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Supplemental Information On Oil And Gas Exploration And Production Activities | 12 Months Ended
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Dec. 31, 2012
Oil and Gas Exploration and Production Industries Disclosures [Abstract] |
Supplemental Information On Oil And Gas Exploration And Production Activities | SUPPLEMENTAL INFORMATION ON OIL AND GAS EXPLORATION AND PRODUCTION ACTIVITIES The following is historical revenue and cost information relating to the Company’s oil and gas operations located entirely in the United States: Capitalized Costs Related to Oil and Gas Producing Activities
| 2012 |  | 2011
Proven properties | $ | 984,795,000 |  |  | $ | 897,130,000 |
Unproven properties | 626,295,000 |  |  | 132,912,000 |
| 1,611,090,000 |  |  | 1,030,042,000 |
Accumulated depreciation, depletion, amortization and impairment reserve | (661,442,000 | ) |  | (571,213,000 | )
Net capitalized costs | $ | 949,648,000 |  |  | $ | 458,829,000 |
Costs Incurred in Oil and Gas Property Acquisition and Development Activities
| 2012 |  | 2011 |  | 2010
Acquisition | $ | 513,904,000 |  |  | $ | 119,522,000 |  |  | $ | 17,627,000 |
Development of proved undeveloped properties | 121,787,000 |  |  | 123,489,000 |  |  | 64,652,000 |
Exploratory | 93,397,000 |  |  | 3,994,000 |  |  | — |
Recompletions | 24,643,000 |  |  | 17,259,000 |  |  | 16,917,000 |
Capitalized asset retirement obligation | 2,195,000 |  |  | 1,390,000 |  |  | 1,328,000 |
Total | $ | 755,926,000 |  |  | $ | 265,654,000 |  |  | $ | 100,524,000 |
Results of Operations for Producing Activities The following schedule sets forth the revenues and expenses related to the production and sale of oil and gas. The income tax expense is calculated by applying the current statutory tax rates to the revenues after deducting costs, which include depreciation, depletion and amortization allowances, after giving effect to the permanent differences. The results of operations exclude general office overhead and interest expense attributable to oil and gas production.
| 2012 |  | 2011 |  | 2010
Revenues | $ | 248,601,000 |  |  | $ | 228,953,000 |  |  | $ | 127,636,000 |
Production costs | (53,708,000 | ) |  | (47,230,000 | ) |  | (31,580,000 | )
Depletion | (90,230,000 | ) |  | (61,965,000 | ) |  | (38,600,000 | )
| 104,663,000 |  |  | 119,758,000 |  |  | 57,456,000 |
Income tax expense (benefit) |  |  |  |  |
Current | 730,000 |  |  | 282,000 |  |  | 40,000 |
Deferred | 25,633,000 |  |  | (372,000 | ) |  | — |
| 26,363,000 |  |  | (90,000 | ) |  | 40,000 |
Results of operations from producing activities | $ | 78,300,000 |  |  | $ | 119,848,000 |  |  | $ | 57,416,000 |
Depletion per barrel of oil equivalent (BOE) | $ | 35.07 |  |  | $ | 26.56 |  |  | $ | 19.54 |
Oil and Gas Reserves (Unaudited) The following table presents estimated volumes of proved developed and undeveloped oil and gas reserves as of December 31, 2012, 2011 and 2010 and changes in proved reserves during the last three years. The reserve reports use an average price equal to the unweighted arithmetic average of hydrocarbon prices received on a field-by-field basis on the first day of each month within the 12-month period ended December 31, 2012, 2011 and 2010, in accordance with guidelines of the SEC applicable to reserves estimates. Volumes for oil are stated in thousands of barrels (MBbls) and volumes for gas are stated in millions of cubic feet (MMcf). The prices used for the 2012 reserve report are $91.32 per barrel and $2.76 per MMbtu, adjusted by lease for transportation fees and regional price differentials, and for oil and gas reserves, respectively. The prices used at December 31, 2011 and 2010 for reserve report purposes are $96.19 per barrel and $4.12 per MMbtu and $76.16 per barrel and $4.38 per MMbtu, respectively. Gulfport emphasizes that the volumes of reserves shown below are estimates which, by their nature, are subject to revision. The estimates are made using all available geological and reservoir data, as well as production performance data. These estimates are reviewed annually and revised, either upward or downward, as warranted by additional performance data.
| 2012 |  | 2011 |  | 2010
| Oil |  | Gas |  | Oil |  | Gas |  | Oil |  | Gas
| (MBbls) |  | (MMcf) |  | (MBbls) |  | (MMcf) |  | (MBbls) |  | (MMcf)
Proved Reserves |  |  |  |  |  |  |  |  |  |  |
Beginning of the period | 16,745 |  |  | 15,728 |  |  | 19,704 |  |  | 16,158 |  |  | 17,488 |  |  | 14,332 |
Purchases in oil and gas reserves in place | — |  |  | — |  |  | 2 |  |  | 19 |  |  | 3,913 |  |  | 3,482 |
Extensions and discoveries | 4,880 |  |  | 31,265 |  |  | 3,940 |  |  | 2,091 |  |  | 5,574 |  |  | 5,303 |
Sales of oil and gas reserves in place | (10,604 | ) |  | (11,757 | ) |  | — |  |  | — |  |  | — |  |  | — |
Revisions of prior reserve estimates | (382 | ) |  | (357 | ) |  | (4,714 | ) |  | (1,662 | ) |  | (5,426 | ) |  | (6,171 | )
Current production | (2,388 | ) |  | (1,108 | ) |  | (2,187 | ) |  | (878 | ) |  | (1,845 | ) |  | (788 | )
End of period | 8,251 |  |  | 33,771 |  |  | 16,745 |  |  | 15,728 |  |  | 19,704 |  |  | 16,158 |
Proved developed reserves | 5,219 |  |  | 18,482 |  |  | 7,485 |  |  | 6,152 |  |  | 7,230 |  |  | 6,068 |
Proved undeveloped reserves | 3,032 |  |  | 15,289 |  |  | 9,260 |  |  | 9,576 |  |  | 12,474 |  |  | 10,090 |
The Company contributed its Permian Basin assets to Diamondback in 2012, as discussed in Note 4, resulting in a decrease of 12,564 thousand barrels of oil equivalent (MBOE) in estimated proved reserves in 2012. In addition, the Company experienced downward reserve revisions of 442 MBOE in estimated proved reserves in 2012 primarily due to a change in the drilling schedule of its Niobrara acreage. The Company also experienced downward reserve revisions in 2011. These downward revisions were primarily the result of the drilling of PUDs during the Company’s 2011 drilling program and ethane takeaway issues in the Permian Basin. The Company experienced downward reserve revisions in estimated proved reserves in 2010. These downward revisions were primarily the result of the five-year schedule for proved undeveloped reserves from the SEC’s “Modernization of Oil and Gas Reporting” Final Rule. Discounted Future Net Cash Flows (Unaudited) The following tables present the estimated future cash flows, and changes therein, from Gulfport’s proven oil and gas reserves as of December 31, 2012, 2011 and 2010 using an unweighted average first-of-the-month price for the period January through December for 2012, 2011 and 2010. Standardized Measure of Discounted Future Net Cash Flows Relating to Proved Oil and Gas Reserves (Unaudited)
| Year ended December 31,
| 2012 |  | 2011 |  | 2010
Future cash flows | $ | 954,833,000 |  |  | $ | 1,594,050,000 |  |  | $ | 1,479,295,000 |
Future development and abandonment costs | (159,113,000 | ) |  | (306,810,000 | ) |  | (301,651,000 | )
Future production costs | (147,024,000 | ) |  | (295,383,000 | ) |  | (305,814,000 | )
Future production taxes | (89,175,000 | ) |  | (124,739,000 | ) |  | (136,323,000 | )
Future income taxes | (114,867,000 | ) |  | (229,649,000 | ) |  | (159,171,000 | )
Future net cash flows | 444,654,000 |  |  | 637,469,000 |  |  | 576,336,000 |
10% discount to reflect timing of cash flows | (96,013,000 | ) |  | (260,788,000 | ) |  | (260,849,000 | )
Standardized measure of discounted future net cash flows | $ | 348,641,000 |  |  | $ | 376,681,000 |  |  | $ | 315,487,000 |
In order to develop its proved undeveloped reserves according to the drilling schedule used by the engineers in Gulfport’s reserve report, the Company will need to spend $82,772,000, $16,416,000 and $4,335,000 during years 2013, 2014 and 2015, respectively. Changes in Standardized Measure of Discounted Future Net Cash Flows Relating to Proved Oil and Gas Reserves (Unaudited)
| Year ended December 31,
| 2012 |  | 2011 |  | 2010
Sales and transfers of oil and gas produced, net of production costs | $ | (194,893,000 | ) |  | $ | (181,723,000 | ) |  | $ | (96,056,000 | )
Net changes in prices, production costs, and development costs | 108,941,000 |  |  | 136,071,000 |  |  | 122,147,000 |
Acquisition of oil and gas reserves in place | — |  |  | 72,000 |  |  | 63,043,000 |
Extensions and discoveries | 151,654,000 |  |  | 107,110,000 |  |  | 88,227,000 |
Revisions of previous quantity estimates, less related production costs | (10,504,000 | ) |  | (112,553,000 | ) |  | (89,155,000 | )
Sales of reserves in place | (214,867,000 | ) |  | — |  |  | — |
Accretion of discount | 37,668,000 |  |  | 31,549,000 |  |  | 24,077,000 |
Net changes in income taxes | 25,585,000 |  |  | (36,674,000 | ) |  | (54,879,000 | )
Change in production rates and other | 68,376,000 |  |  | 117,342,000 |  |  | 17,309,000 |
Total change in standardized measure of discounted future net cash flows | $ | (28,040,000 | ) |  | $ | 61,194,000 |  |  | $ | 74,713,000 |

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- Definition The entire disclosure for oil and gas producing industries. + References Reference 1: http://www.xbrl.org/2003/role/presentationRef -Publisher FASB -Name Accounting Standards Codification -Topic 932 -SubTopic 235 -Section 50 -URI http://asc.fasb.org/section&trid=2145543 Reference 2: http://www.xbrl.org/2003/role/presentationRef -Publisher FASB -Name Statement of Financial Accounting Standard (FAS) -Number 19 -Paragraph 59A-59Z, 59AA, 59BB, 59CC -LegacyDoc This reference is SUPERSEDED by the Accounting Standards Codification effective for interim and annual periods ending after September 15, 2009. This reference is included to help users transition from the previous accounting hierarchy and will be removed from future versions of this taxonomy. + Details
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