Exhibit 99.1
Gulfport Energy Reports Fourth Quarter and Full-Year 2006 Results
OKLAHOMA CITY (March 28, 2007) Gulfport Energy Corporation (NASDAQ: GPOR) today reported financial and operating results for the fourth quarter and full-year 2006.
For the year, Gulfport reported net income of $27.8 million, a 155% increase compared to 2005. Earnings per diluted share for the year was $0.82 on revenues of $60.4 million. EBITDA (as defined below) for 2006 was $43 million, a 157% improvement compared to 2005. Cash flow from operating activities before changes in working capital for 2006 totaled $41.9 million, a 154% increase from 2005.
For the fourth quarter, Gulfport reported net income of $5.4 million, compared to a $90,000 loss for the same prior-year period. Earnings per diluted share for the fourth quarter was $0.16 on revenues of $17.6 million. EBITDA (as defined below) for the quarter was $10.6 million, compared to approximately $0.5 million in the fourth quarter 2005. Cash flow from operating activities before changes in working capital for fourth quarter 2006 totaled $10.1 million, compared to approximately $0.4 million in fourth quarter 2005.
Production and Operational Highlights for 2006
Net production was 270,322 barrels of oil and 124,373 million cubic feet (“Mcf”) of natural gas, or 291,051 barrels of oil equivalent (“BOE”), for the fourth quarter 2006. For the year, Gulfport reported record annual net production of 869,728 barrels of oil and 676,817 Mcf of natural gas, or 982,531 BOE. Production increased in 2006 by 60% compared to 2005 annual net production of 612,840 BOE.
During 2006, Gulfport drilled 25 productive wells out of 28 wells drilled, an 89% success rate. The company also performed 19 recompletions, all at the West Cote Blanche Bay (“WCBB”) field. In Thailand, Gulfport owns a 0.7% interest in the Phu Horm field which commenced selling gas in the fourth quarter and is currently producing approximately 100 MMcf per day. Gulfport also entered into the Canadian oil sands in 2006 by taking a 25% interest in Grizzly Oil Sands for which it is the operator. During the year, Grizzly acquired 315,000 acres in the Athabasca Oil Sands and commenced evaluation of the acreage with an initial 62 well core hole drilling program.
Reserves
Total proved reserves, P1 reserves, which consists of Proved Developed Producing (PDP), Proved Developed Non-Producing (PDNP) and Proved Undeveloped (PUD) were 23.2 million BOE at December 31, 2006. The PDP reserves were 1.6 million BOE, PDNP reserves were 4.0 million BOE and PUD reserves were 17.6 million BOE. In addition to the company’s proved reserves, independent engineers have assigned probable reserves, P2 reserves, of 3.8 million BOE to the company’s WCBB field and 1.7 million BOE to its interest in the Phu Horm field in Thailand and possible reserves, P3 reserves of 8.9 million BOE net to Gulfport’s interest in the Phu Horm field.
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In 2006, Gulfport’s capital expenditures associated with the exploration and development of its oil and gas properties were approximately $55 million. This amount includes $50.4 million associated with exploratory and development drilling and $4.2 million for recompletions.
2007 Operation Update
Drilling
The company has drilled 6 wells year-to-date 2007 in southern Louisiana; four development wells at the WCBB field and two exploratory wells at East Hackberry. The company has also drilled and logged 62 wells in Alberta on its Canadian oil sand acreage.
Facilities
The production facility barge for the East Hackberry field is on location and secured to its pad. Initial tie-in and start-up activities are under way and the connection of flow lines from the initial East Hackberry wells (2006 No. 1, 2007 No. 1 & No. 2) is in progress.
2007 Guidance
Gulfport’s 2007 guidance remains as previously stated on November 9, 2006 with total net production to be in the range of 1.7 million to 1.9 million barrels of oil equivalent. Capital expenditures are estimated in the range of $60 million to $65 million. Operationally, Gulfport plans to drill between 26 to 28 new wells and perform 18 recompletions, similar to its 2006 activity level. The production and capital targets for 2007 exclude our exploratory efforts at Hackberry.
Lease operating expense is projected to be in the range of $7.00 to $8.00 per barrel of oil equivalent for 2007. Selling, general and administrative expenses are estimated to be between $2.00 to $2.50 per barrel of oil equivalent for 2007.
Conference Call
Gulfport Energy will host a conference call today at 11:00 a.m. Eastern time to discuss its fourth quarter and full year 2006 financial and operational results. Interested parties may listen to the call via Gulfport’s website at www.gulfportenergy.com or by calling 1-866-356-3093. The passcode for the call is 70202201. A replay of the call will be available for two weeks at 1-888-286-8010. The replay passcode is 40502287. The webcast will be archived for 30 days on the company’s website.
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About Gulfport
Gulfport Energy Corporation is an Oklahoma City based independent oil and natural gas exploration and production company with its principal producing properties located along the Louisiana Gulf Coast. Gulfport recently acquired an acreage position in the Alberta oil sands in Canada and drilled core samples this winter. In addition, Gulfport also has an interest in the producing Phu Horm gas field in Thailand.
Forward Looking Statements
This news release includes “forward-looking statements” within the meaning of Section 27A of the Securities Act of 1933, as amended (the “Securities Act”), and Section 21E of the Securities Exchange Act of 1934, as amended (the “Exchange Act”). All statements, other than statements of historical facts, included in this news release that address activities, events or developments that Gulfport expects or anticipates will or may occur in the future, including such things as future capital expenditures (including the amount and nature thereof), business strategy and measures to implement strategy, competitive strength, goals, expansion and growth of Gulfport’s business and operations, plans, references to future success, reference to intentions as to future matters and other such matters are forward-looking statements. These statements are based on certain assumptions and analyses made by Gulfport in light of its experience and its perception of historical trends, current conditions and expected future developments as well as other factors it believes are appropriate in the circumstances. However, whether actual results and developments will conform with Gulfport’s expectations and predictions is subject to a number of risks and uncertainties, general economic, market or business conditions; the opportunities (or lack thereof) that may be presented to and pursued by Gulfport; competitive actions by other oil and gas companies; changes in laws or regulations; and other factors, many of which are beyond the control of Gulfport. Information concerning these and other factors can be found in the company’s filings with the Securities and Exchange Commission, including its Forms 10-KSB, 10-QSB and 8-K. Consequently, all of the forward-looking statements made in this news release are qualified by these cautionary statements and there can be no assurances that the actual results or developments anticipated by Gulfport will be realized, or even if realized, that they will have the expected consequences to or effects on Gulfport, its business or operations. We have no intention, and disclaim any obligation, to update or revise any forward-looking statements, whether as a result of new information, future results or otherwise.
Non-GAAP Financial Measures
EBITDA is a non-GAAP financial measure equal to net income, the most directly comparable GAAP financial measure, plus interest expense, accretion expense and depreciation, depletion and amortization. Operating cash flow is a non-GAAP financial measure equal to cash flows from operating activities before changes in assets and liabilities. The Company has presented EBITDA because it uses EBITDA as an integral part of its internal reporting to measure its performance and to evaluate the performance of its senior management. EBITDA is considered an important indicator of the operational strength of the Company’s business. EBITDA eliminates the uneven effect of considerable amounts of non-cash depletion, depreciation of tangible assets and amortization of certain intangible assets. A limitation of this measure, however, is that it does not reflect the periodic costs of certain capitalized tangible and intangible assets used in generating revenues in the Company’s businesses. Management evaluates the costs of such tangible and intangible assets and the impact of related impairments through other financial measures, such as capital expenditures, investment spending and return on capital. Therefore, the Company believes that EBITDA provides useful information to its investors regarding its performance and overall results of operations. EBITDA and operating cash flow are not intended to be performance measures that should be regarded as an alternative to, or more meaningful than, either net income as an indicator of operating performance or to cash flows from operating activities as a measure of liquidity. In addition, EBITDA and operating cash flow are not intended to represent funds available for dividends, reinvestment or other discretionary uses, and should not be considered in isolation or as a substitute for measures of performance prepared in accordance with GAAP. The EBITDA and operating EBITDA measures presented in this press release may not be comparable to similarly titled measures presented by other companies, and may not be identical to corresponding measures used in the Company’s various agreements.
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Investor & Media Contact:
John Kilgallon
Director, Investor Relations
jkilgallon@gulfportenergy.com
405-242-4474
Gulfport Energy Corporation
Supplementary Statement of Income
(unaudited)
| Year Ended December 31, | Three Months Ended December 31, | |||||||||||||||
| 2006 | 2005 | 2006 | 2005 | |||||||||||||
| Revenues: |
||||||||||||||||
| Gas sales |
$ | 4,194,000 | $ | 3,437,000 | $ | 776,000 | $ | 618,000 | ||||||||
| Oil and condensate sales |
56,038,000 | 23,986,000 | 16,634,000 | 692,000 | ||||||||||||
| Other income |
158,000 | 136,000 | 177,000 | 10,000 | ||||||||||||
| 60,390,000 | 27,559,000 | 17,587,000 | 1,320,000 | |||||||||||||
| Costs and expenses: |
||||||||||||||||
| Lease operating expenses |
10,670,000 | 7,654,000 | 4,111,000 | 1,420,000 | ||||||||||||
| Production taxes |
7,366,000 | 3,622,000 | 1,944,000 | 488,000 | ||||||||||||
| Depreciation, depletion, and amortization |
12,652,000 | 4,789,000 | 4,428,000 | 341,000 | ||||||||||||
| General and administrative |
3,251,000 | 1,561,000 | 1,019,000 | 687,000 | ||||||||||||
| Accretion expense |
596,000 | 516,000 | 149,000 | 167,000 | ||||||||||||
| 34,535,000 | 18,142,000 | 11,651,000 | 3,103,000 | |||||||||||||
| INCOME FROM OPERATIONS |
25,855,000 | 9,417,000 | 5,936,000 | (1,783,000 | ) | |||||||||||
| OTHER (INCOME) EXPENSE: |
||||||||||||||||
| Interest expense |
1,956,000 | 250,000 | 644,000 | 75,000 | ||||||||||||
| Interest expense - preferred stock |
— | 272,000 | — | — | ||||||||||||
| Business interruption insurance recoveries |
(3,601,000 | ) | (1,710,000 | ) | — | (1,710,000 | ) | |||||||||
| Interest income |
(308,000 | ) | (290,000 | ) | (112,000 | ) | (58,000 | ) | ||||||||
| (1,953,000 | ) | (1,478,000 | ) | 532,000 | (1,693,000 | ) | ||||||||||
| INCOME BEFORE INCOME TAXES |
27,808,000 | 10,895,000 | 5,404,000 | (90,000 | ) | |||||||||||
| INCOME TAX EXPENSE |
— | — | — | — | ||||||||||||
| NET INCOME |
$ | 27,808,000 | $ | 10,895,000 | $ | 5,404,000 | ($ | 90,000 | ) | |||||||
| NET INCOME PER COMMON SHARE: |
||||||||||||||||
| Basic |
$ | 0.85 | $ | 0.36 | $ | 0.16 | $ | 0.00 | ||||||||
| Diluted |
$ | 0.82 | $ | 0.34 | $ | 0.16 | $ | 0.00 | ||||||||
| Weighted Average Shares (Diluted) |
33,936,074 | 32,501,464 | 34,268,329 | 33,430,707 | ||||||||||||
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Gulfport Energy Corporation
Reconcilation of EBITDA and Cash Flow
(unaudited)
| Twelve Months Ended | Three Months Ended | |||||||||||||
| December 31, 2006 | December 31, 2005 | December 31, 2006 | December 31, 2005 | |||||||||||
| Net Income |
$ | 27,808,000 | $ | 10,895,000 | $ | 5,404,000 | ($ | 90,000 | ) | |||||
| Interest expense |
1,956,000 | 522,000 | 644,000 | 75,000 | ||||||||||
| Accretion expense |
596,000 | 516,000 | 149,000 | 167,000 | ||||||||||
| Depreciation, depletion, and amortization |
12,652,000 | 4,789,000 | 4,428,000 | 341,000 | ||||||||||
| EBITDA |
$ | 43,012,000 | $ | 16,722,000 | $ | 10,625,000 | $ | 493,000 | ||||||
| Twelve Months Ended | Three Months Ended | |||||||||||||
| December 31, 2006 | December 31, 2005 | December 31, 2006 | December 31, 2005 | |||||||||||
| Cash provided by operating activity |
$ | 39,523,000 | $ | 15,200,000 | $ | 11,587,000 | $ | 151,000 | ||||||
| Adjustments: |
||||||||||||||
| Changes in assets and liabilities |
2,372,000 | 1,296,000 | (1,533,000 | ) | 252,000 | |||||||||
| Operating Cash Flow |
$ | 41,895,000 | $ | 16,496,000 | $ | 10,054,000 | $ | 403,000 | ||||||
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Gulfport Energy Corporation
Supplemental Information on Oil and Gas Exploration and Production Activities
March 28, 2007
Unaudited
| Total Oil and Natural Gas Proved Reserves |
(M BOE) | ||
| Proved Reserves |
|||
| December 31, 2005 |
23,172 | ||
| Purchases in place |
— | ||
| Revisions |
|||
| Performance |
(542 | ) | |
| Price |
(32 | ) | |
| Extensions, discoveries and other additions |
1,544 | ||
| Sales in place |
— | ||
| Production |
(983 | ) | |
| December 31, 2006 |
23,159 | * | |
| * | Reserves numbers above do not include proved reserves of 3.5 Bcf attributed to Gulfport’s interest in the Phu Horm field in Thailand, per the Gaffney Cline & Associates reserve report dated April 2006. |
| Reserve Category Breakout |
(M BOE) | |||||||
| 2005 | 2006 | Change | ||||||
| Total Proved Reserves |
||||||||
| West Cote Blanche Bay and East Hackberry |
||||||||
| Proved Developed Producing (PDP) |
1,655 | 1,587 | -4.1 | % | ||||
| Proved Developed Non Producing (PDNP) |
3,279 | 3,968 | 21.0 | % | ||||
| Proved Undeveloped (PUD) |
18,238 | 17,604 | -3.5 | % | ||||
| Total Proved Reserves (1P) |
23,172 | 23,159 | * | -0.1 | % | |||
| Probable Resources |
||||||||
| West Cote Blanche Bay |
3,800 | |||||||
| Thailand |
1,700 | |||||||
| Total Probable Resource |
5,500 | |||||||
| Total Proved + Probable Resources (2P) |
28,659 | |||||||
| Possible Resources |
||||||||
| Thailand |
8,900 | |||||||
| Total Possible Resources |
8,900 | |||||||
| Total Proved + Probable + Possible Resources (3P) |
37,559 | |||||||
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| Costs Incurred in Oil and Gas Property Acquisition and Development Activities |
($) | ||
| 2006 | |||
| Acquisition |
— | ||
| Development of Proved Undeveloped Properties |
$ | 41,770,000 | |
| Exploratory |
8,607,000 | ||
| Recompletions |
4,235,000 | ||
| Capitalized Asset Retirement Obligation |
405,000 | ||
| Total |
$ | 55,017,000 | |
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