Exhibit 99.1
 | News Release | Energy Partners, Ltd. 201 St. Charles Avenue, Suite 3400 New Orleans, Louisiana 70170 | ||
(504) 569-1875
|
EPL Announces First Quarter Results for 2011
New Orleans, Louisiana, May 04, 2011…Energy Partners, Ltd. (EPL or the Company) (NYSE:EPL) today reported financial and operational results for the first quarter 2011.
Highlights
| • | First quarter 2011 revenue of $67.2 million, up 23% from the fourth quarter 2010, aided by a 23% increase in crude oil production and 19% increase in realized crude oil prices versus that same period |
| • | First quarter 2011 EBITDAX of $37.9 million and discretionary cash flow of $36.2 million (see reconciliation of EBITDAX and discretionary cash flow in the tables) |
| • | Increased expectations for 2011 projected EBITDAX, currently expected to range from $240 million to $270 million using the midpoint of guidance (see EBITDAX table in guidance section) |
| • | Cash on hand and liquidity continuing to build, with current estimated cash at $55 million and liquidity (cash on hand plus undrawn availability on the Company’s revolver) of $205 million |
| • | Net debt per Boe rapidly decreasing from already low levels, currently down to $4.37 based on the 2010 year end proved reserves pro forma for the recent acquisition |
| • | Recently closed acquisition of oily shallow GOM assets has been fully integrated and the EPL technical team has identified new sizable oily drilling potential |
Financial Results
Revenue for the first quarter of 2011 was $67.2 million, up 23% from the fourth quarter 2010, resulting from higher oil revenues from higher oil production and realized oil prices offset by lower natural gas revenues from the decline in gas production resulting from the Company’s focus on oil-weighted development projects.
For the first quarter of 2011, EPL reported a net loss to common stockholders of $14.5 million, or $0.36 per diluted share. The net loss for the first quarter of 2011 was attributable to $20.2 million of non-cash unrealized losses on derivative instruments and $10.8 million of non-cash costs attributable to property impairments. The majority of the property impairments occurred as a result of a mechanical issue with a gas well outside of the Company’s focus areas. Based on high oil prices and low gas prices, the Company elected not to make a high cost, high-risk casing repair and to instead deploy the additional capital into other oil-weighted projects. Excluding the impact of these non-cash items, EPL’s adjusted fourth quarter net income, a non-GAAP measure, would have been $4.8 million, or $0.12 per diluted share.
For the first quarter of 2011, EBITDAX was $37.9 million and discretionary cash flow was $36.2 million (see reconciliation of EBITDAX and discretionary cash flow in the tables). Cash flow from operating activities in the first quarter of 2011 was $14.8 million.
Gary C. Hanna, the Company’s CEO, stated, “We are raising our 2011 EBITDAX guidance to a range of approximately $240 to $270 million, up from our previous midpoint guidance of $225 million. This updated range uses the midpoint of our production guidance and average realized oil prices between $100 to $120 per barrel. To keep production rate versus revenue generation in perspective, with prevailing commodity prices slanted around 25 to 1 in favor of oil production, approximately 90% of our revenue generation is projected this year to come from our increased oil production. In the month of March alone, we realized upwards of $113 per barrel for our crude oil, which is all advantaged by receiving Heavy Louisiana Sweet and Light Louisiana Sweet crude oil basis differentials. As one of the oiliest of our GOM peer group, notably in the range of 70%, we are uniquely positioned in this oil price advantaged commodity market to provide substantial value to our shareholders.”
Production and Price Realizations
Oil production for the first quarter of 2011 averaged 6,567 Boe per day, comprised of 96% crude oil production and 4% natural gas liquids. Natural gas production averaged 23.0 million cubic feet (Mmcf) per day. First quarter 2011 crude oil production volumes were 23% higher than the previous quarter, primarily as a result of the recent acquisition of oil weighted properties which closed mid first quarter and continued focus on oil-weighted projects. Price realizations, all of which are stated before the impact of derivative instruments, averaged $101.34 per barrel for crude oil and $4.17 per thousand cubic feet (Mcf) of natural gas in the first quarter of 2011, compared to $85.39 per barrel of crude oil and $3.81 per Mcf of natural gas in the fourth quarter of 2010.
Operating Expenses
Lease operating expenses (LOE) for the first quarter of 2011 totaled $15.3 million, while general and administrative (G&A) expenses were $5.3 million. The period included $1.7 million for LOE related to its newly acquired properties. Reported G&A expenses include non-cash stock based compensation recorded in the first quarter of 2011 of $0.5 million, as well as $0.5 million of A&D-related expenses due to the recent acquisition. Excluding these items for comparative purposes in both periods, G&A would have been $4.3 million for first quarter 2011 versus an average of $4.2 million per quarter for full year 2010.
Liquidity and Capital Resources
As of March 31, 2011, the Company had unrestricted cash on hand of $44.4 million and $7.2 million of restricted cash. As announced in February of this year, EPL closed on its acquisition of producing Gulf of Mexico (GOM) shelf properties from Anglo-Suisse Offshore Partners, LLC for $200.7 million in cash, subject to customary adjustments to reflect the January 1, 2011 economic effective date (the Acquisition). In order to finance the Acquisition, the Company also closed its previously announced offering of $210 million aggregate principal amount of 8.25% Senior Notes due 2018.
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Concurrently, the Company entered into a new $250 million credit facility with $150 million of undrawn revolving capacity. Currently, EPL estimates its cash on hand at approximately $55 million for total estimated liquidity of $205 million and net debt of $4.37 per barrel of oil equivalent using 2010 year-end proved reserves pro forma for the Acquisition.
Gary Hanna commented, “Post transaction, our credit profile and liquidity remains very strong versus our peer group and we are steadily improving on a net debt basis due to our continued cash build. Our cost of capital is attractive and we have enhanced our growing liquidity through our expanded but unused new credit facility. We have the technical capability and financial flexibility to be acquisitive in this robust shallow GOM A&D market, with our eye squarely on aggregating additional oil-weighted shallow water GOM properties and maintaining a conservative balance sheet.”
Capital Expenditures and Operations Update
During first quarter 2011, capital expenditures, all of which were development related activities totaled approximately $7.1 million. In addition, the Company spent approximately $7.8 million in the first quarter on plugging and abandonment and other decommissioning activities.
The Company’s full year 2011 planned activities are set to ramp up in the second quarter after heavy weather related disruptions during the winter months. By the end of May, the Company expects to have up to five rigs working full time within its focus areas. EPL’s budget for 2011 includes $90 to $105 million of development activities, primarily in the East Bay, South Timbalier, West Delta, and Main Pass field areas, as well as an additional $20 million for exploration projects. The Company is continuing its proactive abandonment and decommissioning program, with an approved 2011 budget of approximately $17 million. The Company plans to plug up to 150 wells and remove over 50 platforms, and the program is already well underway with 81 wells completed. By the end of 2011, EPL expects to have plugged over 300 wells since the start of the program in late 2009, predominately within its East Bay field.
Gary Hanna continued, “We are excited about our acquisition that closed mid-way through the first quarter. Our timing was great in that we bought these properties in a rising commodity price environment, for approximately three times their twelve month trailing cash flow. Most importantly, we will see the full effects of the properties’ heavily oil-weighted production beginning in the second quarter. We have fully integrated these centrally located, shallow water fields into our company. While we are just getting started, our well reactivation program has increased our production estimates for the acquired assets by upwards of 15% and we have decreased estimated lease operating expenses approximately 13% in the West Delta area.
“Right off the bat, our technical team began working on refining our immediate development and longer term exploration plans for the acquired properties. We knew these properties contained high quality, low cost recompletion opportunities and anticipated that we would quickly define upside drilling potential in these prolific areas. As we speak, we have at least a dozen newly identified leads in the West Delta area, with unrisked resource potential of multiple times the acquired proved reserve base. While we are early in this process, it is exceeding our expectations in terms of the rapid identification of potential drilling targets, and confirms our belief in this acquired asset base holding significant upside potential that we hope to unlock in short order.”
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Second Quarter and Full Year 2011 Guidance
ESTIMATED EBITDAX RANGES
2011 EBITDAX Estimates Using the Production Guidance and Various Realized Prices(1)
| Full Year 2011 Production Rate | ||||||||||||
| 8000 Bopd/20 Mmcf/d | 8500 Bopd/24 Mmcf/d | 9000 Bopd/27 Mmcf/d | ||||||||||
Realized Prices ($/Bbl/$Mcf) | ||||||||||||
$100/$4.25 | $ | 220 | $ | 240 | $ | 260 | ||||||
$110/$4.25 | $ | 235 | $ | 255 | $ | 280 | ||||||
$120/$4.25 | $ | 250 | $ | 270 | $ | 300 | ||||||
| (1) | All EBITDAX figures are approximate using production and expense guidance and estimated realized hedging impacts |
ESTIMATED PRODUCTION & SWAP HEDGE VOLUMES
| Net Production (per day): | 2Q 2011 | Full Year 2011 | ||
Oil, including NGLs (Bbls) | 7,750 - 8,500 | 8,000 - 9,000 | ||
Natural gas (Mcf) | 18,000 - 22,000 | 20,000 - 27,000 | ||
% Oil, including NGLs (using midpoint of guidance) | 71% | 68% | ||
Swap Contracted Volume | ||||
Oil (barrels) | 5,891 | 3,561 | ||
% of Oil swap contracted | 76% - 69% | 45% - 40% | ||
% of Boe swap contracted | 55% - 48% | 31% - 26% | ||
Average Swap Price Level | $ 85.00 | $ 84.41 | ||
ESTIMATED EXPENSES (in Millions, unless otherwise noted)
Lease Operating (including energy insurance) | $ 17.8 - 18.8 | $ 62.0 -66.0 | ||
General & Administrative (cash and non-cash) | $ 4.8 - 5.3 | $ 19.0 - 21.0 | ||
Taxes, other than on earnings (% of revenue) | 3% - 5% | 3% - 5% | ||
Exploration Expense | $ 1.0 - 3.0 | $ 2.0 - 5.0 | ||
DD&A ($/Boe) | $ 21.00 - 25.00 | $ 21.00 - 25.00 | ||
Interest Expense (including amortization of discount and deferred financing costs) | $ 4.5 - 5.5 | $ 17.5 - 18.5 |
Gary Hanna concluded, “We are reaffirming our 2011 oil production guidance at 8,000 to 9,000 barrels of oil per day. We firmly believe that beginning in this current quarter we will deliver significant increases in our oil production. We exited the first quarter at over 8,000 barrels of oil per day, and we will have production from our acquired properties counted in full beginning in the second quarter as well as improved performance with deceased winter weather-related issues across all of our assets. Additionally, our capital program, which is focused on oil-weighted projects, will continue to ramp up significantly beginning this month, and we anticipate seeing the full effects of that production, mainly oil, in the third and fourth quarters. Therefore, we are keeping a watchful eye towards hopefully increasing our oil guidance as we ramp up our activities.
“As mentioned earlier, we are raising our EBITDAX guidance to a range of $240 to $270 million. This is in spite of the fact that we are lowering our full year gas production guidance to 20 Mmcf/d to 27 Mmcf/d. Since we are anticipating realizing between 25 to 30 times the revenue for every barrel of crude oil produced versus mcf of gas produced, this has not impacted our projected revenue or cash flow growth for the year. Recently we experienced operational issues on two high rate gas recompletion opportunities performed, one of which was too costly to attempt to repair. We are prudently putting that development capital to better use, back into higher return oil projects within our portfolio.”
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Conference Call Information
EPL has scheduled a conference call for today, May 4, 2011 at 9:00 A.M. Central Time/10:00 A.M. Eastern Time, to review results for the first quarter of 2011. To participate in the EPL conference call, callers in the United States and Canada can dial (866) 845-8624 and international callers can dial (706) 634-0487. The Conference I.D. for callers is 61839007.
The call will be available for replay beginning two hours after the call is completed through midnight of May 18, 2011. For callers in the United States and Canada, the toll-free number for the replay is (800) 642-1687. For international callers the number is (706) 645-9291. The Conference I.D. for all callers to access the replay is 61839007.
The conference call will be webcast live and for on-demand listening at the Company’s web site, www.eplweb.com. Listeners may access the call through the “Conference Calls” link in the Investor Relations section of the site. The call will also be available through the CCBN Investor Network.
Description of the Company
Founded in 1998, EPL is an independent oil and natural gas exploration and production company based in New Orleans, Louisiana, and Houston, Texas. The Company’s operations are concentrated in the U.S. Gulf of Mexico shelf, focusing on the state and federal waters offshore Louisiana. For more information, please visit www.eplweb.com.
Investors/Media
T.J. Thom, Chief Financial Officer
504-799-1902
tthom@eplweb.com
Forward-Looking Statements
This press release may contain forward-looking information and statements regarding EPL. Any statements included in this press release that address activities, events or developments that EPL “expects,” “believes,” “plans,” “projects,” “estimates” or “anticipates” will or may occur in the future are forward-looking statements. We believe these judgments are reasonable, but actual results may differ materially due to a variety of important factors. Among other items, such factors might include: changes in general economic conditions; uncertainties in reserve and production estimates; unanticipated recovery or production problems; hurricane and other weather-related interference with business operations; the effects of delays in completion of, or shut-ins of, gas gathering systems, pipelines and processing facilities; changes in legislative and regulatory requirements concerning safety and the environment as they relate to operations; oil and natural gas prices and competition; the impact of derivative positions; production expenses and expense estimates; cash flow and cash flow estimates; future financial performance; planned and unplanned capital expenditures; drilling and operating risks; our ability to replace oil and gas reserves; risks and liabilities associated with the properties acquired in the acquisition; volatility in the financial and credit markets or in oil and natural gas prices; and other matters that are discussed in EPL’s filings with the Securities and Exchange Commission. (http://www.sec.gov/).
| ### | 11-012 |
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ENERGY PARTNERS, LTD.
CONSOLIDATED STATEMENTS OF OPERATIONS
(In thousands)
(Unaudited)
| Three Months | Three Months | Three Months | ||||||||||
| Ended | Ended | Ended | ||||||||||
| March 31, | December 31, | March 31, | ||||||||||
| 2011 | 2010 | 2010 | ||||||||||
Revenue: | ||||||||||||
Oil and natural gas | $ | 67,215 | 54,687 | 70,683 | ||||||||
Other | 34 | 35 | 36 | |||||||||
| 67,249 | 54,722 | 70,719 | ||||||||||
Costs and expenses: | ||||||||||||
Lease operating | 15,331 | 11,391 | 14,442 | |||||||||
Transportation | 135 | 253 | 490 | |||||||||
Exploration expenditures and dry hole costs | 548 | 2,513 | 1,854 | |||||||||
Impairments | 10,788 | 2,122 | 769 | |||||||||
Depreciation, depletion and amortization | 21,063 | 23,277 | 29,855 | |||||||||
Accretion of liability for asset retirement obligations | 3,575 | 3,201 | 3,222 | |||||||||
General and administrative | 5,287 | 4,208 | 4,188 | |||||||||
Taxes, other than on earnings | 3,318 | 2,714 | 2,037 | |||||||||
Loss (gain) on abandonment activities | 172 | (943 | ) | (197 | ) | |||||||
Other | (42 | ) | 925 | (52 | ) | |||||||
Total costs and expenses | 60,175 | 49,661 | 56,608 | |||||||||
Income from operations | 7,074 | 5,061 | 14,111 | |||||||||
Other income (expense): | ||||||||||||
Interest income | 10 | 8 | 9 | |||||||||
Interest expense | (2,470 | ) | (934 | ) | (4,202 | ) | ||||||
Loss on derivative instruments | (25,525 | ) | (5,980 | ) | (1,924 | ) | ||||||
Loss on early extinguishment of debt | (2,377 | ) | — | — | ||||||||
| (30,362 | ) | (6,906 | ) | (6,117 | ) | |||||||
Income (loss) before income taxes | (23,288 | ) | (1,845 | ) | 7,994 | |||||||
Benefit from (provision for) income taxes | 8,779 | 717 | (2,878 | ) | ||||||||
Net income (loss) | $ | (14,509 | ) | (1,128 | ) | 5,116 | ||||||
Net income (loss), as reported | $ | (14,509 | ) | (1,128 | ) | 5,116 | ||||||
Add back: | ||||||||||||
Unrealized loss (gain) due to the change in fair market value of derivative contracts | 20,234 | 4,798 | (1,736 | ) | ||||||||
Impairments | 10,788 | 2,122 | 769 | |||||||||
Deduct: | ||||||||||||
Income tax adjustment for above items | (11,695 | ) | (2,692 | ) | 348 | |||||||
Adjusted Non-GAAP net income | $ | 4,818 | 3,100 | 4,497 | ||||||||
EBITDAX Reconciliation: | ||||||||||||
Net income (loss), as reported | $ | (14,509 | ) | (1,128 | ) | 5,116 | ||||||
Add back: | ||||||||||||
Income taxes | (8,779 | ) | (717 | ) | 2,878 | |||||||
Net interest expense | 2,460 | 926 | 4,193 | |||||||||
Depreciation, depletion, amortization and accretion | 24,638 | 26,478 | 33,077 | |||||||||
Impairments | 10,788 | 2,122 | 769 | |||||||||
Exploration expenditures and dry hole costs | 548 | 2,513 | 1,854 | |||||||||
Loss (gain) on abandonment activities | 172 | (943 | ) | (197 | ) | |||||||
Loss on early extinguishment of debt | 2,377 | — | — | |||||||||
Less impact of: | ||||||||||||
Unrealized loss (gain) due to the change in fair market value of derivative contracts | 20,234 | 4,798 | (1,736 | ) | ||||||||
EBITDAX | $ | 37,929 | 34,049 | 45,954 | ||||||||
EBITDAX is defined as net income (loss) before income taxes, net interest expense, depreciation, depletion, amortization and accretion, impairments, exploration expenditures and dry hole costs, loss (gain) on abandonment activities, loss on early extinguishment of debt and cumulative effect of change in accounting principle, and further deducts the unrealized gain or loss on our derivative contracts. We have reported EBITDAX because we believe EBITDAX is a measure commonly reported and widely used in our industry as an indicator of a company’s ability to internally fund exploration and development activities and incur and service debt. EBITDAX is not a calculation based on generally accepted accounting principles (GAAP) in the United States and should not be considered in isolation from or as a substitute for net income, as an indication of operating performance or cash flows from operating activities or as a measure of liquidity. Investors should carefully consider the specific items included in our computation of EBITDAX. Investors should be cautioned that EBITDAX as reported by us may not be comparable in all instances to EBITDAX as reported by other companies. In addition, EBITDAX does not represent funds available for discretionary use.
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ENERGY PARTNERS, LTD.
CONSOLIDATED STATEMENTS OF NET CASH PROVIDED BY
OPERATING ACTIVITIES
(In thousands)
(Unaudited)
| Three Months | Three Months | Three Months | ||||||||||
| Ended | Ended | Ended | ||||||||||
| March 31, | December 31, | March 31, | ||||||||||
| 2011 | 2010 | 2010 | ||||||||||
Cash flows from operating activities: | ||||||||||||
Net income (loss) | $ | (14,509 | ) | (1,128 | ) | 5,116 | ||||||
Adjustments to reconcile net income (loss) to net cash provided by operating activities: | ||||||||||||
Depreciation, depletion and amortization | 21,063 | 23,277 | 29,855 | |||||||||
Accretion of liability for asset retirement obligations | 3,575 | 3,201 | 3,222 | |||||||||
Loss on early extinguishment of debt | 2,377 | — | — | |||||||||
Unrealized loss (gain) on derivative contracts | 20,234 | 4,798 | (1,736 | ) | ||||||||
Non-cash compensation | 502 | 260 | 165 | |||||||||
In-kind interest on PIK Notes | — | — | 3,225 | |||||||||
Deferred income taxes | (8,797 | ) | (717 | ) | 2,878 | |||||||
Exploration expenditures | 115 | 2,290 | 1,756 | |||||||||
Impairments | 10,788 | 2,122 | 769 | |||||||||
Amortization of deferred financing costs and discount | 246 | 382 | 504 | |||||||||
Loss (gain) on abandonment activities | 172 | (943 | ) | (197 | ) | |||||||
Changes in operating assets and liabilities: | ||||||||||||
Trade accounts receivable | (12,407 | ) | 1,928 | (637 | ) | |||||||
Other receivables | 1,283 | — | 1,413 | |||||||||
Prepaid expenses | 898 | 1,170 | (1,872 | ) | ||||||||
Other assets | 79 | 276 | (461 | ) | ||||||||
Accounts payable and accrued expenses | (3,760 | ) | (1,300 | ) | (3,656 | ) | ||||||
Asset retirement obligations | (7,033 | ) | (5,228 | ) | (1,263 | ) | ||||||
Net cash provided by operating activities | $ | 14,826 | 30,388 | 39,081 | ||||||||
Reconciliation of discretionary cash flow: | ||||||||||||
Net cash provided by (used in) operating activities | 14,826 | 30,388 | 39,081 | |||||||||
Changes in working capital | 20,940 | 3,154 | 6,476 | |||||||||
Non-cash exploration expenditures and impairments | (10,903 | ) | (4,412 | ) | (2,525 | ) | ||||||
Total exploration expenditures, dry hole costs and impairments | 11,336 | 4,635 | 2,623 | |||||||||
Discretionary cash flow | $ | 36,199 | 33,765 | 45,655 | ||||||||
The table above reconciles discretionary cash flow to net cash provided by or used in operating activities. Discretionary cash flow is defined as cash flow from operations before changes in working capital and exploration expenditures. Discretionary cash flow is widely accepted as a financial indicator of an oil and natural gas company’s ability to generate cash which is used to internally fund exploration and development activities, pay dividends and service debt. Discretionary cash flow is presented based on management’s belief that this non-GAAP financial measure is useful information to investors because it is widely used by professional research analysts in the valuation, comparison, rating and investment recommendations of companies within the oil and natural gas exploration and production industry. Many investors use the published research of these analysts in making their investment decisions. Discretionary cash flow is not a measure of financial performance under GAAP and should not be considered as an alternative to cash flows from operating activities, as defined by GAAP, or as a measure of liquidity, or an alternative to net income. Investors should be cautioned that discretionary cash flow as reported by the Company may not be comparable in all instances to discretionary cash flow as reported by other companies.
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ENERGY PARTNERS, LTD.
SELECTED PRODUCTION, PRICING AND OPERATIONAL STATISTICS
(Unaudited)
| Three Months Ended March 31, | Three Months Ended December 31, | Three Months Ended March 31, | ||||||||||
| 2011 | 2010 | 2010 | ||||||||||
| PRODUCTION AND PRICING | ||||||||||||
Net Production (per day): | ||||||||||||
Crude Oil (Bbls) | 6,279 | 5,094 | 5,970 | |||||||||
Natural Gas Liquids (Bbls) | 288 | 670 | 1,257 | |||||||||
Oil (Bbls) | 6,567 | 5,764 | 7,227 | |||||||||
Natural gas (Mcf) | 22,995 | 34,564 | 50,932 | |||||||||
Total (Boe) | 10,400 | 11,524 | 15,716 | |||||||||
Average Sales Prices: | ||||||||||||
Crude Oil (Bbls) | $ | 101.34 | 85.39 | 77.17 | ||||||||
Natural Gas Liquids (Bbls) | 50.70 | 41.47 | 44.23 | |||||||||
Oil (per Bbl) | 99.12 | 80.28 | 71.44 | |||||||||
Natural gas (per Mcf) | 4.17 | 3.81 | 5.28 | |||||||||
Average (per Boe) | 71.81 | 51.58 | 49.97 | |||||||||
Oil and Natural Gas Revenues (in thousands): | ||||||||||||
Crude Oil | $ | 57,271 | 40,016 | 41,464 | ||||||||
Natural Gas Liquids | 1,314 | 2,555 | 5,003 | |||||||||
Oil | 58,585 | 42,571 | 46,467 | |||||||||
Natural gas | 8,630 | 12,116 | 24,216 | |||||||||
Total | 67,215 | 54,687 | 70,683 | |||||||||
Impact of oil derivatives settled during the period per Bbl (1): | $ | (8.95 | ) | (2.23 | ) | (5.63 | ) | |||||
| OPERATIONAL STATISTICS | ||||||||||||
Average Costs (per Boe): | ||||||||||||
Lease operating expense | $ | 16.38 | 10.74 | 10.21 | ||||||||
Depreciation, depletion and amortization | 22.50 | 21.95 | 21.11 | |||||||||
Accretion expense | 3.82 | 3.02 | 2.28 | |||||||||
Taxes, other than on earnings | 3.54 | 2.56 | 1.44 | |||||||||
General and administrative | 5.65 | 3.97 | 2.96 | |||||||||
| (1) | The derivative amounts represent the realized portion of gains or losses on derivative contracts settled during the period which are included in Other income (expense) in the consolidated statements of operations. |
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ENERGY PARTNERS, LTD.
CONSOLIDATED BALANCE SHEETS
(In thousands, except share data)
| March 31, 2011 | December 31, 2010 | |||||||
ASSETS | ||||||||
Current assets: | ||||||||
Cash and cash equivalents | $ | 44,422 | $ | 33,553 | ||||
Trade accounts receivable - net | 33,850 | 21,443 | ||||||
Receivables from insurance | 805 | 2,088 | ||||||
Fair value of commodity derivative instruments | 29 | 186 | ||||||
Deferred tax assets | 7,249 | 2,693 | ||||||
Prepaid expenses | 2,910 | 3,303 | ||||||
Total current assets | 89,265 | 63,266 | ||||||
Property and equipment | 945,795 | 719,147 | ||||||
Less accumulated depreciation, depletion and amortization | (199,906 | ) | (168,055 | ) | ||||
Net property and equipment | 745,889 | 551,092 | ||||||
Restricted cash | 7,216 | 8,489 | ||||||
Other assets | 1,735 | 1,814 | ||||||
Deferred financing costs — net of accumulated amortization | 5,870 | 2,245 | ||||||
| $ | 849,975 | $ | 626,906 | |||||
LIABILITIES AND STOCKHOLDERS’ EQUITY | ||||||||
Current liabilities: | ||||||||
Accounts payable | $ | 14,122 | $ | 18,358 | ||||
Accrued expenses | 29,471 | 28,394 | ||||||
Asset retirement obligations | 9,878 | 16,902 | ||||||
Fair value of commodity derivative instruments | 24,248 | 12,320 | ||||||
Total current liabilities | 77,719 | 75,974 | ||||||
Long-term debt | 203,878 | — | ||||||
Asset retirement obligations | 82,111 | 54,681 | ||||||
Deferred tax liabilities | 18,228 | 22,469 | ||||||
Fair value of commodity derivative instruments | 8,149 | — | ||||||
Other | 666 | 666 | ||||||
| 390,751 | 153,790 | |||||||
Commitments and contingencies | ||||||||
Stockholders’ equity: | ||||||||
Preferred stock, $0.001 par value per share. Authorized 1,000,000 shares; no shares issued and outstanding at March 31, 2011 and December 31, 2010. | — | — | ||||||
Common stock, $0.001 par value per share. Authorized 75,000,000 shares; shares issued and outstanding 40,192,255 and 40,091,664 at March 31, 2011 and December 31, 2010, respectively. | 40 | 40 | ||||||
Additional paid-in capital | 503,181 | 502,556 | ||||||
Accumulated deficit | (43,989 | ) | (29,480 | ) | ||||
Treasury stock, at cost, 511 shares at March 31, 2011 | (8 | ) | — | |||||
Total stockholders’ equity | 459,224 | 473,116 | ||||||
| $ | 849,975 | $ | 626,906 | |||||
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