U.S. Energy (USEG) 10-K 28 Mar 18 2017 FY Annual report Financial data

Document and Entity Information

Document and Entity Information - USD ($)	12 Months Ended
	Dec. 31, 2017	Mar. 21, 2018	Jun. 30, 2017
Document And Entity Information
Entity Registrant Name	US ENERGY CORP
Entity Central Index Key	101,594
Document Type	10-K
Document Period End Date	Dec. 31, 2017
Amendment Flag	false
Current Fiscal Year End Date	--12-31
Entity a Well-known Seasoned Issuer	No
Entity a Voluntary Filer	No
Entity's Reporting Status Current	Yes
Entity Filer Category	Smaller Reporting Company
Entity Public Float			$ 4,171,464
Entity Common Stock, Shares Outstanding		12,440,927
Trading Symbol	USEG
Document Fiscal Period Focus	FY
Document Fiscal Year Focus	2,017

Consolidated Balance Sheets

Consolidated Balance Sheets - USD ($) $ in Thousands	Dec. 31, 2017	Dec. 31, 2016
Current assets:
Cash and equivalents	$ 3,277	$ 2,518
Oil and gas sales receivable	687	562
Discontinued operations - assets of mining segment	114	114
Assets available for sale	653	653
Marketable securities	876	947
Refundable deposits	250
Other current assets	61	95
Total current assets	5,918	4,889
Oil and gas properties under full cost method:
Unevaluated properties and exploratory wells in progress	4,664	4,664
Evaluated properties	86,313	87,834
Less accumulated depreciation, depletion and amortization	(83,362)	(82,640)
Net oil and gas properties	7,615	9,858
Other assets:
Property and equipment, net	1,717	1,864
Other assets	66	156
Total other assets	1,783	2,020
Total assets	15,316	16,767
Accounts payable and accrued liabilities:
Payable to major operator		2,710
Contingent ownership interests		1,430
Other	707	743
Related party payable	50
Accrued compensation and benefits	64	49
Current portion of long-term debt	600	6,000
Liabilities from derivative contracts	161
Total current liabilities	1,582	10,932
Noncurrent liabilities:
Long-term debt, less current portion	937
Asset retirement obligations	913	1,045
Warrant liability	1,200	1,030
Other liabilities	22	2
Total noncurrent liabilities	3,072	2,077
Commitments, contingencies, and related party transactions (Note 10)
Shareholders' equity:
Preferred stock, par value $0.01 per share. Authorized 100,000 shares, 50,000 shares of series A Convertible Preferred Stock in 2017; liquidation preference of $2,527 as of December 31, 2017	1	1
Common stock, $0.01 par value; unlimited shares authorized; 11,820,057 and 6,134,506 shares issued and outstanding, respectively	118	61
Additional paid-in capital	136,631	127,576
Accumulated deficit	(125,185)	(123,825)
Other comprehensive loss	(903)	(55)
Total shareholders' equity	10,662	3,758
Total liabilities and shareholders' equity	$ 15,316	$ 16,767

Consolidated Balance Sheets (Pa

Consolidated Balance Sheets (Parenthetical) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016
Preferred stock, par value	$ 0.01	$ 0.01
Preferred stock, authorized	100,000	100,000
Liquidation preference shares	$ 2,527
Common stock, par value	$ 0.01	$ 0.01
Common stock, unlimited authorized	Unlimited	Unlimited
Common stock, issued	11,820,057	6,134,506
Common stock, outstanding	11,820,057	6,134,506
Series A Convertible Preferred Stock [Member]
Preferred stock, authorized	50,000

Consolidated Statements of Oper

Consolidated Statements of Operations and Comprehensive Loss - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Revenue:
Oil	$ 5,054	$ 4,689	$ 9,047
Natural gas and liquids	1,491	1,057	1,249
Total revenue	6,545	5,746	10,296
Oil and gas operations:
Production costs	3,402	2,728	7,352
Depreciation, depletion and amortization	753	2,529	8,412
Impairment of oil and gas properties		9,568	57,676
General and administrative:
Compensation and benefits, including directors and contract employees	741	640	2,602
Stock-based compensation	323	213	948
Employee severance costs		3	504
Professional fees, insurance and other	2,314	1,994	1,866
Total operating expenses	7,533	17,675	79,360
Operating Loss	(988)	(11,929)	(69,064)
Other income (expense):
Realized gain (loss) on commodity price risk derivatives	135	1,440	(75)
Unrealized gain (loss) on commodity price risk derivatives	(161)	(1,634)	1,634
Gain on sale of assets	3	102	121
Gain on sale of oil and gas properties	4,318
Loss on debt for equity conversion	(4,440)
Gain (loss) on investments	777	750	(68)
Rental and other income (loss)	(321)	(169)	431
Warrant revaluation gain (loss)	(170)	210
Interest expense	(513)	(442)	(263)
Total other income (expense)	(372)	257	1,780
Loss from continuing operations	(1,360)	(11,672)	(67,284)
Discontinued operations:
Discontinued operations		(2,448)	(2,992)
Impairment loss on discontinued operations			(22,620)
Loss from discontinued operations		(2,448)	(25,612)
Net loss	(1,360)	(14,120)	(92,896)
Change in fair value of marketable equity securities, net of tax	(848)	(55)	56
Comprehensive loss	(2,208)	(14,175)	(92,840)
Loss from continuing operations	(1,360)	(11,672)	(67,284)
Accrued dividends related to Series A Convertible Preferred Stock	(514)	(232)
Loss from continuing operations applicable to common shareholders	$ (1,874)	$ (11,904)	$ (67,284)
Loss per share- basic and diluted
Continuing operations	$ (0.23)	$ (2.5)	$ (14.38)
Discontinued operations		(0.51)	(5.48)
Total	$ (0.23)	$ (3.01)	$ (19.86)
Weighted average shares outstanding
Basic and diluted	5,899,802	4,768,013	4,677,500

Consolidated Statements of Chan

Consolidated Statements of Changes in Shareholders' Equity - USD ($) $ in Thousands	Common Stock [Member]	Preferred Stock [Member]	Additional Paid-in Capital [Member]	Accumulated Deficit [Member]	Accumulated Other Comprehensive Loss [Member]	Total
Balance at Dec. 31, 2014	$ 47		$ 124,213	$ (16,809)	$ (56)	$ 107,395
Balance, shares at Dec. 31, 2014	4,674,610
Issuance of common stock upon vesting of restricted common stock, net			332			332
Issuance of common stock upon vesting of restricted common stock, net, shares	25,346
Stock-based compensation			588			588
Realized loss on marketable equity securities					56	$ 56
Revised 2016 option grants, shares						340,711
Net loss				(92,896)		$ (92,896)
Balance at Dec. 31, 2015	$ 47		125,133	(109,705)		15,475
Balance, shares at Dec. 31, 2015	4,699,956
Stock-based compensation			213			213
Issuance of common stock	$ 3		(3)
Issuance of common stock , shares	367,667
Cash payment for fractional shares			(3)			(3)
Cash payment for fractional shares, shares	(1,245)
Issuance of common shares on 7/7/16 to settle ESOP	$ 1		169			170
Issuance of common shares on 7/7/16 to settle ESOP, shares	68,128
Issuance of common shares	$ 10		68			78
Issuance of common shares, shares	1,000,000
Issuance of Series A Convertible Preferred Stock		$ 1	1,999			2,000
Issuance of Series A Convertible Preferred Stock, shares		50,000
Unrealized loss on marketable equity securities					(55)	$ (55)
Revised 2016 option grants, shares
Net loss				(14,120)		$ (14,120)
Balance at Dec. 31, 2016	$ 61	$ 1	127,576	(123,825)	(55)	3,758
Balance, shares at Dec. 31, 2016	6,134,506	50,000
Stock-based compensation			128			128
Unrealized loss on marketable equity securities					(848)	(848)
Placement fees recorded in equity			(114)			(114)
Revised 2016 option grants	$ (1)		196			$ 195
Revised 2016 option grants, shares	(151,008)					170,000
Issued shares to creditor	$ 58		8,845			$ 8,903
Issued shares to creditor, shares	5,819,270
Net loss				(1,360)		(1,360)
Balance at Dec. 31, 2017	$ 118	$ 1	$ 136,631	$ (125,185)	$ (903)	$ 10,662
Balance, shares at Dec. 31, 2017	11,802,768	50,000

Consolidated Statements of Cash

Consolidated Statements of Cash Flows - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Cash flows from operating activities:
Net loss	$ (1,360)	$ (14,120)	$ (92,896)
Loss from discontinued operations		2,448	25,612
Loss from continuing operations	(1,360)	(11,672)	(67,284)
Adjustments to reconcile loss from continuing operations to net cash provided by / (used in) operating activities:
Depreciation, depletion, accretion, and amortization	890	2,529	8,557
Debt amortization
Impairment of oil and gas properties		9,568	57,676
Change in fair value of oil price risk derivative	161	1,634	(1,634)
Interest change in Major Operator	(141)	(1,476)
Gain on sale of oil and gas properties	(4,318)
Loss on conversion of debt to equity	4,440
Gain on sale of assets	(3)	(102)	(121)
Stock-based compensation and services	323	213	948
(Gain)/loss on Warrants	170	(210)
Other	(704)	(372)	(110)
Decrease (increase) in:
Oil and gas sales receivable	(125)	580	2,034
Other assets	(159)	86	63
Increase (decrease) in:
Accounts payable	(77)	(1,050)	1,126
Major operator overpayments			1,429
Accrued compensation and benefits	11	(1,133)	(188)
Other liabilities			8
Net cash provided by / (used in) operating activities	(892)	(1,405)	2,504
Cash flows from investing activities:
Capital expenditures	(299)	(194)	(3,620)
Proceeds from sale of oil and gas properties and other	2,000		264
Proceeds from settlement of property litigation			1,500
Net change in restricted investments			1,291
Net cash provided by / (used) in investing activities:	1,701	(194)	(565)
Cash flows from financing activities:
Issuance of common stock	(27)	1,317
Redemption of common stock		(3)	(29)
Payments for debt issuance costs	(23)	(103)	(125)
Net cash provided by / (used in) financing activities	(50)	1,211	(154)
Discontinued operations:
Net cash used in operating activities		(448)	(2,440)
Net cash used in investing activities			(1)
Net cash used in discontinued operations		(448)	(2,441)
Net increase (decrease) in cash and equivalents	759	(836)	(656)
Cash and equivalents, beginning of year	2,518	3,354	4,010
Cash and equivalents, end of year	3,277	2,518	3,354
Supplemental disclosures of cash flow information:
Cash payments for income taxes
Cash payments for interest	451	442	210
Non-cash investing and financing activities:
Unrealized gain/(loss) on marketable equity securities	(848)	(55)	56
Fees incurred during equity for debt conversion and common stock sales agreement	114
Debt Long Term to Short Term	600
Payable to Major Operator forgiven	3,999
Increase (decrease) in accrued capital expenditures for oil and gas properties	48	112	(112)
Asset Retirement obligations assumed by Purchaser	(167)	(1)
Net additions to oil and gas properties through asset retirement obligations	$ 3		$ 61

Organization, Operations and Si

Organization, Operations and Significant Accounting Policies	12 Months Ended
	Dec. 31, 2017
Organization, Consolidation and Presentation of Financial Statements [Abstract]
Organization, Operations and Significant Accounting Policies	1. ORGANIZATION, OPERATIONS AND SIGNIFICANT ACCOUNTING POLICIES Organization and Operations U.S. Energy Corp. (collectively with its subsidiaries Energy One LLC, Highlands Ranch LLC, and Remington Village, LLC referred to as the “Company”) was incorporated in the State of Wyoming on January 26, 1966. The Company’s principal business activities are focused in the acquisition, exploration and development of oil and gas properties in the United States. Use of Estimates The preparation of financial statements in conformity with generally accepted accounting principles in the United States (“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 that are used in the calculation of depreciation, depletion, amortization and impairment of the carrying value of evaluated oil and gas properties; production and commodity price estimates used to record accrued oil and gas sales receivable; valuation of commodity derivative instruments; the impact of commodity prices and other events affecting impairment of mining properties; and the cost of future asset retirement obligations. The Company evaluates its estimates on an on-going basis and bases its estimates on historical experience and on various other assumptions the Company believes to be reasonable. 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 accompanying financial statements include the accounts of the Company and its wholly-owned subsidiary Energy One LLC (“Energy One”). All inter-company balances and transactions have been eliminated in consolidation. Certain prior period amounts have been reclassified to conform to the current period presentation of the accompanying financial statements. Cash and Equivalents The Company considers all highly liquid investments with original maturities of three months or less to be cash equivalents. Oil and Gas Sales Receivable The Company’s accounts receivable consists primarily of receivables from joint interest operators for the Company’s share of oil, gas, and natural gas liquids (“NGLs”). Generally, the Company’s oil and gas sales receivables are collected within three months and the Company has had minimal bad debts. Collectability is dependent upon the financial wherewithal of the joint interest operators and is influenced by the general economic conditions of the industry. Receivables are not collateralized. As of December 31, 2017 and 2016, the Company had not provided for an allowance for doubtful accounts. Marketable Equity Securities The Company categorizes its marketable equity securities as available-for-sale. Accordingly, increases or decreases in the fair value are generally presumed to be temporary and are recorded as a component of shareholders’ equity within comprehensive income or loss. The Company periodically evaluates if cumulative losses are indicative of other than temporary impairment whereby a loss is recognized when management determines that the value is unlikely to recover to the Company’s cost basis. Gains or losses from sales are recorded in operations when realized. Oil and Gas Properties The Company follows the full cost method of 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 are subject to depreciation, depletion and amortization (“DD&A”) using the equivalent unit-of-production method, based on total proved oil and gas reserves. For financial statement presentation, DD&A includes accretion expense related to asset retirement obligations. Excluded from amounts subject to DD&A are costs associated with unevaluated properties, including exploratory wells in progress. Under the full cost method, net capitalized costs are limited to the lower of unamortized cost reduced by the related net deferred tax liability, or the cost center ceiling (the “Ceiling Test”). 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 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 the Company’s oil and gas revenue and asset retirement obligations, (ii) the cost of unevaluated 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 gas properties. If the net book value reduced by the related net deferred income tax liability (if any) 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. Since all of the Company’s oil and gas properties are located within the United States, the Company only has one cost center for which a quarterly Ceiling Test is performed. Property 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 as follows: Years Real estate: Buildings 20 to 45 Building improvements 10 to 25 Land improvements 10 to 35 Administrative assets: Computers and software 3 to 10 Office furniture and equipment 5 to 20 Vehicles and other 5 Discontinued Operations- Mining Properties Effective January 1, 2015, the Company adopted new accounting guidance related to the recognition and presentation of discontinued operations in its financial statements. Under the revised guidance, beginning in 2015 only disposals of businesses that represent strategic shifts that have a major effect on an organization’s operations and financial results will be reported in discontinued operations. Accordingly, as discussed in Note 6, the Company’s disposal of its mining segment qualified for reporting as discontinued operations in the accompanying financial statements. The Company capitalized all costs incidental to the acquisition of mining properties. Mining equipment was depreciated using the straight-line method over estimated useful lives that ranged from 10 to 20 years. Costs of operating a related water treatment plant on the mine property, holding costs to maintain permits, mining exploration costs and general corporate overhead were expensed as incurred. Capitalized costs were charged to operations to the extent it was subsequently determined that the mine property were not economic due to permanent decreases in market prices of commodities, excessive production costs, depletion of the mineral resource, or other factors. Impairment of Long-Lived Assets The Company evaluates long-lived assets for impairment when events or changes in circumstances indicate that the related carrying amount may not be recoverable. If estimated future cash flows, on an undiscounted basis, are less than the carrying amount of the related asset, an asset impairment charge is recognized, and measured as the amount by which the carrying value exceeds the estimated fair value. Changes in significant assumptions underlying future cash flow estimates may have a material effect on the Company’s financial position and results of operations. Long-lived assets are classified as held for sale when the Company commits to a plan to sell the assets. Such assets are classified within current assets if 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. 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 the Company’s 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 the Company’s consolidated statements of operations. The Company may also use puts, calls and basis swaps in the future. Warrant Liability From time to time we may have financial instruments such as warrants that may be classified as liabilities when either (a) the holders possess rights to net cash settlement, (b) physical or net equity settlement is not in our control, or (c) the instruments contain other provisions that causes us to conclude that they are not indexed to our equity. Such instruments are initially recorded at fair value and subsequently adjusted to fair value at the end of each reporting period through earnings. Accordingly, warrants are accounted for as a liability. This warrant liability is accounted for at fair value with changes in fair value reported in earnings. Asset Retirement Obligations The Company records the estimated fair value of restoration and reclamation liabilities related to its oil and gas properties and its inactive mining properties as of the date that the liability is incurred. The Company reviews the liability each quarter and determines if a change in estimate is required, and accretion of the discounted liability is recorded based on the passage of time. Final determinations are made during the fourth quarter of each year. The Company deducts any actual funds expended for restoration and reclamation during the quarter in which it occurs. Revenue Recognition The Company derives revenue primarily from the sale of produced oil, natural gas, and NGLs. In the accompanying statements of operations, revenue from gas includes sales of both natural 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 lease operating expense in the accompanying statements of operations. The Company records oil and gas revenue under the sales method of accounting. Gas balancing obligations as of December 31, 2017, 2016, and 2015 were not significant. Revenue is recorded in the month that the production is delivered to the purchaser. At the end of each month, the Company estimates the amount of production delivered to the purchaser and the price the Company will receive. The Company uses its knowledge of its properties, their historical performance, market prices, and other factors as the basis for these estimates. 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 The Company 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. The Company computes the fair values of its options granted to employees using the Black Scholes pricing model. The Company 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. For awards granted which contain a graded vesting schedule, and the only condition for vesting is a service condition, compensation cost is recognized as an expense on a straight-line basis over the requisite service period as if the award was, in substance, a single award. Stock-based compensation expense is recognized based on awards ultimately expected to vest whereby estimates of forfeitures are based upon historical experience. Income Taxes The Company 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, the Company 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, 2017 and 2016, management believed it was more likely than not that such tax benefits would not be realized and a valuation allowance has been provided. The Company would recognize any interest and penalties related to uncertain tax positions as a component of income tax expense. Earnings Per Share Basic net income (loss) per share is computed based on the weighted average number of common shares outstanding. 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. Recent Accounting Pronouncements Revenue recognition. Financial instruments. Recognition and Measurement of Financial Assets and Financial Liabilities Leases. Leases Statement of cash flows. Statement of Cash Flows Business combinations. Clarifying the Definition of a Business Stock-based compensation. Scope of Modification Accounting Hedging activities Financial instruments with characteristics of liabilities and equity.

Liquidity

Liquidity	12 Months Ended
	Dec. 31, 2017
Organization, Consolidation and Presentation of Financial Statements [Abstract]
Liquidity	2. LIQUIDITY As of December 31, 2017, the Company had a working capital surplus of $4.3 million and an accumulated deficit of $125.2 million. Additionally, the Company incurred a net loss of $1.4 million for the year ended December 31, 2017. As of December 31, 2017, the Company was in full compliance with all covenants under its credit agreement. During the 2017, the Company completed the following actions which are expected to improve the Company’s operating results going forward while increasing the ability of the Company to grow in the current oil and gas industry price environment. ● On October 3, 2017, U.S. Energy Corp. (the “Company”), the Company’s wholly owned subsidiary Energy One LLC and Statoil Oil and Gas LP (“Statoil”) entered into a purchase and sale agreement (the “Purchase Agreement”), under which, the Company assigned certain non-operated assets in the Williston Basin, North Dakota in consideration for the elimination of $4.0 million in outstanding liabilities and payment by Statoil to the Company of $2.0 million in cash. U.S. Energy has historically accounted for the eliminated liabilities on the Company’s balance sheet under “Payable to major operator” and “Contingent ownership interests.” The Purchase Agreement has an effective date of August 1, 2017 and was unanimously approved by the board of directors of the Company. ● On December 27, 2017, U.S. Energy Corp. received shareholder approval for the exchange agreement (“Exchange Agreement”) by and among the Company, the Company’s wholly owned subsidiary Energy One LLC and APEG Energy II, L.P., (“APEG”), an entity controlled by Angelus Private Equity Group, LLC pursuant to which, on the terms and subject to the conditions of the Exchange Agreement, APEG exchanged $4,463,380 of outstanding borrowings under the Company’s Credit Facility, for 5,819,270 new shares of common stock of the Company, par value $0.01 per share, representing an exchange price of $0.767 representing a 1.3% premium over the 30-day volume weighted average price of the Company’s common stock on September 20, 2017 (the “Exchange Shares”). Accrued, unpaid interest on the Credit Facility held by APEG was paid in cash at the closing of the transaction. Following the close of the transaction, APEG holds approximately 49.3% of the outstanding Common Stock of U.S. Energy. The Transaction was approved by the Company’s shareholders and closed in the fourth quarter of 2017. Additionally, the transaction was recorded based on a $1.53 stock price which represented the Company’s stock price on the date of shareholder approval. As of December 31, 2017, the Company had cash and equivalents of $3.3 million. Management believes overhead and mining expense eliminations have positioned the Company to survive the continued low commodity price environment. However, there can be no assurance that the Company will be able to complete future financings, dispositions or acquisitions on acceptable terms or at all. Our strategy is to continue to (1) maintain adequate liquidity and selectively participate in new drilling and completion activities, subject to economic and industry conditions, (2) pursue acquisition and disposition opportunities, and (3) evaluate various avenues to strengthen our balance sheet and improve our liquidity position. We expect to fund any near-term capital requirements and working capital needs from existing cash on hand. Because production from existing oil and natural gas wells declines over time, further reductions of capital expenditures used to drill and complete new oil and natural gas wells would likely result in lower levels of oil and natural gas production in the future.

Commodity Price Risk Derivative

Commodity Price Risk Derivatives	12 Months Ended
	Dec. 31, 2017
Price Risk Derivatives [Abstract]
Commodity Price Risk Derivatives	3. COMMODITY PRICE RISK DERIVATIVES The Company’s wholly-owned subsidiary Energy One has entered into commodity price derivative contracts (“economic hedges”) with BP Energy. The derivative contracts are priced based on West Texas Intermediate (“WTI”) quoted prices for crude oil and Henry Hub quoted prices for natural gas. The Company is a guarantor of Energy One’s obligations under the economic hedges. The objective of utilizing the economic hedges is to reduce the effect of price changes on a portion of the Company’s future oil production, achieve more predictable cash flows in an environment of volatile oil and gas prices and to manage the Company’s exposure to commodity price risk. The use of these derivative instruments limits the downside risk of adverse price movements. However, there is a risk that such use may limit the Company’s ability to benefit from favorable price movements. Energy One may, from time to time, add incremental derivatives to hedge additional production, restructure existing derivative contracts or enter into new transactions to modify the terms of current contracts in order to realize the current value of its existing positions. The Company does not engage in speculative derivative activities or derivative trading activities, nor does it use derivatives with leveraged features. Presented below is a summary of outstanding crude oil and natural gas swaps as of December 31, 2017. Action Begin End Quantity (bbls/d) Price Crude oil price swaps Bought 1/1/18 6/30/18 150 52.20 Action Begin End Quantity (mcf/d) Price Natural gas price swaps Bought 1/1/18 12/31/18 2,500 3.01 Natural gas price swaps Sold 1/1/18 12/31/18 2,000 2.98 We recognized a realized gain on commodity price risk derivatives of $0.1 million for the year ended December 31, 2017 compared to a realized gain of $1.4 million for 2016. We recognized an unrealized loss on commodity price risk derivatives of $0.2 million for the year ended December 31, 2017 compared to an unrealized loss of $1.6 million for 2016. As of December 31, 2017, the Company had un unrealized loss on commodity derivative contracts of $0.16 million which consisted of an unrealized loss from oil price derivatives of $0.22 million which was offset by an unrealized gain from natural gas commodity derivatives of $0.06 million.

Oil and Gas Producing Activitie

Oil and Gas Producing Activities	12 Months Ended
	Dec. 31, 2017
Oil and Gas Property [Abstract]
Oil and Gas Producing Activities	4. OIL AND GAS PRODUCING ACTIVITIES Divestitures On October 3, 2017, U.S. Energy Corp. (the “Company”), the Company’s wholly owned subsidiary Energy One LLC and Statoil Oil and Gas LP (“Statoil”) entered into a purchase and sale agreement (the “Purchase Agreement”), pursuant to which, on the terms, and subject to the conditions of the Purchase Agreement, the Company assigned, sold, and conveyed certain non-operated assets in the Williston Basin, North Dakota in consideration for the elimination of $4.0 million in outstanding liabilities to StatOil and payment by Statoil to the Company of $2.0 million in cash. U.S. Energy has historically accounted for the eliminated liabilities on the Company’s balance sheet under “Payable to major operator” and “Contingent ownership interests.” The Purchase Agreement was unanimously approved by the board of directors of the Company and closed on October 5, 2017, with an effective date of August 1, 2017. A gain/loss calculation must be performed on any transaction which impacts reserves greater than 25%.The gain/loss calculation first identifies the total consideration received, followed by a fair market valuation regarding the amount of reserves sold versus the Company’s remaining reserves. The purpose of the fair market valuation is to proportionately bifurcate the considerations received between the refunding of historical capitalized costs and the gain/loss calculation on the asset sale. As a result of this analysis, the Company recorded a gain of $4.3 million relate to the divestiture. Ceiling Test and Impairment The reserves used in the Ceiling Test incorporate assumptions regarding pricing and discount rates over which management has no influence in the determination of present value. In the calculation of the Ceiling Test for the year ended December 31, 2017, the Company used $51.34 per barrel for oil and $2.976 per MMbtu for natural gas (as further adjusted for property specific gravity, quality, local markets and distance from markets) to compute the future cash flows of the Company’s producing properties. The discount factor used was 10%. For the years ended December 31, 2017, 2016, and 2015 impairment of the Company’s oil and gas properties amounted to $0.0 million, $9.6 million and $57.7 million, respectively. These impairment charges were primarily due to a decline in the price of oil, additional capitalized well costs and changes in production. Recent declines in the price of oil have significantly increased the risk of Ceiling Test write-downs in future periods. Capitalized Costs The following table presents the Company’s capitalized costs associated with oil and gas producing activities as of December 31, 2017 and 2016: 2017 2016 Oil and Gas Properties Unevaluated properties: Unproved leasehold costs $ 4,664 $ 4,664 Exploratory wells in progress - - Evaluated properties in full cost pool 86,313 87,834 Less accumulated depreciation, depletion and amortization (83,362 ) (82,640 ) Net capitalized costs $ 7,615 $ 9,858 The Company’s depreciation, depletion and amortization per equivalent BOE was $3.86 for 2017, $11.93 for 2016, and $26.80 for 2015. Unevaluated Oil and Gas Properties Unevaluated oil and gas properties consist of leasehold costs and exploratory wells in progress which are excluded from the DD&A calculation and the Ceiling Test until a determination about the existence of proved reserves can be completed. As of December 31, 2017 and 2016, unevaluated oil and gas properties consisted solely of unproved lease acquisition costs of $4.7 million. On a quarterly basis, management reviews market conditions and other changes in circumstances related to the Company’s unevaluated properties and transfers the costs to evaluated properties within the full cost pool as warranted. Results of Operations Presented below are the results of operations from oil and gas producing activities for the years ended December 31, 2017, 2016 and 2015: 2017 2016 2015 Oil and gas sales $ 6,545 $ 5,746 $ 10,296 Production costs (3,402 ) (2,728 ) (7,352 ) Depreciation, depletion and amortization (753 ) (2,529 ) (8,412 ) Impairment of oil and gas properties - (9,568 ) (57,676 ) Results of operations from oil and gas producing activities $ 2,390 $ (9,079 ) $ (63,144 )

Property and Equipment, Net

Property and Equipment, Net	12 Months Ended
	Dec. 31, 2017
Property, Plant and Equipment [Abstract]
Property and Equipment, Net	5. PROPERTY AND EQUIPMENT, NET Property and equipment consists of the following as of December 31, 2017 and 2016: 2017 2016 Real estate: Land $ 380 $ 380 Buildings 4,012 4,012 Land improvements 641 641 Administrative assets: Computers and software 368 368 Office furniture and equipment 222 222 Vehicles and other 11 51 Total 5,634 5,674 Less accumulated depreciation (3,917 ) (3,810 ) Property and equipment, net $ 1,717 $ 1,864 Depreciation expense related to real estate and administrative assets amounted to $0.1 million respectively for the years ended December 31, 2017, 2016 and 2015, respectively.

Discontinued Operations

Discontinued Operations	12 Months Ended
	Dec. 31, 2017
Discontinued Operations and Disposal Groups [Abstract]
Discontinued Operations	6. DISCONTINUED OPERATIONS Disposition of Mining Segment In February 2006, the Company reacquired the Mt. Emmons molybdenum mining properties (the “Property”). The Company has not conducted any extractive mining operations at the Property since its re-acquisition but the Company was obligated under existing permits to operate a water treatment plant (“WTP”) and to incur holding costs associated with the retention of the mining properties, which resulted in aggregate annual expenses of approximately $3,000 during each of the three years in the period ended December 31, 2015. The market price for molybdenum oxide was approximately $11 per pound during 2013 and 2014 with a decrease to approximately $5 per pound by the fourth quarter of 2015. In light of the considerable ongoing costs related to the Property and the deteriorating market for molybdenum, during 2015 the Company began to explore the viability of alternative structures to the development of the Property that could result in a sharing or elimination of the ongoing costs and liabilities. In February 2016, the Company’s Board of Directors decided to dispose of the Property rather than continuing the Company’s long-term development strategy whereby the Company entered into the following agreements: A. The Company entered into an Acquisition Agreement (the “Acquisition Agreement”) with Mt. Emmons Mining Company, a subsidiary of Freeport-McMoRan Inc. (“MEM”), whereby MEM acquired the Property which consists of the Mt. Emmons mine site located in Gunnison County, Colorado, including the Keystone Mine, the WTP and other related properties. Under the Acquisition Agreement, MEM replaced the Company as the permittee and operator of the WTP and will discharge the obligation of the Company to operate the WTP from and after the closing in accordance with the applicable permits issued by the Colorado Department of Public Health and Environment. The Company did not receive any cash consideration for the disposition; the sole consideration for the transfer was that MEM assumed the Company’s obligations to operate the WTP and to pay the future mine holding costs for portions of the Property that it desires to retain. As a result of the subsequent disposition of the Property as described above, the Company determined that an impairment charge of $22.6 million was required to be recorded in the fourth quarter of 2015. Presented below is calculation of the impairment charge: Net book value of assets conveyed $ 22,824 Asset retirement obligations assumed by Purchaser (204 ) Impairment charge recognized in 2015 $ 22,620 Under U.S. GAAP, the disposal of a segment is reported as discontinued operations in the Company’s financial statements. Presented below are the assets and liabilities associated with the Company’s mining segment as of December 31, 2017 and 2016, along with the impact of the impairment charge: 2017 2016 Assets retained by the Company: Performance bonds $ 114 $ 114 Net assets conveyed to Purchaser: Undeveloped mining claims - - Mining equipment - - Less accumulated depreciation of mining equipment - - Less write-down due to impairment - - Net book value of assets conveyed - - Total assets of discontinued operations $ 114 $ 114 Asset retirement obligations assumed by Purchaser $ - B. Concurrent with entry into the Acquisition Agreement and as additional consideration for MEM to accept transfer of the Property, the Company entered into a Series A Convertible Preferred Stock Purchase Agreement (the “Series A Purchase Agreement”) with MEM, whereby the Company issued 50,000 shares of newly designated Series A Convertible Preferred Stock (the “Preferred Stock”) in exchange for (i) MEM accepting the transfer of the Property and replacing the Company as the permittee and operator of the WTP, and (ii) the payment of $1 to the Company. The Series A Purchase Agreement contains customary representations and warranties on the part of the Company. As contemplated by the Acquisition Agreement and the Series A Purchase Agreement and as approved by the Company’s Board of Directors, the Company filed with the Secretary of State of the State of Wyoming Articles of Amendment containing a Certificate of Designations with respect to the Preferred Stock (the “Certificate of Designations”). Pursuant to the Certificate of Designations, the Company designated 50,000 shares of its authorized preferred stock as Series A Convertible Preferred Stock. The Preferred Stock accrues dividends at a rate of 12.25% per annum of the Adjusted Liquidation Preference (as defined below); such dividends are not payable in cash but are accrued and compounded quarterly in arrears. The “Adjusted Liquidation Preference” is initially $40 per share of Preferred Stock for an aggregate of $2,000, with increases each quarter by the accrued quarterly dividend. The Preferred Stock is senior to other classes or series of shares of the Company with respect to dividend rights and rights upon liquidation. No dividend or distribution will be declared or paid on junior stock, including the Company’s common stock, (1) unless approved by the holders of Preferred Stock and (2) unless and until a like dividend has been declared and paid on the Preferred Stock on an as-converted basis. At the option of the holder, each share of Preferred Stock may initially be converted into 13.33 shares of the Company’s $0.01 par value Common Stock (the “Conversion Rate”) for an aggregate of 666,667 shares. The Conversion Rate is subject to anti-dilution adjustments for stock splits, stock dividends and certain reorganization events and to price-based anti-dilution protections. Each share of Preferred Stock will be convertible into a number of shares of Common Stock equal to the ratio of the initial conversion value to the conversion value as adjusted for accumulated dividends multiplied by the Conversion Rate. In no event will the aggregate number of shares of Common Stock issued upon conversion be greater than 793,000 shares. The Preferred Stock will generally not vote with the Company’s Common Stock on an as-converted basis on matters put before the Company’s shareholders. The holders of the Preferred Stock have the right to approve specified matters as set forth in the Certificate of Designations and have the right to require the Company to repurchase the Preferred Stock in connection with a change of control. During the first quarter of 2016, the Company recorded the fair value of the Preferred Stock based on the initial liquidation preference of $2,000. Since the cash consideration paid by MEM for the Preferred Stock was a nominal amount, the Company recorded a charge to operations of approximately $2,000 associated with the issuance. C. Concurrent with entry into the Acquisition Agreement and the Series A Purchase Agreement, the Company and MEM entered into an Investor Rights Agreement, which provides MEM rights to certain information and Board observer rights. MEM has agreed that it, along with its affiliates, will not acquire more than 16.86% of the Company’s issued and outstanding shares of Common Stock. In addition, MEM has the right to demand registration of the shares of Common Stock issuable upon conversion of the Preferred Stock under the Securities Act of 1933, as amended. Combined Results of Operations for Discontinued Operations The results of operations of the discontinued mining operations are presented separately for all periods presented in the accompanying financial statements. Presented below are the components for the years ended December 31, 2017, 2016 and 2015: 2017 2016 2015 Operating results for apartment complex: Rental revenue $ - $ - $ - Operating expenses - - - Net earnings for apartment complex - - - Operating expenses of mining segment: Water treatment plant - (254 ) (1,737 ) Mine property holding costs - (2,194 ) (1,133 ) Impairment of mining asset - - (22,620 ) Depreciation of mine equipment - - (122 ) Total expenses for mining segment - (2,448 ) (25,612 ) Total results for discontinued operations $ - $ (2,448 ) $ (25,612 )

Debt

Debt	12 Months Ended
	Dec. 31, 2017
Debt Disclosure [Abstract]
Debt	7. DEBT Energy One, a wholly-owned subsidiary the Company, has a Credit Facility with APEG Energy II, L.P. (“APEG”). As of December 31, 2017 and 2016, outstanding borrowings under the Credit Facility amounted to $1.5 million and $6.0 million, respectively. On May 2, 2017 the Amended and Restated Credit Agreement was sold, assigned and transferred between Wells Fargo Bank N.A. to APEG. U.S. Energy Corp., Energy One and APEG entered into a Limited Forbearance Agreement dated May 2, 2017. On June 28, 2017, U.S. Energy Corp., Energy One and APEG entered into a Fifth Amendment to the Credit Facility providing for, among other things, an extension of the maturity date to July 30, 2019, new financial coverage ratio covenants and a waiver with respect to any historical Company non-compliance with any and all financial covenants. As of December 31, 2017 and 2016, the borrowing base was $6.0 million. Borrowings under the Credit Facility are secured by Energy One’s oil and gas producing properties and substantially all of the Company’s cash and equivalents. Each borrowing under the agreement has a term of six months, but can be continued at the Company’s election through July 2019 if the Company remains in compliance with the covenants under the Credit Facility. The interest rate on the Credit Facility is currently fixed at 8.75%. Energy One is required to comply with customary affirmative covenants and with certain negative covenants. The principal negative financial covenants do not permit (as the following terms are defined in the Fifth Amendment) (i) Proved Developed Producing Coverage Ratio to be less than 1.2 to 1; and (ii) the current ratio to be less than 1.0 to 1.0. As of December 31, 2017, the Company is in compliance with all Credit Facility covenants. Additionally, the Credit Agreement prohibits or limits Energy One’s ability to incur additional debt, pay cash dividends and other restricted payments, sell assets, enter into transactions with affiliates, and to merge or consolidate with another company. The Company is a guarantor of Energy One’s obligations under the Credit Agreement. On December 27, 2017, U.S. Energy Corp. received shareholder approval for the exchange agreement (“Exchange Agreement”) by and among the Company, the Company’s wholly owned subsidiary Energy One LLC and APEG Energy II, L.P., (“APEG”), an entity controlled by Angelus Private Equity Group, LLC pursuant to which, on the terms and subject to the conditions of the Exchange Agreement, APEG exchanged $4,463,380 of outstanding borrowings under the Company’s Credit Facility, for 5,819,270 new shares of common stock of the Company, par value $0.01 per share, representing an exchange price of $0.767 representing a 1.3% premium over the 30-day volume weighted average price of the Company’s common stock on September 20, 2017 (the “Exchange Shares”). Accrued, unpaid interest on the Credit Facility held by APEG was paid in cash at the closing of the transaction. Following the close of the transaction, APEG holds approximately 49.3% of the outstanding Common Stock of U.S. Energy. The Transaction was approved by the Company’s shareholders and closed in the fourth quarter of 2017. Additionally, the transaction was recorded based on a $1.53 stock price which represented the Company’s stock price on the date of shareholder approval.

Executive Retirement and Severa

Executive Retirement and Severance	12 Months Ended
	Dec. 31, 2017
Retirement Benefits [Abstract]
Executive Retirement and Severance	8. EXECUTIVE RETIREMENT AND SEVERANCE In October 2005, the Board of Directors adopted an Executive Retirement Policy (the “Retirement Plan”) for the benefit of certain executive officers of the Company. To be eligible to participate in the Retirement Plan, the executive officer was required to serve as one of the designated executive officers for at least 15 years, reached the age of 60, and been an employee of the Company on December 31, 2010. Upon retirement, the executive was entitled to cash payments equaling 50% of the greater of (i) the amount of compensation earned as base cash pay on the final regular pay check or (ii) the average annual pay, less all bonuses, received over the last five years of employment with the Company. The Company periodically engaged the services of a third party actuary to determine the estimated liability under the Retirement Plan. Presented below is a summary of changes in the liability for the years ended December 31, 2017 and 2016: 2016 Balance, beginning of year $ 583 Adjustment to fair value - Payment of retirement benefits (583 ) Negotiated settlement at discount and other - Balance, end of year $ - The current portion of the Company’s liability under the Retirement Plan was fully settled in 2016. These amounts are included in accrued compensation and benefits in the accompanying consolidated balance sheets, and the remainder of the liability is included in other long-term liabilities. Total compensation expense under the Retirement Plan for the years ended December 31, 2017 and 2016 was $0 and $3, respectively. In order to fund the Retirement Plan obligation, the Company periodically made cash contributions to a separate trust account that was managed by an independent trustee. The trust account was invested in debt and equity securities until December 2015 when the trust was terminated and the investments were liquidated for cash in the amount of $1,271 which was included in cash and equivalents as of December 31, 2015. The Company and the Retirement Plan participants mutually agreed to terminate the Retirement Plan in December 2015, and all obligations were settled through cash payments during the first quarter of 2016.

Asset Retirement Obligations

Asset Retirement Obligations	12 Months Ended
	Dec. 31, 2017
Asset Retirement Obligation Disclosure [Abstract]
Asset Retirement Obligations	9. ASSET RETIREMENT OBLIGATIONS The following is a reconciliation of the changes in the Company’s liabilities for asset retirement obligations for the years ended December 31, 2017 and 2016: 2017 2016 Oil and Gas Mining Oil and Gas Mining Balance, beginning of year $ 1,045 $ - $ 1,038 $ 204 Accretion 32 - 33 - Sold/Plugged (167 ) - (26 ) (204 ) New drilled wells 3 - - - Liabilities incurred - - - - Balance, end of year $ 913 $ - $ 1,045 $ - As discussed further in Note 6, asset retirement obligations related to the Company’s mining segment are presented as discontinued operations in the accompanying balance sheets.

Commitments, Contingencies, and

Commitments, Contingencies, and Related Party Transactions	12 Months Ended
	Dec. 31, 2017
Commitments and Contingencies Disclosure [Abstract]
Commitments and Contingencies	10. COMMITMENTS, CONTINGENCIES, AND RELATED PARTY TRANSACTIONS Commitments Lessor Operating Leases. Related Party Payable. Contingencies From time to time, the Company is party to certain legal actions and claims arising in the ordinary course of business. While the outcome of these events cannot be predicted with certainty, management does not expect these matters to have a materially adverse effect on the Company’s financial position or results of operations. Following are currently pending legal matters, and matters that were settled in 2017: North Dakota Properties. On January 28, 2013, the District Court Northwest Judicial District issued an Order for Partial Summary Judgment holding that the State of North Dakota as part of its title to the beds of navigable waterways owns the minerals in the area between the ordinary high and low watermarks on these waterways, and that this public title excludes ownership and any proprietary interest by landowners. This issue has been appealed to the North Dakota Supreme Court. The Company’s legal position is aligned with Brigham, who will continue to provide legal counsel in this case for the benefit of all working interest owners. The Company’s interest in this case was assigned to Statoil as part of the October 2017 asset divestiture to Statoil. The Company is also a party to litigation that seeks to reform certain assignments of mineral interests it acquired from Brigham. This matter involves the depth below the surface to which the assignments were effective. The plaintiff is seeking to reform the agreement such that the Company’s assignment would be revised to be 12 feet closer to the surface. This dispute affects one of the Company’s producing wells. The matter was settled on July 7, 2017 with the court ruling in favor Brigham and therefore U.S. Energy will retain all interests in all subject leases. Quiet Title Actions. Arbitration of Employment Claim. Contingent Ownership Interests.

Shareholders' Equity

Shareholders' Equity	12 Months Ended
	Dec. 31, 2017
Stockholders' Equity Note [Abstract]
Shareholders' Equity	11. SHAREHOLDERS’ EQUITY Preferred Stock The Company’s articles of incorporation authorize the issuance of up to 100,000 shares of preferred stock, $0.01 par value. Shares of preferred stock may be issued with such dividend, liquidation, voting and conversion features as may be determined by the Board of Directors without shareholder approval. The Company is authorized to issue 50,000 shares of Series P preferred stock in connection with a shareholder rights plan that expired in 2011. As discussed in Note 6, in February 2016 the Board of Directors approved the designation of 50,000 shares of Series A Convertible Preferred Stock in connection with the disposition of the Company’s mining segment. Warrants On December 21, 2016, the Company completed a registered direct offering of 1,000,000 shares of common stock at a net gross price of $1.50 per share. Concurrently, the investors received warrants to purchase 1,000,000 shares of Common Stock of the Company at an exercise price of $2.05 per share, subject to adjustment, for a period of five years from closing. The total net proceeds received by the Company was approximately $1.32 million. The fair value of the warrants upon issuance was $1.24 million, with the remaining $0.08 million being attributed to common stock. The warrants contain a dilutive issuance and other liability provisions which cause the warrants to be accounted for as a liability. Such warrant instruments are initially recorded as a liability and are accounted for at fair value with changes in fair value reported in earnings. As of December 31, 2017 the Company had a warrant liability of $1.2 million. Stock Option Plans Employee Stock Option Plans. subsequently In June 2012 the Board of Directors adopted, and the shareholders subsequently approved, the U.S. Energy Corp. 2012 Equity and Performance Incentive Plan (the “2012 Equity Plan”). The 2012 Equity Plan, as amended and approved by shareholders in June 2015, and as further amended and approved by shareholders in July 2017, reserves for issuance to the Company’s employees and Directors a total of 1,533,333 shares of the Company’s common stock. The 2012 Equity Plan has a term of 10 years which expires in June 2022. As of December 31, 2017, options for a total of 292,350 shares are outstanding under the 2012 Equity Plan and expire on various dates through January 2025. Director and Advisory Board Members Option Plan. A summary of the combined activity in the 2001 ISOP, the 2012 Equity Plan, and the 2008 Director SOP for the years ended December 31, 2017, 2016 and 2015 is as follows: 2017 2016 2015 Shares Price (1) Shares Price (1) Shares Price (1) Outstanding, beginning of year 390,525 $ 20.64 390,525 $ 20.64 2,276,079 $ 3.78 Granted 170,000 1.00 - - 340,711 1.50 Forfeited - - - - - - Expired (170,838 ) 29.82 - - (273,768 ) 3.86 Exercised - - - - - - Outstanding, end of year 389,687 $ 8.05 390,525 $ 20.64 2,343,022 $ 3.44 Shares restated after 6 to 1 split 389,687 $ 8.05 390,525 $ 20.64 390,525 $ 20.64 Exercisable, end of year 274,132 $ 10.79 376,084 $ 20.79 2,194,022 $ 3.53 Shares restated after 6 to 1 split - $ - - $ - 365,693 $ 21.17 (1) Represents the weighted average price. No stock options were exercised during the years ended December 31, 2017, 2016, or 2015. The following table summarizes information for stock options outstanding and for stock options exercisable at December 31, 2017: Options Outstanding Options Exercisable Number Exercise Price Remaining Number Weighted of Range Weighted Contractual of Average Shares Low High Average Term (years) Shares Exercise Price 56,786 $ 9.00 $ 9.00 $ 9.00 7.0 51,231 $ 9.00 49,504 12.48 12.48 12.48 5.5 49,504 12.48 98,396 13.92 17.10 15.01 1.8 98,396 15.01 15,001 22.62 30.24 24.03 5.5 15,001 24.03 60,000 0.72 0.72 0.72 9.6 60,000 0.72 110,000 1.16 1.16 1.16 9.9 - - 389,687 $ 0.72 $ 30.24 $ 8.05 6.7 274,132 $ 10.79 In connection with severance agreements entered into with employees during 2015, an aggregate of 1,617,689 outstanding stock options would have expired upon termination of employment. However, the Company agreed to permit exercise until the original expiration dates specified in the option agreements. Accordingly, the Company determined the fair value of the options at the date of modification and recorded additional compensation expense which amounted to an aggregate of $0.1 million. For the years ended December 31, 2017, 2016 and 2015, total stock-based compensation expense associated with stock options, including the modification charge discussed above, was $0.3 million, $0.2 million, and $0.9 million, respectively. As of December 31, 2017, there was $0.1 million of unrecognized expense related to unvested stock options, which will be recognized as stock-based compensation expense through November 2019. In estimating the fair value of options, the Company used the Black-Scholes option-pricing model with the following weighted average assumptions: 2017 2016 Expected lives (in years) 10.0 - Risk-free interest rate 2.33 % - Expected volatility 80.0 % - Expected dividend yield 0.00 % - On September 23, 2016, the Board of Directors granted restricted stock to each member of the Board for 58,500 shares per Board member for an aggregate grant of 351,000 shares. In connection with the resignations of four members of the Company’s Board of Directors, the restricted stock grants were amended and the members of the Board of Directors subsequently agreed to accept 33,332 fully-vested shares each, in lieu of the 58,500 share grants for a net total of 199,992 shares. The closing price of the Company’s common stock on the grant date was $1.05, resulting in an aggregate compensation charge of $0.2 million. As of December 31, 2017, the Company had expensed the entire aggregate compensation charge over 2017 and there was $0 of unrecognized expense related to the September 23, 2016 grants. Employee Stock Ownership Plan The Board of Directors of the Company adopted the U.S. Energy Corp. 1989 Employee Stock Ownership Plan (“ESOP”) in 1989, for the benefit of all the Company’s employees. Employees were not eligible for ESOP contributions to the extent that their annual taxable compensation exceeded $0.3 million for 2015. In September 2016, the Company’s Board of Directors agreed to terminate the ESOP, which resulted in a distribution of the remaining shares held by the ESOP to the vested employees during the first quarter of 2017. For the year ended December 31, 2017, we did not incur any stock-based compensation expense related to the ESOP.

Income Taxes

Income Taxes	12 Months Ended
	Dec. 31, 2017
Income Tax Disclosure [Abstract]
Income Taxes	12. INCOME TAXES The Company incurred a net loss for each of the years ended December 31, 2017, 2016 and 2015, and the Company has recorded valuation allowances for its net deferred tax assets for each of those years. Accordingly, the Company has not recognized a benefit for income taxes in the accompanying financial statements. Income tax benefit using the Company’s effective income tax rate differs from the U.S. Federal Statutory income tax rate due to the following: 2017 2016 2015 Income tax benefit at federal statutory rate $ 472 $ 4,801 $ 31,585 State income tax benefit, net of federal impact 38 292 1,440 Change in Federal tax rate, net of state benefit (1) (5,440 ) Loss on debt to equity conversion (1,630 ) Effect of Sec. 382 Limitation (29,803 ) Incentive stock options and restricted stock not deductible for tax purposes 964 - (269 ) Percentage depletion carryover 138 19 - Prior year true up 1,076 534 171 Other 77 Decrease in valuation allowance (34,109 ) (5,646 ) (32,927 ) Income tax benefit (expense) $ - $ - $ - (1) The change in the Federal Tax rate was due to the passage of Public Law 115-97 (Tax Cuts and Jobs Act). This resulted in a provisional reduction of the Company’s deferred tax assets before valuation analysis primarily due to a reduction in the US Statutory rate from 35% to 21%. We will continue to analyze the Tax Cuts and Jobs Act and future associated Treasury Regulations. This future analysis could potentially affect the measurement of deferred tax balances and give rise to new deferred tax amounts. 2017 2016 Deferred tax assets: Net operating loss carryover (2) $ 874 $ 26,739 Property and equipment 7,123 14,575 Percentage depletion and contribution carryovers (2) 1,872 2,512 Alternative minimum tax credit carryover (2) 785 706 Equity method investment and other 398 547 Deferred compensation liability 8 12 Asset retirement obligations 221 377 Stock-based compensation 83 (44 ) Total deferred tax assets 11,364 45,424 Deferred tax liabilities: Property and equipment - - Oil price risk derivatives - - Other (3 ) (4 ) Total deferred tax liabilities (3 ) (4 ) Net deferred tax assets 11,361 45,420 Less valuation allowance (11,361 ) (45,420 ) Net deferred tax asset $ - $ - (2) On December 27, 2017, the Company paid down debt with common stock. This represented a 49.3% ownership change in the company. This combined with other equity events triggered Net Operation Loss limitations under I.R.C Section 382. As a result, the Company’s Net Operating Loss carryforwards were significantly limited. The Company has net operating loss carryovers (after limitations) as of December 31, 2017 of approximately $3,600,000 for federal income tax purposes. The net operating loss carryovers may be carried back two years and forward twenty years from the year the net operating loss was generated. The net operating losses may be used to offset future taxable income and expire in varying amounts through 2036. In addition, the Company has alternative minimum tax credit carry-forwards of approximately $785,000 (subject to limitations) which are available to offset future federal income taxes over an indefinite period. The statute of limitations is closed for the tax years through 2011. The Company recognizes, measures, and discloses uncertain tax positions whereby tax positions must meet a “more-likely-than-not” threshold to be recognized. During the years ended December 31, 2017, 2016 and 2015, no adjustments were recognized for uncertain tax positions.

Loss Per Share

Loss Per Share	12 Months Ended
	Dec. 31, 2017
Earnings Per Share [Abstract]
Loss Per Share	13. LOSS PER SHARE Basic loss per share is computed based on the weighted average number of common shares outstanding. The calculation of diluted loss per share adds dilutive stock options computed using the treasury stock method as follows: 2017 2016 2015 Basic weighted average common shares outstanding 5,899,802 4,768,013 4,677,500 Dilutive stock options using treasury stock method - - - Diluted weighted average common shares outstanding 5,899,802 4,768,013 4,677,500 For the years ended December 31, 2017, 2016 and 2015, common stock equivalents excluded from the calculation of weighted average shares because they were antidilutive are as follows: 2017 2016 2015 Stock options 389,687 390,525 390,525 Unvested shares of restricted common stock 5,555 24,832 16,667 Total 395,242 415,357 407,192

Significant Concentrations

Significant Concentrations	12 Months Ended
	Dec. 31, 2017
Risks and Uncertainties [Abstract]
Significant Concentrations	14. SIGNIFICANT CONCENTRATIONS The Company has exposure to credit risk in the event of nonpayment by the joint interest operators of the Company’s oil and gas properties. During the years ended December 31, 2017, 2016 and 2015, three joint interest operators accounted for the following percentages of the Company’s oil and gas sales: Operator 2017 2016 2015 A 13 % 16 % 20 % B 25 % 32 % 35 % C 34 % 29 % 25 % Substantially all of the Company’s cash and equivalents are in accounts with a single financial institution and the balances typically exceed federally insured limits. The Company has not experienced any losses in such accounts.

Fair Value Measurements

Fair Value Measurements	12 Months Ended
	Dec. 31, 2017
Fair Value Disclosures [Abstract]
Fair Value Measurements	15. FAIR VALUE MEASUREMENTS Fair value is the price that would be received to sell an asset or paid to transfer a liability in an orderly transaction between market participants at the measurement date. In determining fair value, the Company uses various methods including market, income and cost approaches. Based on these approaches, the Company often utilizes certain assumptions that market participants would use in pricing the asset or liability, including assumptions about risk and the risks inherent in the inputs to the valuation technique. These inputs can be readily observable, market corroborated, or generally unobservable inputs. The Company utilizes valuation techniques that maximize the use of observable inputs and minimize the use of unobservable inputs. Based on the observability of the inputs used in the valuation techniques the Company is required to provide the following information according to the fair value hierarchy. The fair value hierarchy ranks the quality and reliability of the information used to determine fair values. Financial assets and liabilities carried at fair value will be classified and disclosed in one of the following three categories: Level 1 - Quoted prices for identical assets and liabilities traded in active exchange markets, such as the New York Stock Exchange. Level 2 - Observable inputs other than Level 1 including quoted prices for similar assets or liabilities, quoted prices in less active markets, or other observable inputs that can be corroborated by observable market data. Level 2 also includes derivative contracts whose value is determined using a pricing model with observable market inputs or can be derived principally from or corroborated by observable market data. Level 3 - Unobservable inputs supported by little or no market activity for financial instruments whose value is determined using pricing models, discounted cash flow methodologies, or similar techniques, as well as instruments for which the determination of fair value requires significant management judgment or estimation; also includes observable inputs for nonbinding single dealer quotes not corroborated by observable market data. The Company has processes and controls in place to attempt to ensure that fair value is reasonably estimated. The Company performs due diligence procedures over third-party pricing service providers in order to support their use in the valuation process. Where market information is not available to support internal valuations, independent reviews of the valuations are performed and any material exposures are evaluated through a management review process. While the Company believes its valuation methods are appropriate and consistent with other market participants, the use of different methodologies or assumptions to determine the fair value of certain financial instruments could result in a different estimate of fair value at the reporting date. The following is a description of the valuation methodologies used for complex financial instruments measured at fair value: Oil Price Risk Derivative Valuation Methodologies The Company determines its estimate of the fair value of derivative instruments using a market approach based on several factors, including quoted market prices in active markets, quotes from third parties, the credit rating of the counterparty and the Company’s own credit rating. In consideration of counterparty credit risk, the Company assessed the likelihood that the counterparty to the derivative would default by failing to make any contractually required payments. Additionally, the Company considers that it is of adequate credit quality and has the financial resources and willingness to meet its potential repayment obligations associated with the derivative transactions. The crude oil derivative markets are highly active. Although the Company’s derivative instruments are valued using indices, the instruments themselves are traded with third-party counterparties and are not openly traded on an exchange. As such, the Company has classified these instruments as Level 2. Warrant Valuation Methodologies The warrants contain a dilutive issuance and other liability provisions which cause the warrants to be accounted for as a liability. Such warrant instruments are initially recorded and valued as a level 3 liability and are accounted for at fair value with changes in fair value reported in earnings. The Company estimated the value of the warrants on December 31, 2016 using the Monte Carlo model with the following assumptions: a term expiring June 21, 2022, exercise price of $2.05, volatility rate of 90%, and a risk-free interest rate of 2.01%. The Company remeasured the warrants as of December 31, 2017, using the same Monte Carlo model, using the following assumptions: a term expiring June 21, 2022, exercise price of $2.05, stock price of $1.50, average volatility rate of 90%, and a risk-free interest rate of 2.15%. As of December 31, 2017, the fair value of the warrants was $1,200,000, or $1.20 per warrant, and was recorded as a liability on the accompanying consolidated balance sheets. An increase in any of the variables would cause an increase in the fair value of the warrants. Likewise, a decrease in any variable would cause a decrease in the value of the warrants. Marketable Equity Securities Valuation Methodologies The fair value of available for sale securities is based on quoted market prices obtained from independent pricing services. Accordingly, the Company has classified these instruments as Level 1. Other Financial Instruments The carrying amount of cash and equivalents, oil and gas sales receivable, other current assets, accounts payable and accrued expenses approximate fair value because of the short-term nature of those instruments. The recorded amounts for the Credit Facility discussed in Note 7 approximates the fair market value due to the variable nature of the interest rates, and the fact that market interest rates have remained substantially the same since the latest amendment to the Credit Facility. Recurring Fair Value Measurements Recurring measurements of the fair value of assets and liabilities as of December 31, 2017 and 2016 are as follows: December 31, 2017 December 31, 2016 Level 1 Level 2 Level 3 Total Level 1 Level 2 Level 3 Total Marketable equity securitites: Sutter Gold Mining Company $ - $ 8 $ - $ 8 $ - $ 16 $ - $ 16 Anfield Resources, Inc. 868 - - 868 930 - - 930 Total $ 868 $ 8 $ - $ 876 $ 930 $ 16 $ - $ 946 Outstanding warrant liability - - 1,200 1,200 - - 1,030 1,030 Crude oil price risk derivatives - 161 - 161 - - - - Total $ - $ 161 $ 1,200 $ 1,361 $ - $ - $ 1,030 $ 1,030 The following table presents a reconciliation of changes in assets and liabilities measured at fair value on a recurring basis for the years ended December 31, 2017 and 2016: Assets Liabilities Marketable Securities Crude Oil Crude Oil Executive Sutter Anfield Derivatives Derivatives Retirement Warrants (Level 2) (Level 1) (Level 2) (Level 2) (Level 3) (Level 3) Net Fair value, December 31, 2015 13 238 1,634 - (583 ) - 1,302 Acquisition of investment - 750 - - - - 750 Issuance of warrants - - - - - 1,240 1,240 Other comprehensive loss 3 - - - - - 3 Fair value adjustments included in net loss: - Net unrealized gain on warrant valuation - - - - - (210 ) (210 ) Net unrealized loss on Anfield Shares - (58 ) - - - - (58 ) Offset of derivative assets and liabilities - - (194 ) - - - (194 ) Cash settlements paid - - (1,440 ) - 583 - (857 ) Fair value, December 31, 2016 $ 16 $ 930 $ - - $ - $ 1,030 $ 1,976 Total net losses included in: Acquisition of investment - 777 - - - - 777 Other comprehensive loss (8 ) - - - - - (8 ) Fair value adjustments included in net loss: - Net unrealized loss on oil price risk derivatives - - - (26 ) - - (26 ) Net unrealized loss on warrant valuation - - - - - 170 170 Net unrealized loss on Anfield Shares - (839 ) - - - - (839 ) Cash settlements paid - - - (135 ) - - (135 ) - Fair value, December 31, 2017 $ 8 $ 868 $ - (161 ) $ - $ 1,200 $ 1,915

Unaudited Supplemental Oil and

Unaudited Supplemental Oil and Gas Information	12 Months Ended
	Dec. 31, 2017
Oil and Gas Exploration and Production Industries Disclosures [Abstract]
Unaudited Supplemental Oil and Gas Information	16. UNAUDITED SUPPLEMENTAL OIL AND GAS INFORMATION Oil and Gas Reserves (Unaudited) Proved reserves are estimated quantities of oil, NGLs and natural gas which geological and engineering data demonstrate with reasonable certainty to be recoverable in future years from known reservoirs under existing economic and operating conditions. Oil and gas prices used are the average price during the 12-month period prior to the effective date of the report, determined as an unweighted arithmetic average of the first-day-of-the-month price for each month within such period, unless prices are defined by contractual arrangements. Proved developed reserves are reserves that can reasonably be expected to be recovered through existing wells with existing equipment and operating methods. The Company emphasizes that reserve estimates are inherently imprecise and that estimates of new discoveries and undeveloped locations are more imprecise than estimates of established producing oil and gas properties. Accordingly, these estimates are expected to change as future information becomes available. Proved oil and gas reserve quantities at December 31, 2017, 2016 and 2015 and the related discounted future net cash flows before income taxes are based on the estimates prepared by Jane E. Trusty, PE. Such estimates have been prepared in accordance with guidelines established by the Securities and Exchange Commission. All of the Company’s estimated proved reserves are located in the United States. The Company’s estimated quantities of proved oil and gas reserves and changes in net proved reserves are summarized below for the years ended December 31, 2017, 2016 and 2015: 2017 2016 2015 Oil Gas Oil Gas Oil Gas (bbls) (mcfe) (1) (bbls) (mcfe) (1) (bbls) (mcfe) (1) Total proved reserves: Reserve quantities, beginning of year 657,280 1,379,163 1,615,180 2,477,930 4,119,736 3,211,245 Revisions of previous estimates 302,530 55,072 (795,459 ) (584,494 ) (2,377,364 ) (206,912 ) Discoveries and extensions 22,801 21,787 23,841 20,336 94,458 27,102 Sale of minerals in place (194,667 ) (118,944 ) (53,853 ) (57,258 ) - - Production (111,914 ) (448,571 ) (132,429 ) (477,351 ) (221,650 ) (553,505 ) Reserve quantities, end of year 676,030 888,507 657,280 1,379,163 1,615,180 2,477,930 Proved developed reserves, end of year 676,030 888,507 657,280 1,379,163 1,248,750 2,068,190 (1) Mcf equivalents (Mcfe) consist of natural gas reserves in mcf plus NGLs converted to mcf using a factor of 6 mcf for each barrel of NGL. Standardized Measure (Unaudited) The Company computes a standardized measure of future net cash flows and changes therein relating to estimated proved reserves in accordance with authoritative accounting guidance. The assumptions used to compute the standardized measure are those prescribed by the FASB and the SEC. These assumptions do not necessarily reflect the Company’s expectations of actual revenues to be derived from those reserves, nor their present value amount. The limitations inherent in the reserve quantity estimation process, as discussed previously, are equally applicable to the standardized measure computations since these reserve quantity estimates are the basis for the valuation process. Future cash inflows and production and development costs are determined by applying prices and costs, including transportation, quality, and basis differentials, to the year-end estimated future reserve quantities. The following prices as adjusted for transportation, quality, and basis differentials were used in the calculation of the standardized measure: 2017 2016 2015 Oil per Bbl $ 51.34 $ 42.75 $ 43.54 Gas per Mcfe (1) $ 2.98 $ 2.48 $ 3.36 (1) Consists of the weighted average price for natural gas in mcf plus NGL’s converted to mcf using a factor of 6 mcf for each barrel of NGL. Future operating costs are determined based on estimates of expenditures to be incurred in developing and producing the proved reserves in place at the end of the period using year-end costs and assuming continuation of existing economic conditions. Estimated future income taxes are computed using the current statutory income tax rates, including consideration for estimated future statutory depletion. The resulting future net cash flows are reduced to present value amounts by applying a 10 percent annual discount factor. The standardized measure of discounted future net cash flows relating to the Company’s proved oil and gas reserves is as follows as of December 31, 2017, 2016 and 2015: 2017 2016 2015 Future cash inflows $ 34,424 $ 27,769 $ 78,646 Future cash outflows: Production costs (18,518 ) (18,814 ) (44,685 ) Development costs - - (8,050 ) Income taxes - - - Future net cash flows 15,906 8,955 25,911 10% annual discount factor (6,653 ) (2,208 ) (8,143 ) Standardized measure of discounted future net cash flows $ 9,253 $ 6,747 $ 17,768 Changes in Standardized Measure (Unaudited) The changes in the standardized measure of future net cash flows relating to proved oil and gas reserves for the years ended December 31, 2017, 2016 and 2015 are as follows: 2017 2016 2015 Standardized measure, beginning of year $ 6,747 $ 17,768 $ 81,889 Sales of oil and gas, net of production costs (3,143 ) (3,102 ) (2,944 ) Net changes in prices and production costs 2,347 (9,248 ) (96,586 ) Changes in estimated future development costs - 6,590 51,998 Extensions and discoveries 511 167 2,260 Sale of minerals in place (1,049 ) (78 ) - Revisions in previous quantity estimates 3,416 (6,791 ) (27,693 ) Previously estimated development costs incurred - - - Net changes in income taxes - - 3,306 Accretion of discount 675 1,777 8,189 Changes in timing and other (251 ) (336 ) (2,651 ) Standardized measure, end of year $ 9,253 $ 6,747 $ 17,768

Quarterly Financial Data (Unaud

Quarterly Financial Data (Unaudited)	12 Months Ended
	Dec. 31, 2017
Quarterly Financial Information Disclosure [Abstract]
Quarterly Financial Data (Unaudited)	17. QUARTERLY FINANCIAL DATA (Unaudited) The Company’s quarterly financial information for the two-year period ended December 31, 2017 is as follows: Year Ended December 31, 2016 Year Ended December 31, 2017 First Second Third Fourth First Second Third Fourth Quarter Quarter Quarter Quarter Quarter Quarter Quarter Quarter Oil and gas sales $ 1,066 $ 1,996 $ 1,867 $ 817 $ 1,747 $ 1,992 $ 1,538 $ 1,268 Operating expenses: - Impairment of oil and gas properties (6,957 ) (2,611 ) - - - - - - Other (1) (2,561 ) (3,061 ) (2,761 ) 276 (2,485 ) (1,996 ) (1,601 ) (1,451 ) Operating income (loss) (1) $ (8,452 ) $ (3,676 ) $ (894 ) $ 1,093 $ (738 ) $ (4 ) $ (63 ) $ (183 ) Income (loss) from continuing operations (1) $ (8,275 ) $ (4,206 ) $ (265 ) $ 1,074 $ (740 ) $ (336 ) $ (382 ) $ 98 Discontinued operations (2,327 ) (10 ) - (111 ) - - - - Net income (loss) $ (10,602 ) $ (4,216 ) $ (265 ) $ 963 $ (740 ) $ (336 ) $ (382 ) $ 983 Income (loss) per share - basic (1)(2) Continuing operations $ (1.76 ) $ (0.90 ) $ (0.06 ) $ 0.23 $ (0.13 ) $ (0.02 ) $ (0.06 ) $ 0.02 Discontinued operations (0.49 ) (0.00 ) - - - - - - Total $ (2.25 ) $ (0.90 ) $ (0.06 ) $ 0.23 $ (0.13 ) $ (0.02 ) $ (0.06 ) $ 0.02 Income (loss) per share - diluted (1)(2) Continuing operations $ (1.76 ) $ (0.90 ) $ (0.06 ) $ 0.23 $ (0.13 ) $ (0.02 ) $ (0.06 ) $ 0.02 Discontinued operations (0.49 ) (0.00 ) - - - - - - Total $ (2.25 ) $ (0.90 ) $ (0.06 ) $ 0.23 $ (0.13 ) $ (0.02 ) $ (0.06 ) $ 0.02 Weighted average shares outstanding: Basic 4,705,500 4,705,000 4,768,000 4,768,013 5,834,568 5,834,568 5,834,568 5,899,802 Diluted (1) 4,705,500 4,705,000 4,768,000 4,768,013 5,834,568 6,626,344 5,834,568 5,899,802 (1) Amounts have been restated from amounts reported in previous reports to retroactively present the impact of Discontinued Operations as discussed further in Note 6. (2) Earnings per share amounts may not sum due to rounding. The Company’s quarterly reserve reports are prepared based on a trailing 12-month average for benchmark oil and gas prices. The weighted average oil price used to prepare reserve estimates and to calculate the Full Cost Ceiling limitation for the first quarter of 2018 is expected to increase. Assuming other variables remain substantially unchanged, the Company does not expect to record an impairment charge during the first quarter of 2018.

Subsequent Events

Subsequent Events	12 Months Ended
	Dec. 31, 2017
Subsequent Events [Abstract]
Subsequent Events	18. SUBSEQUENT EVENTS On January 5, 2018 the Company entered into a common stock sales agreement with a financial institution pursuant to which we may sell from time to time, at our option, through the sales agent, shares of common stock representing an aggregate offering price of up to $2.5 million. Sales of the shares, if any, will be made in transactions that are deemed to be “at the market offerings” as defined in Rule 415 under the Securities Act of 1933, as amended.

Organization, Operations and 25

Organization, Operations and Significant Accounting Policies (Policies)	12 Months Ended
	Dec. 31, 2017
Accounting Policies [Abstract]
Organization and Operations	Organization and Operations U.S. Energy Corp. (collectively with its subsidiaries Energy One LLC, Highlands Ranch LLC, and Remington Village, LLC referred to as the “Company”) was incorporated in the State of Wyoming on January 26, 1966. The Company’s principal business activities are focused in the acquisition, exploration and development of oil and gas properties in the United States.
Use of Estimates	Use of Estimates The preparation of financial statements in conformity with generally accepted accounting principles in the United States (“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 that are used in the calculation of depreciation, depletion, amortization and impairment of the carrying value of evaluated oil and gas properties; production and commodity price estimates used to record accrued oil and gas sales receivable; valuation of commodity derivative instruments; the impact of commodity prices and other events affecting impairment of mining properties; and the cost of future asset retirement obligations. The Company evaluates its estimates on an on-going basis and bases its estimates on historical experience and on various other assumptions the Company believes to be reasonable. 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	Principles of Consolidation The accompanying financial statements include the accounts of the Company and its wholly-owned subsidiary Energy One LLC (“Energy One”). All inter-company balances and transactions have been eliminated in consolidation. Certain prior period amounts have been reclassified to conform to the current period presentation of the accompanying financial statements.
Cash and Equivalents	Cash and Equivalents The Company considers all highly liquid investments with original maturities of three months or less to be cash equivalents.
Oil and Gas Sales Receivable	Oil and Gas Sales Receivable The Company’s accounts receivable consists primarily of receivables from joint interest operators for the Company’s share of oil, gas, and natural gas liquids (“NGLs”). Generally, the Company’s oil and gas sales receivables are collected within three months and the Company has had minimal bad debts. Collectability is dependent upon the financial wherewithal of the joint interest operators and is influenced by the general economic conditions of the industry. Receivables are not collateralized. As of December 31, 2017 and 2016, the Company had not provided for an allowance for doubtful accounts.
Marketable Equity Securities	Marketable Equity Securities The Company categorizes its marketable equity securities as available-for-sale. Accordingly, increases or decreases in the fair value are generally presumed to be temporary and are recorded as a component of shareholders’ equity within comprehensive income or loss. The Company periodically evaluates if cumulative losses are indicative of other than temporary impairment whereby a loss is recognized when management determines that the value is unlikely to recover to the Company’s cost basis. Gains or losses from sales are recorded in operations when realized.
Oil and Gas Properties	Oil and Gas Properties The Company follows the full cost method of 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 are subject to depreciation, depletion and amortization (“DD&A”) using the equivalent unit-of-production method, based on total proved oil and gas reserves. For financial statement presentation, DD&A includes accretion expense related to asset retirement obligations. Excluded from amounts subject to DD&A are costs associated with unevaluated properties, including exploratory wells in progress. Under the full cost method, net capitalized costs are limited to the lower of unamortized cost reduced by the related net deferred tax liability, or the cost center ceiling (the “Ceiling Test”). 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 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 the Company’s oil and gas revenue and asset retirement obligations, (ii) the cost of unevaluated 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 gas properties. If the net book value reduced by the related net deferred income tax liability (if any) 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. Since all of the Company’s oil and gas properties are located within the United States, the Company only has one cost center for which a quarterly Ceiling Test is performed.
Property and Equipment	Property 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 as follows: Years Real estate: Buildings 20 to 45 Building improvements 10 to 25 Land improvements 10 to 35 Administrative assets: Computers and software 3 to 10 Office furniture and equipment 5 to 20 Vehicles and other 5
Discontinued Operations- Mining Properties	Discontinued Operations- Mining Properties Effective January 1, 2015, the Company adopted new accounting guidance related to the recognition and presentation of discontinued operations in its financial statements. Under the revised guidance, beginning in 2015 only disposals of businesses that represent strategic shifts that have a major effect on an organization’s operations and financial results will be reported in discontinued operations. Accordingly, as discussed in Note 6, the Company’s disposal of its mining segment qualified for reporting as discontinued operations in the accompanying financial statements. The Company capitalized all costs incidental to the acquisition of mining properties. Mining equipment was depreciated using the straight-line method over estimated useful lives that ranged from 10 to 20 years. Costs of operating a related water treatment plant on the mine property, holding costs to maintain permits, mining exploration costs and general corporate overhead were expensed as incurred. Capitalized costs were charged to operations to the extent it was subsequently determined that the mine property were not economic due to permanent decreases in market prices of commodities, excessive production costs, depletion of the mineral resource, or other factors.
Impairment of Long-Lived Assets	Impairment of Long-Lived Assets The Company evaluates long-lived assets for impairment when events or changes in circumstances indicate that the related carrying amount may not be recoverable. If estimated future cash flows, on an undiscounted basis, are less than the carrying amount of the related asset, an asset impairment charge is recognized, and measured as the amount by which the carrying value exceeds the estimated fair value. Changes in significant assumptions underlying future cash flow estimates may have a material effect on the Company’s financial position and results of operations. Long-lived assets are classified as held for sale when the Company commits to a plan to sell the assets. Such assets are classified within current assets if 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.
Derivative Instruments	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 the Company’s 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 the Company’s consolidated statements of operations. The Company may also use puts, calls and basis swaps in the future.
Warrant Liability	Warrant Liability From time to time we may have financial instruments such as warrants that may be classified as liabilities when either (a) the holders possess rights to net cash settlement, (b) physical or net equity settlement is not in our control, or (c) the instruments contain other provisions that causes us to conclude that they are not indexed to our equity. Such instruments are initially recorded at fair value and subsequently adjusted to fair value at the end of each reporting period through earnings. Accordingly, warrants are accounted for as a liability. This warrant liability is accounted for at fair value with changes in fair value reported in earnings.
Asset Retirement Obligations	Asset Retirement Obligations The Company records the estimated fair value of restoration and reclamation liabilities related to its oil and gas properties and its inactive mining properties as of the date that the liability is incurred. The Company reviews the liability each quarter and determines if a change in estimate is required, and accretion of the discounted liability is recorded based on the passage of time. Final determinations are made during the fourth quarter of each year. The Company deducts any actual funds expended for restoration and reclamation during the quarter in which it occurs.
Revenue Recognition	Revenue Recognition The Company derives revenue primarily from the sale of produced oil, natural gas, and NGLs. In the accompanying statements of operations, revenue from gas includes sales of both natural 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 lease operating expense in the accompanying statements of operations. The Company records oil and gas revenue under the sales method of accounting. Gas balancing obligations as of December 31, 2017, 2016, and 2015 were not significant. Revenue is recorded in the month that the production is delivered to the purchaser. At the end of each month, the Company estimates the amount of production delivered to the purchaser and the price the Company will receive. The Company uses its knowledge of its properties, their historical performance, market prices, and other factors as the basis for these estimates. 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	Stock-Based Compensation The Company 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. The Company computes the fair values of its options granted to employees using the Black Scholes pricing model. The Company 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. For awards granted which contain a graded vesting schedule, and the only condition for vesting is a service condition, compensation cost is recognized as an expense on a straight-line basis over the requisite service period as if the award was, in substance, a single award. Stock-based compensation expense is recognized based on awards ultimately expected to vest whereby estimates of forfeitures are based upon historical experience.
Income Taxes	Income Taxes The Company 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, the Company 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, 2017 and 2016, management believed it was more likely than not that such tax benefits would not be realized and a valuation allowance has been provided. The Company would recognize any interest and penalties related to uncertain tax positions as a component of income tax expense.
Earnings Per Share	Earnings Per Share Basic net income (loss) per share is computed based on the weighted average number of common shares outstanding. 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.
Recent Accounting Pronouncements	Recent Accounting Pronouncements Revenue recognition. Financial instruments. Recognition and Measurement of Financial Assets and Financial Liabilities Leases. Leases Statement of cash flows. Statement of Cash Flows Business combinations. Clarifying the Definition of a Business Stock-based compensation. Scope of Modification Accounting Hedging activities Financial instruments with characteristics of liabilities and equity.

Organization, Operations and 26

Organization, Operations and Significant Accounting Policies (Tables)	12 Months Ended
	Dec. 31, 2017
Organization, Consolidation and Presentation of Financial Statements [Abstract]
Schedule of Property and Equipment Useful Life	Depreciation of buildings, improvements, machinery and equipment is provided principally by the straight-line method over estimated useful lives as follows: Years Real estate: Buildings 20 to 45 Building improvements 10 to 25 Land improvements 10 to 35 Administrative assets: Computers and software 3 to 10 Office furniture and equipment 5 to 20 Vehicles and other 5

Commodity Price Risk Derivati27

Commodity Price Risk Derivatives (Tables)	12 Months Ended
	Dec. 31, 2017
Price Risk Derivatives [Abstract]
Schedule of Outstanding Crude Oil and Natural Gas Swaps	Presented below is a summary of outstanding crude oil and natural gas swaps as of December 31, 2017. Action Begin End Quantity (bbls/d) Price Crude oil price swaps Bought 1/1/18 6/30/18 150 52.20 Action Begin End Quantity (mcf/d) Price Natural gas price swaps Bought 1/1/18 12/31/18 2,500 3.01 Natural gas price swaps Sold 1/1/18 12/31/18 2,000 2.98

Oil and Gas Producing Activit28

Oil and Gas Producing Activities (Tables)	12 Months Ended
	Dec. 31, 2017
Oil and Gas Property [Abstract]
Schedule of Costs Incurred in Purchase of Proved and Unproved Properties, and Exploration and Development Activities	The following table presents the Company’s capitalized costs associated with oil and gas producing activities as of December 31, 2017 and 2016: 2017 2016 Oil and Gas Properties Unevaluated properties: Unproved leasehold costs $ 4,664 $ 4,664 Exploratory wells in progress - - Evaluated properties in full cost pool 86,313 87,834 Less accumulated depreciation, depletion and amortization (83,362 ) (82,640 ) Net capitalized costs $ 7,615 $ 9,858
Schedule of Operations from Oil and Gas Producing Activities	Presented below are the results of operations from oil and gas producing activities for the years ended December 31, 2017, 2016 and 2015: 2017 2016 2015 Oil and gas sales $ 6,545 $ 5,746 $ 10,296 Production costs (3,402 ) (2,728 ) (7,352 ) Depreciation, depletion and amortization (753 ) (2,529 ) (8,412 ) Impairment of oil and gas properties - (9,568 ) (57,676 ) Results of operations from oil and gas producing activities $ 2,390 $ (9,079 ) $ (63,144 )

Property and Equipment, Net (T

Property and Equipment, Net (Tables)	12 Months Ended
	Dec. 31, 2017
Property, Plant and Equipment [Abstract]
Schedule of Property and Equipment	Property and equipment consists of the following as of December 31, 2017 and 2016: 2017 2016 Real estate: Land $ 380 $ 380 Buildings 4,012 4,012 Land improvements 641 641 Administrative assets: Computers and software 368 368 Office furniture and equipment 222 222 Vehicles and other 11 51 Total 5,634 5,674 Less accumulated depreciation (3,917 ) (3,810 ) Property and equipment, net $ 1,717 $ 1,864

Discontinued Operations (Tables

Discontinued Operations (Tables)	12 Months Ended
	Dec. 31, 2017
Discontinued Operations and Disposal Groups [Abstract]
Schedule of Impairment Charge	Presented below is calculation of the impairment charge: Net book value of assets conveyed $ 22,824 Asset retirement obligations assumed by Purchaser (204 ) Impairment charge recognized in 2015 $ 22,620
Schedule of Assets and Liabilities Associated with the Mining Segment	2017 2016 Assets retained by the Company: Performance bonds $ 114 $ 114 Net assets conveyed to Purchaser: Undeveloped mining claims - - Mining equipment - - Less accumulated depreciation of mining equipment - - Less write-down due to impairment - - Net book value of assets conveyed - - Total assets of discontinued operations $ 114 $ 114 Asset retirement obligations assumed by Purchaser $ -
Schedule of Components of Discontinued Operations	. Presented below are the components for the years ended December 31, 2017, 2016 and 2015: 2017 2016 2015 Operating results for apartment complex: Rental revenue $ - $ - $ - Operating expenses - - - Net earnings for apartment complex - - - Operating expenses of mining segment: Water treatment plant - (254 ) (1,737 ) Mine property holding costs - (2,194 ) (1,133 ) Impairment of mining asset - - (22,620 ) Depreciation of mine equipment - - (122 ) Total expenses for mining segment - (2,448 ) (25,612 ) Total results for discontinued operations $ - $ (2,448 ) $ (25,612 )

Executive Retirement and Seve31

Executive Retirement and Severance (Tables)	12 Months Ended
	Dec. 31, 2017
Retirement Benefits [Abstract]
Schedule of changes in the liability	Presented below is a summary of changes in the liability for the years ended December 31, 2017 and 2016: 2016 Balance, beginning of year $ 583 Adjustment to fair value - Payment of retirement benefits (583 ) Negotiated settlement at discount and other - Balance, end of year $ -

Asset Retirement Obligations (T

Asset Retirement Obligations (Tables)	12 Months Ended
	Dec. 31, 2017
Asset Retirement Obligation Disclosure [Abstract]
Schedule of Asset Retirement Obligations	The following is a reconciliation of the changes in the Company’s liabilities for asset retirement obligations for the years ended December 31, 2017 and 2016: 2017 2016 Oil and Gas Mining Oil and Gas Mining Balance, beginning of year $ 1,045 $ - $ 1,038 $ 204 Accretion 32 - 33 - Sold/Plugged (167 ) - (26 ) (204 ) New drilled wells 3 - - - Liabilities incurred - - - - Balance, end of year $ 913 $ - $ 1,045 $ -

Shareholders' Equity (Tables)

Shareholders' Equity (Tables)	12 Months Ended
	Dec. 31, 2017
Stockholders' Equity Note [Abstract]
Schedule of Stock Options Activity	A summary of the combined activity in the 2001 ISOP, the 2012 Equity Plan, and the 2008 Director SOP for the years ended December 31, 2017, 2016 and 2015 is as follows: 2017 2016 2015 Shares Price (1) Shares Price (1) Shares Price (1) Outstanding, beginning of year 390,525 $ 20.64 390,525 $ 20.64 2,276,079 $ 3.78 Granted 170,000 1.00 - - 340,711 1.50 Forfeited - - - - - - Expired (170,838 ) 29.82 - - (273,768 ) 3.86 Exercised - - - - - - Outstanding, end of year 389,687 $ 8.05 390,525 $ 20.64 2,343,022 $ 3.44 Shares restated after 6 to 1 split 389,687 $ 8.05 390,525 $ 20.64 390,525 $ 20.64 Exercisable, end of year 274,132 $ 10.79 376,084 $ 20.79 2,194,022 $ 3.53 Shares restated after 6 to 1 split - $ - - $ - 365,693 $ 21.17 (1) Represents the weighted average price.
Schedule of Stock Options Outstanding and Exercisable	The following table summarizes information for stock options outstanding and for stock options exercisable at December 31, 2017: Options Outstanding Options Exercisable Number Exercise Price Remaining Number Weighted of Range Weighted Contractual of Average Shares Low High Average Term (years) Shares Exercise Price 56,786 $ 9.00 $ 9.00 $ 9.00 7.0 51,231 $ 9.00 49,504 12.48 12.48 12.48 5.5 49,504 12.48 98,396 13.92 17.10 15.01 1.8 98,396 15.01 15,001 22.62 30.24 24.03 5.5 15,001 24.03 60,000 0.72 0.72 0.72 9.6 60,000 0.72 110,000 1.16 1.16 1.16 9.9 - - 389,687 $ 0.72 $ 30.24 $ 8.05 6.7 274,132 $ 10.79
Schedule of Assumptions Fair Value of Options	. In estimating the fair value of options, the Company used the Black-Scholes option-pricing model with the following weighted average assumptions: 2017 2016 Expected lives (in years) 10.0 - Risk-free interest rate 2.33 % - Expected volatility 80.0 % - Expected dividend yield 0.00 % -

Income Taxes (Tables)

Income Taxes (Tables)	12 Months Ended
	Dec. 31, 2017
Income Tax Disclosure [Abstract]
Schedule of Effective Income Tax	Income tax benefit using the Company’s effective income tax rate differs from the U.S. Federal Statutory income tax rate due to the following: 2017 2016 2015 Income tax benefit at federal statutory rate $ 472 $ 4,801 $ 31,585 State income tax benefit, net of federal impact 38 292 1,440 Change in Federal tax rate, net of state benefit (1) (5,440 ) Loss on debt to equity conversion (1,630 ) Effect of Sec. 382 Limitation (29,803 ) Incentive stock options and restricted stock not deductible for tax purposes 964 - (269 ) Percentage depletion carryover 138 19 - Prior year true up 1,076 534 171 Other 77 Decrease in valuation allowance (34,109 ) (5,646 ) (32,927 ) Income tax benefit (expense) $ - $ - $ - (1) The change in the Federal Tax rate was due to the passage of Public Law 115-97 (Tax Cuts and Jobs Act). This resulted in a provisional reduction of the Company’s deferred tax assets before valuation analysis primarily due to a reduction in the US Statutory rate from 35% to 21%. We will continue to analyze the Tax Cuts and Jobs Act and future associated Treasury Regulations. This future analysis could potentially affect the measurement of deferred tax balances and give rise to new deferred tax amounts.
Schedule of Deferred Tax Assets and Liabilities	The components of deferred tax assets and liabilities as of December 31, 2017 and 2016 are as follows: 2017 2016 Deferred tax assets: Net operating loss carryover (2) $ 874 $ 26,739 Property and equipment 7,123 14,575 Percentage depletion and contribution carryovers (2) 1,872 2,512 Alternative minimum tax credit carryover (2) 785 706 Equity method investment and other 398 547 Deferred compensation liability 8 12 Asset retirement obligations 221 377 Stock-based compensation 83 (44 ) Total deferred tax assets 11,364 45,424 Deferred tax liabilities: Property and equipment - - Oil price risk derivatives - - Other (3 ) (4 ) Total deferred tax liabilities (3 ) (4 ) Net deferred tax assets 11,361 45,420 Less valuation allowance (11,361 ) (45,420 ) Net deferred tax asset $ - $ - (2) On December 27, 2017, the Company paid down debt with common stock. This represented a 49.3% ownership change in the company. This combined with other equity events triggered Net Operation Loss limitations under I.R.C Section 382. As a result, the Company’s Net Operating Loss carryforwards were significantly limited.

Loss Per Share (Tables)

Loss Per Share (Tables)	12 Months Ended
	Dec. 31, 2017
Earnings Per Share [Abstract]
Schedule of Dilutive Stock Options Computed Using the Treasury Stock	The calculation of diluted loss per share adds dilutive stock options computed using the treasury stock method as follows: 2017 2016 2015 Basic weighted average common shares outstanding 5,899,802 4,768,013 4,677,500 Dilutive stock options using treasury stock method - - - Diluted weighted average common shares outstanding 5,899,802 4,768,013 4,677,500
Schedule of Antidilutive Weighted Average Shares	For the years ended December 31, 2017, 2016 and 2015, common stock equivalents excluded from the calculation of weighted average shares because they were antidilutive are as follows: 2017 2016 2015 Stock options 389,687 390,525 390,525 Unvested shares of restricted common stock 5,555 24,832 16,667 Total 395,242 415,357 407,192

Significant Concentrations (Tab

Significant Concentrations (Tables)	12 Months Ended
	Dec. 31, 2017
Risks and Uncertainties [Abstract]
Schedule of Company's Oil and Gas Sales	During the years ended December 31, 2017, 2016 and 2015, three joint interest operators accounted for the following percentages of the Company’s oil and gas sales: Operator 2017 2016 2015 A 13 % 16 % 20 % B 25 % 32 % 35 % C 34 % 29 % 25 %

Fair Value Measurements (Tables

Fair Value Measurements (Tables)	12 Months Ended
	Dec. 31, 2017
Fair Value Disclosures [Abstract]
Schedule of Recurring Measurements of the Fair Value of Assets and Liabilities	Recurring measurements of the fair value of assets and liabilities as of December 31, 2017 and 2016 are as follows: December 31, 2017 December 31, 2016 Level 1 Level 2 Level 3 Total Level 1 Level 2 Level 3 Total Marketable equity securitites: Sutter Gold Mining Company $ - $ 8 $ - $ 8 $ - $ 16 $ - $ 16 Anfield Resources, Inc. 868 - - 868 930 - - 930 Total $ 868 $ 8 $ - $ 876 $ 930 $ 16 $ - $ 946 Outstanding warrant liability - - 1,200 1,200 - - 1,030 1,030 Crude oil price risk derivatives - 161 - 161 - - - - Total $ - $ 161 $ 1,200 $ 1,361 $ - $ - $ 1,030 $ 1,030
Schedule of Reconciliation of Changes in Assets and Liabilities Measured at Fair Value On a Recurring Basis	The following table presents a reconciliation of changes in assets and liabilities measured at fair value on a recurring basis for the years ended December 31, 2017 and 2016: Assets Liabilities Marketable Securities Crude Oil Crude Oil Executive Sutter Anfield Derivatives Derivatives Retirement Warrants (Level 2) (Level 1) (Level 2) (Level 2) (Level 3) (Level 3) Net Fair value, December 31, 2015 13 238 1,634 - (583 ) - 1,302 Acquisition of investment - 750 - - - - 750 Issuance of warrants - - - - - 1,240 1,240 Other comprehensive loss 3 - - - - - 3 Fair value adjustments included in net loss: - Net unrealized gain on warrant valuation - - - - - (210 ) (210 ) Net unrealized loss on Anfield Shares - (58 ) - - - - (58 ) Offset of derivative assets and liabilities - - (194 ) - - - (194 ) Cash settlements paid - - (1,440 ) - 583 - (857 ) Fair value, December 31, 2016 $ 16 $ 930 $ - - $ - $ 1,030 $ 1,976 Total net losses included in: Acquisition of investment - 777 - - - - 777 Other comprehensive loss (8 ) - - - - - (8 ) Fair value adjustments included in net loss: - Net unrealized loss on oil price risk derivatives - - - (26 ) - - (26 ) Net unrealized loss on warrant valuation - - - - - 170 170 Net unrealized loss on Anfield Shares - (839 ) - - - - (839 ) Cash settlements paid - - - (135 ) - - (135 ) - Fair value, December 31, 2017 $ 8 $ 868 $ - (161 ) $ - $ 1,200 $ 1,915

Unaudited Supplemental Oil an38

Unaudited Supplemental Oil and Gas Information (Tables)	12 Months Ended
	Dec. 31, 2017
Oil and Gas Exploration and Production Industries Disclosures [Abstract]
Schedule of Proved Oil and Gas Reserves and Changes in Net Proved Reserves	The Company’s estimated quantities of proved oil and gas reserves and changes in net proved reserves are summarized below for the years ended December 31, 2017, 2016 and 2015: 2017 2016 2015 Oil Gas Oil Gas Oil Gas (bbls) (mcfe) (1) (bbls) (mcfe) (1) (bbls) (mcfe) (1) Total proved reserves: Reserve quantities, beginning of year 657,280 1,379,163 1,615,180 2,477,930 4,119,736 3,211,245 Revisions of previous estimates 302,530 55,072 (795,459 ) (584,494 ) (2,377,364 ) (206,912 ) Discoveries and extensions 22,801 21,787 23,841 20,336 94,458 27,102 Sale of minerals in place (194,667 ) (118,944 ) (53,853 ) (57,258 ) - - Production (111,914 ) (448,571 ) (132,429 ) (477,351 ) (221,650 ) (553,505 ) Reserve quantities, end of year 676,030 888,507 657,280 1,379,163 1,615,180 2,477,930 Proved developed reserves, end of year 676,030 888,507 657,280 1,379,163 1,248,750 2,068,190 (1) Mcf equivalents (Mcfe) consist of natural gas reserves in mcf plus NGLs converted to mcf using a factor of 6 mcf for each barrel of NGL.
Schedule of Prices as Adjusted for Transportation, Quality	The following prices as adjusted for transportation, quality, and basis differentials were used in the calculation of the standardized measure: 2017 2016 2015 Oil per Bbl $ 51.34 $ 42.75 $ 43.54 Gas per Mcfe (1) $ 2.98 $ 2.48 $ 3.36
Schedule of Standardized Measure of Discounted Future Net Cash Flows	The standardized measure of discounted future net cash flows relating to the Company’s proved oil and gas reserves is as follows as of December 31, 2017, 2016 and 2015: 2017 2016 2015 Future cash inflows $ 34,424 $ 27,769 $ 78,646 Future cash outflows: Production costs (18,518 ) (18,814 ) (44,685 ) Development costs - - (8,050 ) Income taxes - - - Future net cash flows 15,906 8,955 25,911 10% annual discount factor (6,653 ) (2,208 ) (8,143 ) Standardized measure of discounted future net cash flows $ 9,253 $ 6,747 $ 17,768
Schedule of Standardized Measure of Future Net Cash Flows	The changes in the standardized measure of future net cash flows relating to proved oil and gas reserves for the years ended December 31, 2017, 2016 and 2015 are as follows: 2017 2016 2015 Standardized measure, beginning of year $ 6,747 $ 17,768 $ 81,889 Sales of oil and gas, net of production costs (3,143 ) (3,102 ) (2,944 ) Net changes in prices and production costs 2,347 (9,248 ) (96,586 ) Changes in estimated future development costs - 6,590 51,998 Extensions and discoveries 511 167 2,260 Sale of minerals in place (1,049 ) (78 ) - Revisions in previous quantity estimates 3,416 (6,791 ) (27,693 ) Previously estimated development costs incurred - - - Net changes in income taxes - - 3,306 Accretion of discount 675 1,777 8,189 Changes in timing and other (251 ) (336 ) (2,651 ) Standardized measure, end of year $ 9,253 $ 6,747 $ 17,768

Quarterly Financial Data (Una39

Quarterly Financial Data (Unaudited) (Tables)	12 Months Ended
	Dec. 31, 2017
Quarterly Financial Information Disclosure [Abstract]
Schedule of Quarterly Financial Information	The Company’s quarterly financial information for the two-year period ended December 31, 2017 is as follows: Year Ended December 31, 2016 Year Ended December 31, 2017 First Second Third Fourth First Second Third Fourth Quarter Quarter Quarter Quarter Quarter Quarter Quarter Quarter Oil and gas sales $ 1,066 $ 1,996 $ 1,867 $ 817 $ 1,747 $ 1,992 $ 1,538 $ 1,268 Operating expenses: - Impairment of oil and gas properties (6,957 ) (2,611 ) - - - - - - Other (1) (2,561 ) (3,061 ) (2,761 ) 276 (2,485 ) (1,996 ) (1,601 ) (1,451 ) Operating income (loss) (1) $ (8,452 ) $ (3,676 ) $ (894 ) $ 1,093 $ (738 ) $ (4 ) $ (63 ) $ (183 ) Income (loss) from continuing operations (1) $ (8,275 ) $ (4,206 ) $ (265 ) $ 1,074 $ (740 ) $ (336 ) $ (382 ) $ 98 Discontinued operations (2,327 ) (10 ) - (111 ) - - - - Net income (loss) $ (10,602 ) $ (4,216 ) $ (265 ) $ 963 $ (740 ) $ (336 ) $ (382 ) $ 983 Income (loss) per share - basic (1)(2) Continuing operations $ (1.76 ) $ (0.90 ) $ (0.06 ) $ 0.23 $ (0.13 ) $ (0.02 ) $ (0.06 ) $ 0.02 Discontinued operations (0.49 ) (0.00 ) - - - - - - Total $ (2.25 ) $ (0.90 ) $ (0.06 ) $ 0.23 $ (0.13 ) $ (0.02 ) $ (0.06 ) $ 0.02 Income (loss) per share - diluted (1)(2) Continuing operations $ (1.76 ) $ (0.90 ) $ (0.06 ) $ 0.23 $ (0.13 ) $ (0.02 ) $ (0.06 ) $ 0.02 Discontinued operations (0.49 ) (0.00 ) - - - - - - Total $ (2.25 ) $ (0.90 ) $ (0.06 ) $ 0.23 $ (0.13 ) $ (0.02 ) $ (0.06 ) $ 0.02 Weighted average shares outstanding: Basic 4,705,500 4,705,000 4,768,000 4,768,013 5,834,568 5,834,568 5,834,568 5,899,802 Diluted (1) 4,705,500 4,705,000 4,768,000 4,768,013 5,834,568 6,626,344 5,834,568 5,899,802 (1) Amounts have been restated from amounts reported in previous reports to retroactively present the impact of Discontinued Operations as discussed further in Note 6. (2) Earnings per share amounts may not sum due to rounding.

Organization, Operations and 40

Organization, Operations and Significant Accounting Policies (Details Narrative) - USD ($)	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Allowance for doubtful accounts
Percentage of estimated future net revenue, discounted	10.00%
Gas balancing obligations
Mining Equipment [Member] | Minimum [Member]
Estimated useful lives	10 years
Mining Equipment [Member] | Maximum [Member]
Estimated useful lives	20 years

Organization, Operations and 41

Organization, Operations and Significant Accounting Policies - Schedule of Property and Equipment Useful Life (Details)	12 Months Ended
	Dec. 31, 2017
Buildings [Member] | Minimum [Member]
Property, Plant and Equipment [Line Items]
Estimated useful lives	20 years
Buildings [Member] | Maximum [Member]
Property, Plant and Equipment [Line Items]
Estimated useful lives	45 years
Building Improvements [Member] | Minimum [Member]
Property, Plant and Equipment [Line Items]
Estimated useful lives	10 years
Building Improvements [Member] | Maximum [Member]
Property, Plant and Equipment [Line Items]
Estimated useful lives	25 years
Land Improvements [Member] | Minimum [Member]
Property, Plant and Equipment [Line Items]
Estimated useful lives	10 years
Land Improvements [Member] | Maximum [Member]
Property, Plant and Equipment [Line Items]
Estimated useful lives	35 years
Computers and Software [Member] | Minimum [Member]
Property, Plant and Equipment [Line Items]
Estimated useful lives	3 years
Computers and Software [Member] | Maximum [Member]
Property, Plant and Equipment [Line Items]
Estimated useful lives	10 years
Office Furniture and Equipment [Member] | Minimum [Member]
Property, Plant and Equipment [Line Items]
Estimated useful lives	5 years
Office Furniture and Equipment [Member] | Maximum [Member]
Property, Plant and Equipment [Line Items]
Estimated useful lives	20 years
Vehicles and Other [Member]
Property, Plant and Equipment [Line Items]
Estimated useful lives	5 years

Liquidity (Details Narrative)

Liquidity (Details Narrative) - USD ($)	Dec. 29, 2017	Oct. 03, 2017	Sep. 20, 2017	Dec. 31, 2017	Sep. 30, 2017	Jun. 30, 2017	Mar. 31, 2017	Dec. 31, 2016	Sep. 30, 2016	Jun. 30, 2016	Mar. 31, 2016	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015	Dec. 27, 2017
Working capital surplus				$ 4,300,000								$ 4,300,000
Accumulated deficit				125,185,000				$ 123,825,000				125,185,000	$ 123,825,000
Net loss				$ (983,000)	$ 382,000	$ 336,000	$ 740,000	$ (963,000)	$ 265,000	$ 4,216,000	$ 10,602,000	$ 1,360,000	$ 14,120,000	$ 92,896,000
Common stock, par value				$ 0.01				$ 0.01				$ 0.01	$ 0.01
Outstanding common stock, percentage															49.30%
Cash and equivalents				$ 3,300,000								$ 3,300,000		$ 1,271,000
Purchase and Sale Agreement [Member] | Energy One LLC and Statoil Oil and Gas LP [Member]
Consideration for the elimination in outstanding liabilities		$ 4,000,000
Payments to acquire oil and gas property		$ 2,000,000
Exchange Agreement [Member] | Energy One LLC and APEG Energy II, L.P. [Member]
Borrowing capacity under credit facility	$ 4,463,380
Number of share issued	5,819,270
Common stock, par value	$ 0.01
Exchange price	$ 0.767			$ 1.53								$ 1.53
Volume weighted average price percentage			1.30%
Outstanding common stock, percentage	49.30%
Stock price			$ 1.53

Commodity Price Risk Derivati43

Commodity Price Risk Derivatives (Details Narrative) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Price Risk Derivatives [Abstract]
Realized gain (loss) on commodity price risk derivatives	$ 135	$ 1,440	$ (75)
Unrealized gains (losses) from derivatives	161	$ 1,634	$ (1,634)
Unrealized loss on commodity derivative contracts	160
Unrealized loss from oil price derivatives	220
Unrealized gain from natural gas commodity derivatives	$ 60

Commodity Price Risk Derivati44

Commodity Price Risk Derivatives - Schedule of Outstanding Crude Oil and Natural Gas Swaps (Details) - Swap [Member]	12 Months Ended
	Dec. 31, 2017$ / bbl$ / McfbblMcf
Natural Gas (mcfe) [Member] | Purchase [Member]
Begin	Jan. 1, 2018
End	Dec. 31, 2018
Quantity | Mcf	2,500
Price | $ / Mcf	3.01
Natural Gas (mcfe) [Member] | Sales [Member]
Begin	Jan. 1, 2018
End	Dec. 31, 2018
Quantity | Mcf	2,000
Price | $ / Mcf	2.98
Crude Oil [Member] | Purchase [Member]
Begin	Jan. 1, 2018
End	Jun. 30, 2018
Quantity | bbl	150
Price | $ / bbl	52.20

Oil and Gas Producing Activit45

Oil and Gas Producing Activities (Details Narrative) - USD ($) $ / shares in Units, $ in Thousands

Oct. 03, 2017

Dec. 31, 2017

Sep. 30, 2017

Jun. 30, 2017

Mar. 31, 2017

Dec. 31, 2016

Sep. 30, 2016

Jun. 30, 2016

Mar. 31, 2016

Dec. 31, 2017

Dec. 31, 2016

Dec. 31, 2015

Gain on sale of oil and gas properties

$ 4,318

Discount rate

10.00%

Impairment of oil and gas properties

$ (2,611)

$ (6,957)

$ 9,568

$ 57,676

Depreciation, depletion and amortization per equivalent BOE

$ 3.86

$ 11.93

$ 26.80

Unproved lease acquisition costs

$ 4,700

$ 4,700

Oil (bbls) [Member]

Reserves

$51.34 per barrel for oil

Natural Gas (mcfe) [Member]

Reserves

2.976 per MMbtu for natural gas

Purchase and Sale Agreement [Member] | Energy One LLC and Statoil Oil and Gas LP [Member]

Consideration for the elimination in outstanding liabilities

$ 4,000

Payments to acquire oil and gas property

$ 2,000

Impacts reserves percentage description

A gain/loss calculation must be performed on any transaction which impacts reserves greater than 25%.

Oil and Gas Producing Activit46

Oil and Gas Producing Activities - Schedule of Costs Incurred in Purchase of Proved and Unproved Properties, and Exploration and Development Activities (Details) - USD ($) $ in Thousands	Dec. 31, 2017	Dec. 31, 2016
Oil and Gas Property [Abstract]
Unproved leasehold costs	$ 4,664	$ 4,664
Exploratory wells in progress
Evaluated properties in full cost pool	86,313	87,834
Less accumulated depreciation, depletion and amortization	(83,362)	(82,640)
Net capitalized costs	$ 7,615	$ 9,858

Oil and Gas Producing Activit47

Oil and Gas Producing Activities - Schedule of Operations from Oil and Gas Producing Activities (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Oil and Gas Property [Abstract]
Oil and gas sales	$ 6,545	$ 5,746	$ 10,296
Production costs	(3,402)	(2,728)	(7,352)
Depreciation, depletion and amortization	(753)	(2,529)	(8,412)
Impairment of oil and gas properties		(9,568)	(57,676)
Results of operations from oil and gas producing activities	$ 2,390	$ (9,079)	$ (63,144)

Property and Equipment, Net (De

Property and Equipment, Net (Details Narrative) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Property, Plant and Equipment [Abstract]
Depreciation expense	$ 890	$ 2,529	$ 8,557

Property and Equipment, Net - S

Property and Equipment, Net - Schedule of Property and Equipment (Details) - USD ($) $ in Thousands	Dec. 31, 2017	Dec. 31, 2016
Property and equipment, gross	$ 5,634	$ 5,674
Less accumulated depreciation	(3,917)	3,810
Property and equipment, net	1,717	1,864
Land [Member]
Property and equipment, gross	380	380
Buildings [Member]
Property and equipment, gross	4,012	4,012
Land Improvements [Member]
Property and equipment, gross	641	641
Computers and Software [Member]
Property and equipment, gross	368	368
Office Furniture and Equipment [Member]
Property and equipment, gross	222	222
Vehicles and Other [Member]
Property and equipment, gross	$ 11	$ 51

Discontinued Operations (Detail

Discontinued Operations (Details Narrative) - USD ($) $ / shares in Units, $ in Thousands	3 Months Ended		12 Months Ended
	Mar. 31, 2016	Dec. 31, 2015	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015	Feb. 29, 2016	Dec. 31, 2014	Dec. 31, 2013
Aggregate annual expenses					$ 3
Impairment charge		$ 22,620
Preferred shares authorized			100,000	100,000
Common stock, par value			$ 0.01	$ 0.01
Common stock shares			11,820,057	6,134,506
Adjusted liquidation preference value			$ 2,527
Series A Convertible Preferred Stock [Member]
Preferred shares authorized			50,000			50,000
Freeport-McMoRan Inc. [Member] | Series A Convertible Preferred Stock Purchase Agreement [Member]
Convertible preferred stock			13.33
Common stock, par value			$ 0.01
Common stock shares			666,667
Common stock issued upon conversion			793,000
Adjusted liquidation preference value	$ 2
Cash consideration paid	$ 2
Freeport-McMoRan Inc. [Member] | Series A Convertible Preferred Stock Purchase Agreement [Member] | Series A Convertible Preferred Stock [Member]
Shares issued			50,000
Description of transfer property			(i) MEM accepting the transfer of the Property and replacing the Company as the permittee and operator of the WTP, and (ii) the payment of $1 to the Company. The Series A Purchase Agreement contains customary representations and warranties on the part of the Company. As contemplated by the Acquisition Agreement and the Series A Purchase Agreement and as approved by the Company’s Board of Directors, the Company filed with the Secretary of State of the State of Wyoming Articles of Amendment containing a Certificate of Designations with respect to the Preferred Stock (the “Certificate of Designations”).
Preferred shares authorized			50,000
Percentage of dividend rate			12.25%
Adjusted liquidation preference per share			$ 40
Accrued quarterly dividend increases in each quarter			$ 2
Freeport-McMoRan Inc. [Member] | Investor Rights Agreement [Member]
Percentage of outstanding shares acquire			16.86%
Mt. Emmons Molybdenum Mining Properties [Member]
Market price							$ 11	$ 11
Mt. Emmons Molybdenum Mining Properties [Member] | Minimum [Member]
Market price		$ 5			$ 5

Discontinued Operations - Sched

Discontinued Operations - Schedule of Impairment Charge (Details) - USD ($) $ in Thousands	3 Months Ended	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2017	Dec. 31, 2016
Discontinued Operations and Disposal Groups [Abstract]
Net book value of assets conveyed	$ 22,824
Asset retirement obligations assumed by Purchaser	(204)
Impairment charge recognized in 2015	$ 22,620

Discontinued Operations - Sch52

Discontinued Operations - Schedule of Assets and Liabilities Associated with the Mining Segment (Details) - USD ($) $ in Thousands	3 Months Ended	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2017	Dec. 31, 2016
Discontinued Operations and Disposal Groups [Abstract]
Performance bonds		$ 114	$ 114
Undeveloped mining claims
Mining equipment
Less accumulated depreciation of mining equipment
Less write-down due to impairment	$ (22,620)
Net book value of assets conveyed
Total assets of discontinued operations		114	114
Asset retirement obligations assumed by Purchaser	$ 204

Discontinued Operations - Sch53

Discontinued Operations - Schedule of Components of Discontinued Operations (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Discontinued Operations and Disposal Groups [Abstract]
Rental revenue
Operating expenses
Net earnings for apartment complex
Water treatment plant		(254)	(1,737)
Mine property holding costs		(2,194)	(1,133)
Impairment of mining asset			(22,620)
Depreciation of mine equipment			(122)
Total expenses for mining segment		(2,448)	(25,612)
Total results for discontinued operations		$ (2,448)	$ (25,612)

Debt (Details Narrative)

Debt (Details Narrative) - USD ($)	Dec. 29, 2017	Sep. 20, 2017	Dec. 31, 2017	Dec. 31, 2016	Dec. 27, 2017
Short-term Debt [Line Items]
Common stock, par value			$ 0.01	$ 0.01
Outstanding common stock, percentage					49.30%
Energy One LLC [Member] | Credit Agreement [Member]
Short-term Debt [Line Items]
Description of covenants			Proved Developed Producing Coverage Ratio to be less than 1.2 to 1; and (ii) the current ratio to be less than 1.0 to 1.0.
Energy One LLC [Member] | Credit Facility [Member] | APEG Energy II, L.P. [Member]
Short-term Debt [Line Items]
Outstanding amount of credit facility			$ 1,500,000	$ 6,000,000
Borrowing base			$ 6,000,000	$ 6,000,000
Credit facility term			6 months
Fixed interest rate			8.75%
Energy One LLC and APEG Energy II, L.P. [Member] | Exchange Agreement [Member]
Short-term Debt [Line Items]
Outstanding amount of credit facility	$ 4,463,380
Number of share issued	5,819,270
Common stock, par value	$ 0.01
Exchange price	$ 0.767		$ 1.53
Volume weighted average price percentage		1.30%
Outstanding common stock, percentage	49.30%

Executive Retirement and Seve55

Executive Retirement and Severance (Details Narrative) - USD ($)	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Cash and equivalents	$ 3,300,000		$ 1,271,000
Executive Retirement Policy [Member]
Description about plan terms	The executive officer was required to serve as one of the designated executive officers for at least 15 years, reached the age of 60, and been an employee of the Company on December 31, 2010. Upon retirement, the executive was entitled to cash payments equaling 50% of the greater of (i) the amount of compensation earned as base cash pay on the final regular pay check or (ii) the average annual pay, less all bonuses, received over the last five years of employment with the Company.
Total compensation expense	$ 0	$ 3,000

Executive Retirement and Seve56

Executive Retirement and Severance - Schedule of changes in the liability (Details) $ in Thousands	12 Months Ended
	Dec. 31, 2016USD ($)
Retirement Benefits [Abstract]
Balance, beginning of year	$ 583
Adjustment to fair value
Payment of retirement benefits	(583)
Negotiated settlement at discount and other
Balance, end of year

Asset Retirement Obligations -

Asset Retirement Obligations - Schedule of Asset Retirement Obligations (Details) - USD ($)	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016
Oil and Gas Properties [Member]
Balance, beginning of year	$ 1,045	$ 1,038
Accretion of discount	32	33
Sold/Plugged	(167)	(26)
New drilled wells	3
Liabilities incurred
Balance, end of year	913	1,045
Mining [Member]
Balance, beginning of year		204
Accretion of discount
Sold/Plugged		(204)
New drilled wells
Liabilities incurred
Balance, end of year

Commitments, Contingencies, a58

Commitments, Contingencies, and Related Party Transactions (Details Narrative) $ in Thousands	1 Months Ended		12 Months Ended
	May 31, 2017USD ($)	Sep. 30, 2013a	Dec. 31, 2017USD ($)	Dec. 31, 2016USD ($)	Dec. 31, 2015USD ($)
Rental income			$ 100	$ 100	$ 100
Professional fees			2,314	1,994	1,866
Rental and other income/(loss)			321	$ 169	$ (431)
Texas Quiet Title Action - Willerson Lease [Member] | Chesapeake Exploration, LLC [Member]
Percentage of lease acquired		15.00%
Area of lease acquired | a		4,244
Legal fees			75
Professional fees			165
Proceeds from the settlement	$ 175
Rental and other income/(loss)	$ 15
Texas Quiet Title Action - Willerson Lease [Member] | Former Employee [Member] | Executive Severance and Non-Compete Agreement [Member]
Damages sought value			1,800
Chief Executive Officer [Member]
Payments of related party			$ 50

Shareholders' Equity (Details N

Shareholders' Equity (Details Narrative) - USD ($) $ / shares in Units, $ in Thousands		Dec. 21, 2016	Sep. 23, 2016	Jun. 30, 2012	Dec. 31, 2001	Jun. 30, 2008	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015	Feb. 29, 2016	Dec. 31, 2014
Preferred shares authorized							100,000	100,000
Preferred shares, par value							$ 0.01	$ 0.01
Warrant liability							$ 1,200	$ 1,030
Number of stock option outstanding							389,687	390,525	2,343,022		2,276,079
Stock option exercised
Compensation expenses							$ 300	$ 200	$ 900
Unrecognized share based compensation							$ 100
Number of shares granted							170,000		340,711
Exercise price of granted shares	[1]						$ 1		$ 1.50
Severance Agreements [Member]
Number of stock option outstanding									1,617,689
Compensation expenses									$ 100
Registered Direct Offering [Member]
Number of share issued		1,000,000
Net share price		$ 1.50
Net proceeds from offering		$ 1,320
Warrant [Member] | Registered Direct Offering [Member]
Number of warrant called		1,000,000
Warrant exercise price		$ 2.05
Warrant term		5 years
Net proceeds from offering		$ 1,240
Common Stock [Member]
Number of share issued								367,667
Number of shares granted							(151,008)
Common Stock [Member] | Registered Direct Offering [Member]
Net proceeds from offering		$ 800
Preferred Stock [Member]
Preferred shares, par value							$ 0.01
Series P Preferred Stock [Member]
Preferred shares authorized							50,000
Series A Convertible Preferred Stock [Member]
Preferred shares authorized							50,000			50,000
Maximum [Member] | Preferred Stock [Member]
Preferred shares authorized							100,000
2001 Incentive Stock Option Plan [Member]
Percentage of common stock issued and outstanding					25.00%
Stock option description					10 years which expired in December 2011		expire on various dates through September 2018.
Number of stock option outstanding							67,558
2012 Equity Plan [Member]
Stock option description				The 2012 Equity Plan has a term of 10 years which expires in June 2022.			expire on various dates through January 2025.
Number of stock option outstanding							292,350
2012 Equity Plan [Member] | Employees and Directors [Member]
Number of shares reserves for future issuance				1,533,333
2008 Stock Option Plan [Member]
Percentage of common stock issued and outstanding						1.00%
Stock option description							expire on various dates through September 2024.
Number of stock option outstanding							29,779
Stock option term						10 years
Employee Stock Ownership Plan [Member]
Annual compensation of ESOP									$ 300
Restricted Stock [Member]
Compensation expenses			$ 200
Number of shares granted			199,992
Number of shares vested			33,332
Exercise price of granted shares			$ 1.05
Restricted Stock [Member] | Board of Directors [Member]
Number of shares granted			58,500
Restricted Stock [Member] | Board Member [Member]
Number of shares granted			351,000
September 23, 2016 Grants [Member]
Unrecognized share based compensation							$ 0
[1]	Represents the weighted average price.

Shareholders' Equity - Schedule

Shareholders' Equity - Schedule of Stock Options Activity (Details) - $ / shares		12 Months Ended
		Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Stockholders' Equity Note [Abstract]
Stock options outstanding, beginning		390,525	2,343,022	2,276,079
Stock options, Granted		170,000		340,711
Stock options, Forfeited
Stock options, Expired		(170,838)		(273,768)
Stock options, Exercised
Stock options outstanding, ending		389,687	390,525	2,343,022
Shares restated after 6 to 1 split, outstanding		389,687	390,525	390,525
Stock options exercisable, ending		274,132	376,084	2,194,022
Shares restated after 6 to 1 split, exercisable				365,693
Stock options outstanding price per share, beginning	[1]	$ 20.64	$ 3.44	$ 3.78
Stock options outstanding price per share, Granted	[1]	1		1.50
Stock options outstanding price per share, Forfeited	[1]
Stock options outstanding price per share, Expired	[1]	29.82		3.86
Stock options outstanding price per share, Exercised	[1]
Stock options outstanding price per share, ending	[1]	8.05	20.64	3.44
Shares restated after 6 to 1 split per share, outstanding	[1]	8.05	20.64	20.64
Stock options exercisable price per share	[1]	10.79	20.79	3.53
Shares restated after 6 to 1 split per share, exercisable	[1]			$ 21.17
[1]	Represents the weighted average price.

Shareholders' Equity - Schedu61

Shareholders' Equity - Schedule of Stock Options Activity (Details) (Parenthetical)	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Stockholders' Equity Note [Abstract]
Stock split	6 to 1 split	6 to 1 split	6 to 1 split

Shareholders' Equity - Schedu62

Shareholders' Equity - Schedule of Stock Options Outstanding and Exercisable (Details) - $ / shares		12 Months Ended
		Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Options Outstanding		389,687	390,525	2,343,022	2,276,079
Exercise price range, Lower range		$ 0.72
Exercise price range, Upper range		30.24
Weighted Average	[1]	$ 8.05	$ 20.64	$ 3.44	$ 3.78
Remaining Contractual Term (Years)		6 years 8 months 12 days
Options Exercisable		274,132	376,084	2,194,022
Weighted Average Exercisable	[1]	$ 10.79	$ 20.79	$ 3.53
Exercise Price One [Member]
Options Outstanding		56,786
Exercise price range, Lower range		$ 9
Exercise price range, Upper range		9
Weighted Average		$ 9
Remaining Contractual Term (Years)		7 years
Options Exercisable		51,231
Weighted Average Exercisable		$ 9
Exercise Price Two [Member]
Options Outstanding		49,504
Exercise price range, Lower range		$ 12.48
Exercise price range, Upper range		12.48
Weighted Average		$ 12.48
Remaining Contractual Term (Years)		5 years 6 months
Options Exercisable		49,504
Weighted Average Exercisable		$ 12.48
Exercise Price Three [Member]
Options Outstanding		98,396
Exercise price range, Lower range		$ 13.92
Exercise price range, Upper range		17.10
Weighted Average		$ 15.01
Remaining Contractual Term (Years)		1 year 9 months 18 days
Options Exercisable		98,396
Weighted Average Exercisable		$ 15.01
Exercise Price Four [Member]
Options Outstanding		15,001
Exercise price range, Lower range		$ 22.62
Exercise price range, Upper range		30.24
Weighted Average		$ 24.03
Remaining Contractual Term (Years)		5 years 6 months
Options Exercisable		15,001
Weighted Average Exercisable		$ 24.03
Exercise Price Five [Member]
Options Outstanding		60,000
Exercise price range, Lower range		$ 0.72
Exercise price range, Upper range		0.72
Weighted Average		$ 0.72
Remaining Contractual Term (Years)		9 years 7 months 6 days
Options Exercisable		60,000
Weighted Average Exercisable		$ 0.72
Exercise Price Six [Member]
Options Outstanding		110,000
Exercise price range, Lower range		$ 1.16
Exercise price range, Upper range		1.16
Weighted Average		$ 1.16
Remaining Contractual Term (Years)		9 years 10 months 25 days
Options Exercisable
Weighted Average Exercisable
[1]	Represents the weighted average price.

Shareholders' Equity - Schedu63

Shareholders' Equity - Schedule of Assumptions Fair Value of Options (Details)	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016
Stockholders' Equity Note [Abstract]
Expected lives (in years)	10 years	0 years
Risk-free interest rate	2.33%	0.00%
Expected volatility	80.00%	0.00%
Expected dividend yield	0.00%	0.00%

Income Taxes (Details Narrative

Income Taxes (Details Narrative) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Description of limitation of use	The net operating losses may be used to offset future taxable income and expire in varying amounts through 2036.
Minimum tax credit carry-forwards	$ 785
Uncertain tax positions
Federal [Member]
Net operating loss carryovers	$ 3,600

Income Taxes - Schedule of Effe

Income Taxes - Schedule of Effective Income Tax (Details) - USD ($) $ in Thousands		12 Months Ended
		Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Income Tax Disclosure [Abstract]
Income tax benefit at federal statutory rate		$ 472	$ 4,801	$ 31,585
State income tax benefit, net of federal impact		38	292	1,440
Change in Federal tax rate, net of state benefit	[1]	(5,440)
Loss on debt to equity conversion		(1,630)
Effect of Sec. 382 Limitation		(29,803)
Incentive stock options and restricted stock not deductible for tax purposes		964		(269)
Percentage depletion carryover		138	19
Prior year true up		1,076	534	171
Other		77
Decrease in valuation allowance		(34,109)	(5,646)	(32,927)
Income tax benefit (expense)
[1]	The change in the Federal Tax rate was due to the passage of Public Law 115-97 (Tax Cuts and Jobs Act). This resulted in a provisional reduction of the Company’s deferred tax assets before valuation analysis primarily due to a reduction in the US Statutory rate from 35% to 21%. We will continue to analyze the Tax Cuts and Jobs Act and future associated Treasury Regulations. This future analysis could potentially affect the measurement of deferred tax balances and give rise to new deferred tax amounts.

Income Taxes - Schedule of Ef66

Income Taxes - Schedule of Effective Income Tax (Details) (Parenthetical)	12 Months Ended
	Dec. 31, 2017
Income Tax Disclosure [Abstract]
U.S statutory rate	35.00%
Reduction in U.S statutory rate	21.00%

Income Taxes - Schedule of Defe

Income Taxes - Schedule of Deferred Tax Assets and Liabilities (Details) - USD ($) $ in Thousands		Dec. 31, 2017	Dec. 31, 2016
Income Tax Disclosure [Abstract]
Net operating loss carryover	[1]	$ 874	$ 26,739
Property and equipment		7,123	14,575
Percentage depletion and contribution carryovers	[1]	1,872	2,512
Alternative minimum tax credit carryover	[1]	785	706
Equity method investment and other		398	547
Deferred compensation liability		8	12
Asset retirement obligations		221	377
Stock-based compensation		83	(44)
Total deferred tax assets		11,364	45,424
Property and equipment
Oil price risk derivatives
Other		(3)	(4)
Total deferred tax liabilities		(3)	(4)
Net deferred tax asset		11,361	45,420
Less valuation allowance		(11,361)	(45,420)
Net deferred tax assets
[1]	On December 27, 2017, the Company paid down debt with common stock. This represented a 49.3% ownership change in the company. This combined with other equity events triggered Net Operation Loss limitations under I.R.C Section 382. As a result, the Company’s Net Operating Loss carryforwards were significantly limited.

Income Taxes - Schedule of De68

Income Taxes - Schedule of Deferred Tax Assets and Liabilities (Details) (Parenthetical)	Dec. 27, 2017
Income Tax Disclosure [Abstract]
Ownership interest	49.30%

Loss Per Share - Schedule of Di

Loss Per Share - Schedule of Dilutive Stock Options Computed Using the Treasury Stock (Details) - shares	3 Months Ended																12 Months Ended
	Dec. 31, 2017		Sep. 30, 2017		Jun. 30, 2017		Mar. 31, 2017		Dec. 31, 2016		Sep. 30, 2016		Jun. 30, 2016		Mar. 31, 2016		Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Earnings Per Share [Abstract]
Basic weighted average common shares outstanding	5,899,802		5,834,568		5,834,568		5,834,568		4,768,013		4,768,000		4,705,000		4,705,500		5,899,802	4,768,013	4,677,500
Dilutive stock options using treasury stock method
Diluted weighted average common shares outstanding	5,899,802	[1]	5,834,568	[1]	6,626,344	[1]	5,834,568	[1]	4,768,013	[1]	4,768,000	[1]	4,705,000	[1]	4,705,500	[1]	5,899,802	4,768,013	4,677,500
[1]	Amounts have been restated from amounts reported in previous reports to retroactively present the impact of Discontinued Operations as discussdiscussed further in Note 6.

Loss Per Share - Schedule of An

Loss Per Share - Schedule of Antidilutive Weighted Average Shares (Details) - shares	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Total	395,242	415,357	407,192
Stock Options [Member]
Total	389,687	390,525	390,525
Unvested Shares of Restricted Common Stock [Member]
Total	5,555	24,832	16,667

Significant Concentrations - Sc

Significant Concentrations - Schedule of Company's Oil and Gas Sales (Details) - Sales Revenue, Net [Member]	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Operator A [Member]
Concentration Risk [Line Items]
Joint interest percent	13.00%	16.00%	20.00%
Operator B [Member]
Concentration Risk [Line Items]
Joint interest percent	25.00%	32.00%	35.00%
Operator C [Member]
Concentration Risk [Line Items]
Joint interest percent	34.00%	29.00%	25.00%

Fair Value Measurements (Detail

Fair Value Measurements (Details Narrative) - USD ($) $ / shares in Units, $ in Thousands	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Warrant liability	$ 170	$ (210)
Warrant [Member] | Securities Purchase Agreement [Member]
Term expiration date	Jun. 21, 2022	Jun. 21, 2022
Exercise price	$ 2.05	$ 2.05
Volatility rate	90.00%	90.00%
Risk-free interest rate	2.15%	2.01%
Stock price	$ 1.50
Warrant liability	$ 1,200
Warrant exercise price	$ 1.20

Fair Value Measurements - Sched

Fair Value Measurements - Schedule of Recurring Measurements of the Fair Value of Assets and Liabilities (Details) - USD ($) $ in Thousands	Dec. 31, 2017	Dec. 31, 2016
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Outstanding warrant liability	$ 1,200	$ 1,030
Recurring Measurements [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Marketable equity securities	876	946
Outstanding warrant liability	1,200	1,030
Crude oil price risk derivatives	161
Total	1,361	1,030
Sutter Gold Mining Company [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Marketable equity securities	8	16
Anfield Resources, Inc. [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Marketable equity securities	868	930
Level 1 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Marketable equity securities	868	930
Outstanding warrant liability
Crude oil price risk derivatives
Total
Level 1 [Member] | Sutter Gold Mining Company [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Marketable equity securities
Level 1 [Member] | Anfield Resources, Inc. [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Marketable equity securities	868	930
Level 2 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Marketable equity securities	8	16
Outstanding warrant liability
Crude oil price risk derivatives	161
Total	161
Level 2 [Member] | Sutter Gold Mining Company [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Marketable equity securities	8	16
Level 2 [Member] | Anfield Resources, Inc. [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Marketable equity securities
Level 3 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Marketable equity securities
Outstanding warrant liability	1,200	1,030
Crude oil price risk derivatives
Total	1,200	1,030
Level 3 [Member] | Sutter Gold Mining Company [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Marketable equity securities
Level 3 [Member] | Anfield Resources, Inc. [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Marketable equity securities

Fair Value Measurements - Sch74

Fair Value Measurements - Schedule of Reconciliation of Changes in Assets and Liabilities Measured at Fair Value On a Recurring Basis (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016
Net unrealized gains on oil price risk derivatives	$ 160
Recurring Measurements [Member]
Fair value	1,976	$ 1,302
Acquisition of investment	777	750
Issuance of warrants		1,240
Other comprehensive loss	(8)	3
Net unrealized gains on oil price risk derivatives	(26)
Net unrealized gain on warrant valuation	170	(210)
Net unrealized loss on Anfield Shares	(839)	(58)
Offset of derivative assets and liabilities		(194)
Cash settlements paid	(135)	(857)
Fair value	1,915	1,976
Level 2 [Member] | Recurring Measurements [Member] | Crude Oil Derivative , Assets [Member]
Fair value		1,634
Acquisition of investment
Issuance of warrants
Other comprehensive loss
Net unrealized gains on oil price risk derivatives
Net unrealized gain on warrant valuation
Net unrealized loss on Anfield Shares
Offset of derivative assets and liabilities		(194)
Cash settlements paid		(1,440)
Fair value
Level 2 [Member] | Recurring Measurements [Member] | Crude Oil Derivative , Liabilities [Member]
Fair value
Acquisition of investment
Issuance of warrants
Other comprehensive loss
Net unrealized gains on oil price risk derivatives	(26)
Net unrealized gain on warrant valuation
Net unrealized loss on Anfield Shares
Offset of derivative assets and liabilities
Cash settlements paid	(135)
Fair value	(161)
Level 2 [Member] | Recurring Measurements [Member] | Sutter Gold Mining Company [Member] | Equity Securities [Member]
Fair value	16	13
Acquisition of investment
Issuance of warrants
Other comprehensive loss	(8)	3
Net unrealized gains on oil price risk derivatives
Net unrealized gain on warrant valuation
Net unrealized loss on Anfield Shares
Offset of derivative assets and liabilities
Cash settlements paid
Fair value	8	16
Level 1 [Member] | Recurring Measurements [Member] | Anfield [Member] | Equity Securities [Member]
Fair value	930	238
Acquisition of investment	777	750
Issuance of warrants
Other comprehensive loss
Net unrealized gains on oil price risk derivatives
Net unrealized gain on warrant valuation
Net unrealized loss on Anfield Shares	(839)	(58)
Offset of derivative assets and liabilities
Cash settlements paid
Fair value	868	930
Level 3 [Member] | Recurring Measurements [Member] | Executive Retirement Programme Liabilities [Member]
Fair value		(583)
Acquisition of investment
Issuance of warrants
Other comprehensive loss
Net unrealized gains on oil price risk derivatives
Net unrealized gain on warrant valuation
Net unrealized loss on Anfield Shares
Offset of derivative assets and liabilities
Cash settlements paid		583
Fair value
Level 3 [Member] | Recurring Measurements [Member] | Warrant Liability [Member]
Fair value	1,030
Acquisition of investment
Issuance of warrants		1,240
Other comprehensive loss
Net unrealized gains on oil price risk derivatives
Net unrealized gain on warrant valuation	170	(210)
Net unrealized loss on Anfield Shares
Offset of derivative assets and liabilities
Cash settlements paid
Fair value	$ 1,200	$ 1,030

Unaudited Supplemental Oil an75

Unaudited Supplemental Oil and Gas Information - Schedule of Proved Oil and Gas Reserves and Changes in Net Proved Reserves (Details) - bbl		12 Months Ended
		Dec. 31, 2017		Dec. 31, 2016		Dec. 31, 2015
Oil (bbls) [Member]
Reserve quantities, beginning of year		657,280		1,615,180		4,119,736
Revisions of previous estimates		302,530		(795,459)		(2,377,364)
Discoveries and extensions		22,801		23,841		94,458
Sale of minerals in place		(194,667)		(53,853)
Production		(111,914)		(132,429)		(221,650)
Reserve quantities, end of year		676,030		657,280		1,615,180
Proved developed reserves, end of year		676,030		657,280		1,248,750
Natural Gas (mcfe) [Member]
Reserve quantities, beginning of year	[1],[2]	1,379,163
Revisions of previous estimates	[2]	55,072
Discoveries and extensions	[2]	21,787
Sale of minerals in place	[2]	(118,944)
Production	[2]	(448,571)
Reserve quantities, end of year	[2]	888,507		1,379,163	[1]
Proved developed reserves, end of year	[2]	888,507
Natural Gas (mcfe) [Member]
Reserve quantities, beginning of year	[2]	1,379,163	[1]	2,477,930		3,211,245
Revisions of previous estimates	[2]			(584,494)		(206,912)
Discoveries and extensions	[2]			20,336		27,105
Sale of minerals in place	[2]			(57,258)
Production	[2]			(477,351)		(553,505)
Reserve quantities, end of year	[2]			1,379,163	[1]	2,477,930
Proved developed reserves, end of year				1,379,163	[1]	2,068,190	[2]
[1]	Consists of the weighted average price for natural gas in mcf plus NGL’s converted to mcf using a factor of 6 mcf for each barrel of NGL.
[2]	Mcf equivalents (Mcfe) consist of natural gas reserves in mcf plus NGLs converted to mcf using a factor of 6 mcf for each barrel of NGL.

Unaudited Supplemental Oil an76

Unaudited Supplemental Oil and Gas Information - Schedule of Prices as Adjusted for Transportation, Quality (Details)		12 Months Ended
		Dec. 31, 2017$ / bbl$ / Mcf	Dec. 31, 2016$ / bbl$ / Mcf	Dec. 31, 2015$ / bbl$ / Mcf
Oil (bbls) [Member]
Sales Prices | $ / bbl		51.34	42.75	43.54
Natural Gas (mcfe) [Member]
Sales Prices		2.98
Natural Gas (mcfe) [Member]
Sales Prices	[1]	2.98	2.48	3.36
[1]	Consists of the weighted average price for natural gas in mcf plus NGL’s converted to mcf using a factor of 6 mcf for each barrel of NGL.

Unaudited Supplemental Oil an77

Unaudited Supplemental Oil and Gas Information - Schedule of Standardized Measure of Discounted Future Net Cash Flows (Details) - USD ($) $ in Thousands	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Oil and Gas Exploration and Production Industries Disclosures [Abstract]
Future cash inflows	$ 34,424	$ 27,769	$ 78,646
Production costs	(18,518)	(18,814)	(44,685)
Development costs			(8,050)
Income taxes
Future net cash flows	15,906	8,955	25,911
10% annual discount factor	(6,653)	(2,208)	(8,143)
Standardized measure of discounted future net cash flows	$ 9,253	$ 6,747	$ 17,768	$ 81,889

Unaudited Supplemental Oil an78

Unaudited Supplemental Oil and Gas Information - Schedule of Standardized Measure of Future Net Cash Flows (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Oil and Gas Exploration and Production Industries Disclosures [Abstract]
Standardized measure, beginning of year	$ 6,747	$ 17,768	$ 81,889
Sales of oil and gas, net of production costs	(3,143)	(3,102)	(2,944)
Net changes in prices and production costs	2,347	(9,248)	(96,586)
Changes in estimated future development costs		6,590	51,998
Extensions and discoveries	511	167	2,260
Sale of minerals in place	(1,049)	(78)
Revisions in previous quantity estimates	3,416	(6,791)	(27,693)
Previously estimated development costs incurred
Net changes in income taxes			3,306
Accretion of discount	675	1,777	8,189
Changes in timing and other	(251)	(336)	(2,651)
Standardized measure, end of year	$ 9,253	$ 6,747	$ 17,768

Quarterly Financial Data (Una79

Quarterly Financial Data (Unaudited) - Schedule of Quarterly Financial Information (Details) - USD ($) $ / shares in Units, $ in Thousands		3 Months Ended																12 Months Ended
		Dec. 31, 2017		Sep. 30, 2017		Jun. 30, 2017		Mar. 31, 2017		Dec. 31, 2016		Sep. 30, 2016		Jun. 30, 2016		Mar. 31, 2016		Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Quarterly Financial Information Disclosure [Abstract]
Oil and gas sales		$ 12,687		$ 1,538		$ 1,992		$ 1,747		$ 817		$ 1,867		$ 1,996		$ 1,066		$ 6,545	$ 5,746	$ 10,296
Impairment of oil and gas properties														(2,611)		(6,957)			9,568	57,676
Other	[1]	(1,451)		(1,601)		(1,996)		(2,485)		276		(2,761)		(3,061)		(2,561)
Operating income		(183)	[1]	(63)	[1]	(4)	[1]	(738)	[1]	1,093	[1]	(894)	[1]	(3,676)	[1]	(8,452)	[1]	(988)	(11,929)	(69,064)
Income (loss) from continuing operations		98	[1]	(382)	[1]	(336)	[1]	(740)	[1]	1,074	[1]	(265)	[1]	(4,206)	[1]	(8,275)	[1]	(1,360)	(11,672)	(67,284)
Discontinued operations										(111)				(10)		(2,327)			(2,448)	(25,612)
Net income (loss)		$ 983		$ (382)		$ (336)		$ (740)		$ 963		$ (265)		$ (4,216)		$ (10,602)		$ (1,360)	$ (14,120)	$ (92,896)
Income (loss) per share - basic, Continuing operations	[1],[2]	$ 0.02		$ (0.06)		$ (0.02)		$ (0.13)		$ 0.23		$ (0.06)		$ (0.90)		$ (1.76)
Income (loss) per share - basic, Discontinued operations	[1],[2]													0		(0.49)
Income (loss) per share - basic, Total	[1],[2]	0.02		(0.06)		(0.02)		(0.13)		0.23		(0.06)		(0.90)		(2.25)
Income (loss) per share - diluted, Continuing operations	[1],[2]	0.02		(0.06)		(0.02)		(0.13)		0.23		(0.06)		(0.90)		(1.76)
Income (loss) per share - diluted, Discontinued operations	[1],[2]													0		(0.49)
Income (loss) per share - diluted, Total	[1],[2]	$ 0.02		$ (0.06)		$ (0.02)		$ (0.13)		$ 0.23		$ (0.06)		$ (0.90)		$ (2.25)
Weighted average shares outstanding: Basic		5,899,802		5,834,568		5,834,568		5,834,568		4,768,013		4,768,000		4,705,000		4,705,500		5,899,802	4,768,013	4,677,500
Weighted average shares outstanding: Diluted		5,899,802	[1]	5,834,568	[1]	6,626,344	[1]	5,834,568	[1]	4,768,013	[1]	4,768,000	[1]	4,705,000	[1]	4,705,500	[1]	5,899,802	4,768,013	4,677,500
[1]	Amounts have been restated from amounts reported in previous reports to retroactively present the impact of Discontinued Operations as discussdiscussed further in Note 6.
[2]	Earnings per share amounts may not sum due to rounding.

Subsequent Events (Details Narr

Subsequent Events (Details Narrative) $ in Thousands	Jan. 05, 2018USD ($)
Subsequent Event [Member] | Maximum [Member]
Proceeds from aggregated offering price	$ 2,500