B. SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES

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.

Principles of Consolidation

The financial statements of USE as of December 31, 2013 and 2012 include the accounts of USE and its wholly owned subsidiaries Energy One, LLC (“Energy One”) and Remington Village, LLC (“Remington Village”). All inter-company balances and transactions have been eliminated in consolidation. The financial statements as of December 31, 2013, 2012 and 2011 reflect USE’s ownership in a geothermal company, Standard Steam Trust LLC (“SST”), which is accounted for using the equity method. At December 31, 2013 USE’s ownership interest in SST was 19.54%.

Cash and Cash Equivalents

USE considers all highly liquid investments with original maturities of three months or less to be cash equivalents. The carrying value of cash and cash equivalents approximates fair value due to the short-term nature of these instruments. USE maintains its cash and cash equivalents in bank deposit accounts which may exceed federally insured limits. USE has not experienced any losses in such accounts and believes the accounts are not exposed to any significant credit risk on cash and cash equivalents.

Marketable Securities

USE categorizes its marketable securities as available-for-sale or held-to-maturity. Increases or decreases in the fair value of available-for-sale securities which are considered temporary are recorded within equity as comprehensive income or losses. Gains or losses as a result of sale are recorded in operations when realized. As of December 31, 2013 and 2012, USE had unrealized gains in the marketable securities before tax effect of $45,000 and $159,000, respectively.

Accounts Receivable

USE determines any required allowance by considering a number of factors including the length of time trade and other accounts receivable are past due and our previous loss history. USE provides reserves for account receivable balances when they become uncollectable. Payments subsequently received on such reserved receivables are credited to the allowance for doubtful accounts. During the years ended December 31, 2013 and 2012, USE recorded $0 and $13,000, respectively, in bad debt expense related to its multifamily housing project. The balance of accounts receivable at December 31, 2013 and 2012 are for the sale of oil and gas and have been collected subsequent to the balance sheet date. No reserve for uncollectable receivables was booked during the year ended December 31, 2013 or 2012.

Valuation of Equity Method Investment

The Company’s investment in SST is evaluated quarterly for possible impairment as applicable in accordance with ASC 323-10-35-32, which provides guidance related to a loss in value of an equity method investment. This evaluation as of December 31, 2013, based on historical losses, current market conditions and forward business plans of SST, resulted in a determination by management that the Company’s investment in SST was impaired as of December 31, 2013. As a result, the Company incurred a non-cash impairment charge of $2.2 million to write off the carrying amount of the investment in SST at December 31, 2013 to zero. Future equity losses will not be recorded, however, the Company will resume accounting for the investment in SST under the equity method should SST subsequently report net income and the Company’s share of that net income equals the net losses not recognized during the period the equity method was suspended. For additional information about the Company’s investment in SST, please refer to Note F – Investment in Standard Steam Trust, LLC.

Restricted Investments

USE accounts for cash deposits held as collateral for reclamation obligations as restricted investments. Maturities or release dates less than twelve months from the end of the reported accounting period are reported as current assets while maturities or release dates in excess of twelve months from report dates are reported as long term assets.

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. Following is a breakdown of the lives over which assets are depreciated:

Machinery and Equipment:
	Office Equipment	3 to 5 years
	Field Tools and Hand Equipment	5 to 7 years
	Vehicles and Trucks	3 to 7 years
	Heavy Equipment	7 to 10 years
Buildings and Improvements:
	Service Buildings	20 years
	Corporate Headquarter Building	45 years

Components of Property and Equipment as of December 31, 2013 and 2012 are as follows:

	(In thousands)
	December 31,			December 31,
	2013			2012
Oil & Gas properties
Unproved	$	7,478		$	9,169
Proved		136,521			119,919
		143,999			129,088
Less accumulated depreciation
depletion and amortization		(57,077	)		(43,454	)
Net book value		86,922			85,634

Mineral properties		20,739			20,739

Building, land and equipment		8,334			8,469
Less accumulated depreciation		(4,135	)		(4,034	)
Net book value		4,199			4,435
Totals	$	111,860		$	110,808

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 December 31, 2013 and 2012 which were not included in the amortized cost pool were $7.5 million and $9.2 million, respectively. These costs consist of exploratory wells in progress and land costs related to unevaluated properties. No capitalized costs related to unproved properties are included in the amortization base at December 31, 2013 and 2012. It is anticipated that these costs will be added to the full cost amortization pool within the next two years as properties are evaluated, drilled or abandoned.

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 USE’s 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 was only one such cost center in 2013. 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 year ended December 31, 2013, USE used $96.78 per barrel for oil and $3.67 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 USE’s producing properties. The discount factor used was 10%.

During the first quarter of 2013, we recorded a proved property impairment of $5.8 million related to our oil and gas assets. The impairment was primarily due to a decline in the price of oil, additional capitalized well costs and changes in production. At December 31, 2013, our net capitalized costs did not exceed the ceiling test limit and as a result, no further proved property impairment was recorded at December 31, 2013. As of year-end there were no unproved properties that were considered to be impaired and reclassified to properties being amortized. Management will continue to review the Company’s 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 withheld from the depletion calculation and the ceiling test. The costs for these wells are then transferred to evaluated property when the wells reach total depth and are cased and the costs become subject to depletion and the ceiling test calculation in future periods.

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 economic due to permanent decreases in market prices of commodities, excessive production costs or depletion of the mineral resource.

Mineral properties at December 31, 2013 and 2012 reflect capitalized costs associated with our Mt. Emmons molybdenum property near Crested Butte, Colorado. Our carrying balance in the Mt. Emmons property at December 31, 2013 and 2012 is as follows:

	(In thousands)
	December 31,		December 31,
	2013		2012
Costs associated with Mount Emmons
beginning of year	$	20,739	$	20,739
Development costs		--		--
Costs at the end of the period	$	20,739	$	20,739

Long-Lived Assets

We evaluate our long-lived assets for impairment when events or changes in circumstances indicate that the related carrying amount may not be recoverable. Impairment calculations are generally based on market appraisals. If estimated future cash flows, on an undiscounted basis, are less than the carrying amount of the related asset, an asset impairment is considered to exist. Changes in significant assumptions underlying future cash flow estimates may have a material effect on our financial position and results of operations.

Assets Held for Sale

In accordance with authoritative accounting guidance regarding property plant and equipment, assets are classified as held for sale when we commit to a plan to sell the assets and there is reasonable certainty that the sale will take place within one year. Upon classification as held for sale, long-lived assets are no longer depreciated or depleted, and a measurement for impairment is performed to determine if there is any excess of carrying value over fair value less costs to sell. Subsequent changes to estimated fair value less the cost to sell will impact the measurement of assets held for sale if the fair value is determined to be less than the carrying value of the assets.

In January 2011, we made the decision to sell our Remington Village multifamily project in Gillette, Wyoming and in September 2012, we made the decision to sell our corporate aircraft and related facilities to reduce overhead costs. All assets classified as assets held for sale at December 31, 2012 were sold in the year ending December 31, 2013. Operations related to Remington Village are shown in discontinued operations on the accompanying consolidated statements of operations. For additional discussion on assets held for sale, please refer to Note G – Assets Held for Sale.

	(In thousands)
	December 31,		December 31,
	2013		2012
Assets held for sale
Remington Village	$	--	$	15,167
Corporate aircraft and facilities		--		1,884
	$	--	$	17,051

Liabilities held for sale
Remington Village	$	--	$	10,022

Derivative Instruments

The Company uses derivative instruments, typically costless collars and fixed-rate swaps, to manage price risk underlying 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 that are related to these contracts currently in earnings and classifies them as gain (loss) on derivative instruments, net 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. See Note D, Commodity Price Risk Management, for further discussion.

Fair Value of Financial Instruments

The carrying amount of cash equivalents, receivables, other current assets, accounts payable and accrued expenses approximate fair value because of the short-term nature of those instruments. The recorded amounts for short-term and long-term debt approximate the fair market value due to the variable nature of the interest rates on the short-term debt, and the fact that interest rates remain generally unchanged from issuance of the long-term debt.

Asset Retirement Obligations

USE accounts for its asset retirement obligations under FASB ASC 410-20, "Asset Retirement Obligations." USE records the fair value of the reclamation liability on its inactive mining properties and its operating oil and gas properties as of the date that the liability is incurred. USE reviews the liability each quarter and determines if a change in estimate is required, and it accretes the discounted liability on a quarterly basis for the future liability. Final determinations are made during the fourth quarter of each year. USE deducts any actual funds expended for reclamation during the quarter in which it occurs.

The following is a reconciliation of the total liability for asset retirement obligations:

	(In thousands)
	December 31,			December 31,
	2013			2012
Beginning asset retirement obligation	$	686		$	510
Accretion of discount		38			34
Liabilities incurred		131			142
Liabilities settled		(43	)		--
Ending asset retirement obligation	$	812		$	686

Mineral properties	$	175		$	162
Oil & Gas wells		637			524
Ending asset retirement obligation	$	812		$	686

Revenue Recognition

USE derives revenue primarily from the sale of produced oil, gas, and NGLs. The Company reports revenue as the gross amount received before taking into account production taxes and transportation costs, which are reported separately as expenses and are included in oil and gas production expense in the accompanying statements of operations. USE records natural gas and oil revenue under the sales method of accounting. Revenue is recorded in the month that the production is delivered to the purchaser. Payment is generally received between 30 and 90 days after the date of production. At the end of each month, we estimate the amount of production delivered to the purchaser and the price we will receive. USE uses its knowledge of its properties, their historical performance, market prices, and other factors as the basis for these estimates.

USE has exposure to credit risk in the event of nonpayment by our operators, which are all in energy related industries. During 2013, we had three major operators, Statoil, Zavanna, LLC and Contango Oil & Gas Company which accounted for approximately 38 percent, 32 percent and 18 percent of our total oil, gas and NGL revenues, respectively. During 2012 we had two major operators, Statoil and Zavanna, which accounted for 57 percent and 32 percent of our total oil, gas and NGL revenues, respectively. During 2011, we had one major operator, Statoil, which accounted for approximately 74 percent of our total oil, gas, and NGL revenues.

Revenues from real estate operations are reported on a gross revenue basis and are recorded at the time the service is provided.

Stock Based Compensation

USE measures the cost of employee and director services received in exchange for all equity awards granted, including stock options, based on the fair market value of the award as of the grant date. USE computes the fair values of its options granted to employees using the Black Scholes pricing model and the following weighted average assumptions:

	Year Ended December 31,
	2013	2012	2011
Risk-free interest rate	1.66%	0.82% to 1.41%	1.77%
Expected lives (years)	6.0	5.0 to 6.0	6.0
Expected volatility	62.59%	61.87% to 63.59%	59.64%
Expected dividend yield	--	--	--

USE recognizes the cost of the equity awards over the period during which an employee is required to provide service in exchange for the award, usually the vesting period. As share-based compensation expense is recognized based on awards ultimately expected to vest, the expense has been reduced for estimated forfeitures based on historical forfeiture rates.

Income Taxes

USE recognizes deferred income tax assets and liabilities for the expected future income tax consequences, based on enacted tax laws, of temporary differences between the financial reporting and tax bases of assets, liabilities and carry forwards.

Additionally, USE recognizes deferred tax assets for the expected future effects of all deductible temporary differences, loss carry forwards and tax credit carry forwards. Deferred tax assets are reduced, if deemed necessary, by a valuation allowance for any tax benefits which, based on current circumstances, are not expected to be realized. At December 31, 2013 and 2012, management believed it was more likely than not that such tax benefits would not be realized and a valuation allowance has been provided. For further discussion, please refer to Note I – Income Taxes.

Earnings Per Share

Basic net income (loss) per share is computed based on the weighted average number of common shares outstanding. Common shares held by the ESOP are included in the computation of earnings per share. Total shares held by the ESOP at December 31, 2013, 2012, and 2011 were 877,399, 824,123, and 684,643, respectively.

Diluted net income (loss) per share is calculated by dividing net income or loss by the diluted weighted average common shares outstanding, which includes the effect of potentially dilutive securities. Potentially dilutive securities for this calculation consist of in-the-money outstanding stock options. When there is a loss from continuing operations, all potentially dilutive shares are anti-dilutive and are excluded from the calculation of net income (loss) per share. The treasury stock method is used to measure the dilutive impact of in-the-money stock options.

The following table details the weighted-average dilutive and anti-dilutive securities related to stock options for the years presented:

	For the years ended December 31,
	2013	2012	2011

Dilutive	--	--	--
Anti-dilutive	872,185	--	969,631

Recent Accounting Pronouncements

On January 1, 2013, the Company adopted new authoritative accounting guidance issued by the Financial Accounting Standards Board (“FASB”), which enhanced disclosures by requiring an entity to disclose information about netting arrangements, including rights of offset, to enable users of its financial statements to understand the effect of those arrangements on its financial position and provided clarification as to the specific instruments that should be considered in these disclosures. These pronouncements were issued to facilitate comparison between financial statements prepared on the basis of GAAP and International Financial Reporting Standards. These disclosures are effective for annual and interim reporting periods beginning on or after January 1, 2013, and are to be applied retrospectively for all comparative periods presented. The impact of retrospectively adopting these pronouncements did not have a material impact on the Company’s consolidated financial statements but did impact the Company's disclosures.

In July 2013, the FASB issued new authoritative accounting guidance related to the reporting of unrecognized tax benefits when a net operating loss carryforward, similar tax loss, or tax credit carryforward exists. This authoritative accounting guidance is effective for interim and annual periods beginning after December 15, 2013. The Company is currently evaluating the provisions of this guidance and assessing its impact on the Company’s financial statements and disclosures, but does not believe its financial statements will be significantly impacted.

The Company has reviewed other current outstanding statements from the FASB and does not believe that any of those statements will have a material effect on the financial statements of the Company when adopted.