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Summary of Significant Accounting Policies (Policies) | 3 Months Ended
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Mar. 31, 2014
Summary of Significant Accounting Policies [Abstract] |
Use of Estimates | Use of Estimates The preparation of financial statements in conformity with U.S. GAAP requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities, disclosure of contingent assets and liabilities at the date of the financial statements and the reported amounts of revenues and expenses during the reporting period. Significant estimates include oil and gas reserves used for depletion and impairment considerations and the cost of future asset retirement obligations. Due to inherent uncertainties, including the future prices of oil and gas, these estimates could change in the near term and such changes could be material.
Properties and Equipment | Properties and Equipment Land, buildings, improvements, machinery and equipment are carried at cost. Depreciation of buildings, improvements, machinery and equipment is provided principally by the straight-line method over estimated useful lives ranging from 3 to 45 years. Components of Property and Equipment as of March 31, 2014 and December 31, 2013 are as follows:
|  | (In thousands) |
|  | March 31, |  |  | December 31, |
|  | 2014 |  |  | 2013 |
Oil & Gas properties |  |  |  |  |  |
Unproved |  | $ | 8,164 |  |  | $ | 7,478 |
Wells in progress |  |  | 1,151 |  |  |  | -- |
Proved |  |  | 142,658 |  |  |  | 136,521 |
|  |  | 151,973 |  |  |  | 143,999 |
Less accumulated depreciation |  |  |  |  |  |  |  |
depletion and amortization |  |  | (60,370 | ) |  |  | (57,077 | )
Net book value |  |  | 91,603 |  |  |  | 86,922 |
Mineral properties |  |  | 21,942 |  |  |  | 20,739 |
Building, land and equipment |  |  | 8,334 |  |  |  | 8,334 |
Less accumulated depreciation |  |  | (4,204 | ) |  |  | (4,135 | )
Net book value |  |  | 4,130 |  |  |  | 4,199 |
Totals |  | $ | 117,675 |  |  | $ | 111,860 |
Oil and Gas Properties | Oil and Gas Properties The Company follows the full cost method in accounting for its oil and gas properties. Under the full cost method, all costs associated with the acquisition, exploration and development of oil and gas properties are capitalized and accumulated in a country-wide cost center. This includes any internal costs that are directly related to development and exploration activities, but does not include any costs related to production, general corporate overhead or similar activities. Proceeds received from property disposals are credited against accumulated cost except when the sale represents a significant disposal of reserves, in which case a gain or loss is recognized. The sum of net capitalized costs and estimated future development and dismantlement costs for each cost center is depleted on the equivalent unit-of-production method, based on proved oil and gas reserves. Excluded from amounts subject to depletion are costs associated with unproved properties. Full Cost Pool - Full cost pool capitalized costs are amortized over the life of production of proven properties. Capitalized costs at March 31, 2014 and December 31, 2013 which were not included in the amortized cost pool were $9.3 million and $7.5 million, respectively. These costs consist of exploratory wells in progress, seismic costs that are being analyzed for potential drilling locations and land costs related to unevaluated properties. No capitalized costs related to unevaluated properties are included in the amortization base at March 31, 2014 or December 31, 2013. Ceiling Test Analysis - Under the full cost method, net capitalized costs are limited to the lower of unamortized cost reduced by the related net deferred tax liability and asset retirement obligations or the cost center ceiling. The cost center ceiling is defined as the sum of (i) estimated future net revenue, discounted at 10% per annum, from proved reserves, based on unescalated average prices per barrel of oil and per MMbtu of natural gas at the first day of each month in the 12-month period prior to the end of the reporting period and costs, adjusted for contract provisions and financial derivatives that hedge our oil and gas revenue and asset retirement obligations, (ii) the cost of properties not being amortized, and (iii) the lower of cost or market value of unproved properties included in the cost being amortized, reduced by (iv) the income tax effects related to differences between the book and tax basis of the crude oil and natural gas properties. If the net book value reduced by the related net deferred income tax liability and asset retirement obligations exceeds the cost center ceiling limitation, a non-cash impairment charge is required in the period in which the impairment occurs. We perform a quarterly ceiling test for each of our oil and gas cost centers. There is only one such cost center in 2014. The reserves used in the ceiling test and the ceiling test itself incorporate assumptions regarding pricing and discount rates over which management has no influence in the determination of present value. In arriving at the ceiling test for the quarter ended March 31, 2014, we used $98.30 per barrel for oil and $3.989 per MMbtu for natural gas (and adjusted for property specific gravity, quality, local markets and distance from markets) to compute the future cash flows of our producing properties. The discount factor used was 10%. During the three months ended March 31, 2014 and 2013, the Company recorded a proved property impairment of $0 and $5.8 million, respectively, related to its oil and gas assets. The impairment recorded for the three months ended March 31, 2013 was primarily due to a decline in the price of oil, additional capitalized well costs and changes in production. Management will continue to review our unproved properties based on market conditions and other changes and, if appropriate, unproved property amounts may be reclassified to the amortized base of properties within the full cost pool. Wells in Progress - Wells in progress represent the costs associated with unproved wells that have not reached total depth or have not been completed as of period end. They are classified as wells in progress and are withheld from the depletion calculation. The costs for these wells are then transferred to evaluated property when the wells reach total depth and are completed and the costs become subject to depletion and the ceiling test calculation in future periods.
Mineral Properties | Mineral Properties We capitalize all costs incidental to the acquisition of mineral properties. Mineral exploration costs are expensed as incurred. When exploration work indicates that a mineral property can be economically developed as a result of establishing proved and probable reserves, costs for the development of the mineral property as well as capital purchases and capital construction are capitalized and amortized using units of production over the estimated recoverable proved and probable reserves. Costs and expenses related to general corporate overhead are expensed as incurred. All capitalized costs are charged to operations if we subsequently determine that the property is not economical due to permanent decreases in market prices of commodities, excessive production costs or depletion of the mineral resource. Mineral properties at March 31, 2014 and December 31, 2013 reflect capitalized costs associated with our Mt. Emmons molybdenum property near Crested Butte, Colorado. Our carrying balance in the Mt. Emmons property at March 31, 2014 and December 31, 2013 is as follows:
|  | (In thousands) |
|  | March 31, |  |  | December 31, |
|  | 2014 |  |  | 2013 |
Costs associated with Mount Emmons |  |  |  |  |  |
beginning of year |  | $ | 20,739 |  |  | $ | 20,739 |
Property purchase (1) |  |  | 1,203 |  |  |  | -- |
Costs at the end of the period |  | $ | 21,942 |  |  | $ | 20,739 |
| (1) | On January 21, 2014, the Company acquired Thompson Creek Metals’ (“TCM”) 50% interest in 160 acres of fee land in the vicinity of the Mt. Emmons project mining claims for $1.2 million. The property was originally acquired jointly by the Company and TCM in January 2009.
Derivative Instruments | Derivative Instruments The Company uses derivative instruments, typically fixed-rate swaps and costless collars, to manage price risk relating to its oil and gas production. All derivative instruments are recorded in the consolidated balance sheets at fair value. The Company offsets fair value amounts recognized for derivative instruments executed with the same counterparty. Although the Company does not designate any of its derivative instruments as cash flow hedges, such derivative instruments provide an economic hedge of our exposure to commodity price risk associated with forecasted future oil and gas production. These contracts are accounted for using the mark-to-market accounting method and accordingly, the Company recognizes all unrealized and realized gains and losses related to these contracts currently in earnings and classifies them as gain (loss) on derivative instruments, on a net basis, in our consolidated statements of operations. The Company may also use puts, calls and basis swaps in the future. The Company’s Board of Directors sets all risk management policies and reviews the status and results of derivative activities, including volumes, types of instruments and counterparties on a quarterly basis. These policies require that derivative instruments be executed only by the Chief Executive Officer or President. The agreements with approved counterparties identify the Chief Executive Officer and President as the only Company representatives authorized to execute trades. Please see Note 4, Commodity Price Risk Management, for further discussion.
Revenue Recognition | Revenue Recognition The Company records oil and natural gas revenue under the sales method of accounting. Under the sales method, we recognize revenues based on the amount of oil or natural gas sold to purchasers, which may differ from the amounts to which we are entitled based on our interest in the properties. Natural gas balancing obligations as of March 31, 2014 were not significant. Revenues from real estate operations are reported on a gross revenue basis and are recorded at the time the service is provided.
Recent Accounting Pronouncements | Recent Accounting Pronouncements In April 2014, the Financial Accounting Standards Board issued new authoritative accounting guidance related to the recognition and presentation of discontinued operations in the financial statements. The guidance is aimed at reducing the frequency of disposals reported as discontinued operations by focusing on strategic shifts that have or will have a major effect on an entity’s operations and financial results. This authoritative accounting guidance is effective for interim and annual periods beginning after December 15, 2014, and is to be applied prospectively. The Company is currently evaluating the provisions of this authoritative guidance and assessing its impact, but does not currently believe it will have a material effect on the Company's financial statements or disclosures. There are no other new significant accounting standards applicable to the Company that have been issued but not yet adopted by the Company as of March 31, 2014.

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