134,500 net acres. We also
continue to evaluate and refine our drilling and completion techniques, lateral length and
completion stages in an effort to improve costs, production and ultimate recovery rates.
3
Financial Update
Credit Agreement and Liquidity
At March 31, 2011, we had a $200 million revolving credit agreement with a $150 million
borrowing base and $76.7 million outstanding. Our liquidity at March 31, 2011, was $74.2 million.
On May 4, 2011, we entered into a tenth amendment to our credit agreement, which increases the
borrowing base by $50 million to $200 million, based on our year-end 2010 proved reserves. The
amendment to our credit agreement also raises the maximum total commitment to $300 million, lowers
the applicable interest rate by 0.50%, extends the maturity date by two years to July 2014, raises
the debt to EBITDAX ratio covenant to not more than 4 to 1, permits the issuance of up to $200
million in senior unsecured debt and adds a fifth bank, Royal Bank of Canada, to the lending group.
Under the amended credit agreement, the issuance of senior unsecured debt would cause a reduction
in borrowing base of 25% of the principal amount of such debt.
Including the borrowing base increase, our liquidity was $124.2 million at March 31, 2011.
See “Supplemental Non-GAAP Financial and Other Measures” below for our calculation of “liquidity.”
We believe we have adequate liquidity from cash generated from operations and unused borrowing
capacity under our revolving credit facility for current working capital needs and maintenance of
our current drilling program. However, we may determine to access the public or private equity or
debt markets for future development of reserves, acquisitions, expansion of our current drilling
program, additional working capital or other liquidity needs, if such financing is available on
acceptable terms. We cannot guarantee that financing will be available on acceptable terms or at
all.
Commodity Derivatives Positions
The following table summarizes our natural gas commodity derivative positions at March 31,
2011:
| Volume (MMBtu) | $/MMBtu | |||||||||||
| Period | Monthly | Total | Fixed | |||||||||
NYMEX — Henry Hub |
||||||||||||
Price swaps 2011 |
230,000 | 2,070,000 | $ | 4.86 | ||||||||
Price call 2012 |
230,000 | 2,760,000 | $ | 6.00 | ||||||||
WAHA basis differential |
||||||||||||
Basis swaps 2011 |
300,000 | 2,700,000 | $ | (0.53 | ) | |||||||
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The following tables summarize our crude oil commodity derivative position and an
additional natural gas commodity derivative position at April 30, 2011:
| Volume (Bbls) | $/Bbl | |||||||||||||||
| Period | Daily | Total | Floor | Ceiling | ||||||||||||
NYMEX — West Texas Intermediate |
||||||||||||||||
Collars May 2011 — December 2011 |
1,000 | 245,000 | $ | 100.00 | $ | 127.00 | ||||||||||
| Volume (MMBtu) | $/MMBtu | |||||||||||
| Period | Monthly | Total | Fixed | |||||||||
NYMEX — Henry Hub |
||||||||||||
Price swaps June 2011 — December 2011 |
200,000 | 1,400,000 | $ | 4.74 | ||||||||
Conference Call Information
The Company will host a conference call on Thursday, May 5, 2011, at 10:00 a.m. Central Time
(11:00 a.m. Eastern Time) to discuss first quarter 2011 financial and operating results. To
participate in the conference call, domestic participants should dial (866) 783-2144 and
international participants should dial (857) 350-1603 approximately 15 minutes before the scheduled
conference time. To access the simultaneous webcast of the conference call, please visit the
Calendar of Events page under the Investor Relations section of the Company’s website,
www.approachresources.com, 15 minutes before the scheduled conference time to register for the
webcast and install any necessary software. A replay of the webcast will be available for one year
on the Company’s website. An accompanying slide presentation also is available on the Company’s
website.
Approach Resources Inc. is an independent oil and gas company with core operations, production
and reserves located in the Permian Basin in West Texas. The Company targets multiple oil and
liquids-rich formations in the Permian Basin, where the Company operates approximately 134,500 net
acres. The Company’s estimated proved reserves total 59.7 million barrels of oil equivalent, 52%
oil and NGLs and 48% natural gas. For more information about the Company, please visit
www.approachresources.com. Please note that the Company routinely posts important information
about the Company under the Investor Relations section of its website.
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
management regarding the Company’s expected drilling program, capital expenditures and production
and operating costs and expenses guidance. These statements are based on certain assumptions made
by the Company based on management’s experience, perception of historical trends and technical
analyses, current conditions, anticipated future developments and other factors believed to be
appropriate and reasonable by management. When used in this press release, the words “will,”
“potential,” “believe,” “estimate,” “intend,” “expect,” “may,” “should,” “anticipate,” “could,”
“plan,” “predict,” “project,” “profile,” “model” or their negatives, other similar expressions or
the statements that include those words, are intended to identify forward-looking statements,
although not all forward-looking statements contain such identifying words. 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. Further information on such assumptions, risks
and
5
uncertainties is available in the Company’s Securities and Exchange Commission (“SEC”) filings.
The Company’s SEC filings are available on the Company’s website at www.approachresources.com. 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.
For a glossary of oil and gas terms and abbreviations used in this release, please see our
Annual Report on Form 10-K filed with the SEC on March 11, 2011.
6
UNAUDITED RESULTS OF OPERATIONS
| Three Months Ended | ||||||||
| March 31, | ||||||||
| 2011 | 2010 | |||||||
Revenues (in thousands) |
||||||||
Gas |
$ | 7,106 | $ | 7,682 | ||||
Oil |
8,024 | 3,555 | ||||||
NGLs |
5,053 | 1,983 | ||||||
Total oil, NGL and gas sales |
20,183 | 13,220 | ||||||
Realized gain on commodity derivatives |
197 | 230 | ||||||
Total oil, NGL and gas sales including
derivative impact |
$ | 20,380 | $ | 13,450 | ||||
Production |
||||||||
Gas (MMcf) |
1,652 | 1,424 | ||||||
Oil (MBbls) |
88 | 47 | ||||||
NGLs (MBbls) |
105 | 46 | ||||||
Total (MBoe) |
469 | 330 | ||||||
Total (MBoe/d) |
5.2 | 3.7 | ||||||
Average prices |
||||||||
Gas (per Mcf) |
$ | 4.30 | $ | 5.39 | ||||
Oil (per Bbl) |
90.67 | 75.42 | ||||||
NGLs (per Bbl) |
48.04 | 43.33 | ||||||
Total (per Boe) |
43.03 | 40.02 | ||||||
Realized gain on commodity derivatives (per Boe) |
0.42 | 0.70 | ||||||
Total including derivative impact (per Boe) |
$ | 43.45 | $ | 40.72 | ||||
Costs and expenses (per Boe) |
||||||||
Lease operating (1) |
$ | 5.64 | $ | 5.58 | ||||
Severance and production taxes |
2.35 | 2.10 | ||||||
Exploration |
9.87 | 4.52 | ||||||
General and administrative |
7.46 | 7.60 | ||||||
Depletion, depreciation and amortization |
12.90 | 17.68 | ||||||
| (1) | Lease operating expense per Boe includes ad valorem taxes. |
7
APPROACH RESOURCES INC. AND SUBSIDIARIES
UNAUDITED CONSOLIDATED STATEMENTS OF OPERATIONS
(In thousands, except shares and per-share amounts)
UNAUDITED CONSOLIDATED STATEMENTS OF OPERATIONS
(In thousands, except shares and per-share amounts)
| Three Months Ended | ||||||||
| March 31, | ||||||||
| 2011 | 2010 | |||||||
REVENUES: |
||||||||
Oil, NGL and gas sales |
$ | 20,183 | $ | 13,220 | ||||
EXPENSES: |
||||||||
Lease operating |
2,647 | 1,840 | ||||||
Severance and production taxes |
1,103 | 694 | ||||||
Exploration |
4,628 | 1,490 | ||||||
General and administrative |
3,500 | 2,509 | ||||||
Depletion, depreciation and amortization |
6,052 | 5,835 | ||||||
Total expenses |
17,930 | 12,368 | ||||||
OPERATING INCOME |
2,253 | 852 | ||||||
OTHER: |
||||||||
Interest expense, net |
(513 | ) | (466 | ) | ||||
Realized gain on commodity derivatives |
197 | 230 | ||||||
Unrealized (loss) gain on commodity derivatives |
(149 | ) | 5,095 | |||||
Gain on sale of oil and gas properties |
488 | — | ||||||
INCOME BEFORE INCOME TAX PROVISION |
2,276 | 5,711 | ||||||
INCOME TAX PROVISION |
812 | 2,148 | ||||||
NET INCOME |
$ | 1,464 | $ | 3,563 | ||||
EARNINGS PER SHARE: |
||||||||
Basic |
$ | 0.05 | $ | 0.17 | ||||
Diluted |
$ | 0.05 | $ | 0.17 | ||||
WEIGHTED AVERAGE SHARES OUTSTANDING: |
||||||||
Basic |
28,293,654 | 20,996,202 | ||||||
Diluted |
28,542,932 | 21,124,615 | ||||||
8
UNAUDITED SELECTED FINANCIAL DATA
| Unaudited Consolidated Balance Sheet Data | March 31, | December 31, | ||||||
| (in thousands) | 2011 | 2010 | ||||||
Cash and cash equivalents |
$ | 1,255 | $ | 23,465 | ||||
Other current assets |
12,890 | 17,865 | ||||||
Property and equipment, net, successful efforts method |
473,263 | 369,210 | ||||||
Other assets |
2,491 | 2,549 | ||||||
Total assets |
$ | 489,899 | $ | 413,089 | ||||
Current liabilities |
$ | 25,342 | $ | 29,240 | ||||
Long-term debt |
76,700 | — | ||||||
Other long-term liabilities |
52,402 | 50,903 | ||||||
Stockholders’ equity |
335,455 | 332,946 | ||||||
Total liabilities and stockholders’ equity |
$ | 489,899 | $ | 413,089 | ||||
| Three Months Ended | ||||||||
| Unaudited Consolidated Cash Flow Data | March 31, | |||||||
| (in thousands) | 2011 | 2010 | ||||||
Net cash provided (used) by: |
||||||||
Operating activities |
$ | 14,394 | $ | 7,152 | ||||
Investing activities |
$ | (113,577 | ) | $ | (14,041 | ) | ||
Financing activities |
$ | 76,968 | $ | 4,800 | ||||
Effect of foreign currency translation |
$ | 5 | $ | (1 | ) | |||
Supplemental Non-GAAP Financial and Other Measures
This release contains certain financial measures that are non-GAAP measures. We have provided
reconciliations below of the non-GAAP financial measures to the most directly comparable GAAP
financial measures and on the Non-GAAP Financial Information page in the Investor Relations section
of our website at www.approachresources.com.
Adjusted Net Income
This release contains the non-GAAP financial measures adjusted net income and adjusted net
income per diluted share, which exclude the following items:
| (i) | Unrealized loss (gain) on commodity derivatives, | ||
| (ii) | Gain on sale of oil and gas properties, and | ||
| (iii) | Related income taxes. |
The amounts included in the calculation of adjusted net income and adjusted net income per
diluted share below were computed in accordance with GAAP. We believe adjusted net income and
adjusted net income per diluted share are useful to investors because they provide readers with a
more meaningful measure of our profitability before recording certain items whose timing or amount
cannot be reasonably determined. However, these measures are provided in addition to, and not as
an alternative for, and should be read in conjunction with, the information contained in our
financial statements prepared in accordance with GAAP (including the notes), included in our SEC
filings and posted on our website.
9
The following table provides a reconciliation of adjusted net income to net income for the
three months ended March 31, 2011 and 2010, respectively (in thousands, except per-share amounts):
| Three Months Ended | ||||||||
| March 31, | ||||||||
| 2011 | 2010 | |||||||
Net income |
$ | 1,464 | $ | 3,563 | ||||
Adjustments for certain non-cash items: |
||||||||
Unrealized loss (gain) on commodity derivatives |
149 | (5,095 | ) | |||||
Gain on sale of oil and gas properties |
(488 | ) | — | |||||
Related income tax effect |
119 | 1,732 | ||||||
Adjusted net income |
$ | 1,244 | $ | 200 | ||||
Adjusted net income per diluted share |
$ | 0.04 | $ | 0.01 | ||||
EBITDAX
We define EBITDAX as net income, plus (1) exploration expense, (2) depletion, depreciation and
amortization expense, (3) share-based compensation expense, (4) unrealized loss (gain) on commodity
derivatives, (5) gain on sale of oil and gas properties, (6) interest expense and (7) income taxes.
EBITDAX is not a measure of net income or cash flow as determined by GAAP. The amounts included in
the calculation of EBITDAX were computed in accordance with GAAP. EBITDAX is presented herein and
reconciled to the GAAP measure of net income because of its wide acceptance by the investment
community as a financial indicator of a company’s ability to internally fund development and
exploration activities. This measure is provided in addition to, and not as an alternative for,
and should be read in conjunction with, the information contained in our financial statements
prepared in accordance with GAAP (including the notes), included in our SEC filings and posted on
our website.
The following table provides a reconciliation of EBITDAX to net income for the three months
ended March 31, 2011 and 2010, respectively (in thousands, except per-share amounts):
| Three Months Ended | ||||||||
| March 31, | ||||||||
| 2011 | 2010 | |||||||
Net income |
$ | 1,464 | $ | 3,563 | ||||
Exploration |
4,628 | 1,490 | ||||||
Depletion, depreciation and amortization |
6,052 | 5,835 | ||||||
Share-based compensation |
835 | 580 | ||||||
Unrealized loss (gain) on commodity derivatives |
149 | (5,095 | ) | |||||
Gain on sale of oil and gas properties |
(488 | ) | — | |||||
Interest expense, net |
513 | 466 | ||||||
Income tax provision |
812 | 2,148 | ||||||
EBITDAX |
$ | 13,965 | $ | 8,987 | ||||
EBITDAX per diluted share |
$ | 0.49 | $ | 0.43 | ||||
10
Liquidity
Liquidity is calculated by adding the net funds available under our revolving credit facility
and cash and cash equivalents. We use liquidity as an indicator of the Company’s ability to fund
development and exploration activities. However, this measurement has limitations. This
measurement can vary from year to year for the Company and can vary among companies based on what
is or is not included in the measurement on a company’s financial statements. This measurement is
provided in addition to, and not as an alternative for, and should be read in conjunction with, the
information contained in our financial statements prepared in accordance with GAAP (including the
notes), included in our SEC filings and posted on our website.
The table below summarizes our liquidity position at March 31, 2011, and our liquidity
position at March 31, 2011, reflecting the May 2011 borrowing base increase to $200 million from
$150 million (dollars in thousands).
| Liquidity with | ||||||||
| Borrowing Base | ||||||||
| Liquidity at | Increase at | |||||||
| March 31, 2011 | March 31, 2011 | |||||||
Borrowing base |
$ | 150,000 | $ | 200,000 | ||||
Cash and cash equivalents |
1,255 | 1,255 | ||||||
Outstanding letters of credit |
(350 | ) | (350 | ) | ||||
Long-term debt |
(76,700 | ) | (76,700 | ) | ||||
Liquidity |
$ | 74,205 | $ | 124,205 | ||||
11