Sow Good (SOWG) 10-Q 15 Aug 16 2016 Q2 Quarterly report Financial data

Document and Entity Information

Document and Entity Information - shares	6 Months Ended
	Jun. 30, 2016	Aug. 12, 2016
Document And Entity Information
Entity Registrant Name	Black Ridge Oil & Gas, Inc.
Entity Central Index Key	1,490,161
Document Type	10-Q
Document Period End Date	Jun. 30, 2016
Amendment Flag	false
Current Fiscal Year End Date	--12-31
Is Entity a Well-known Seasoned Issuer?	No
Is Entity a Voluntary Filer?	No
Is Entity's Reporting Status Current?	Yes
Entity Filer Category	Smaller Reporting Company
Entity Common Stock, Shares Outstanding		47,979,990
Document Fiscal Period Focus	Q2
Document Fiscal Year Focus	2,016

CONDENSED BALANCE SHEETS (Unaud

CONDENSED BALANCE SHEETS (Unaudited) - USD ($)	Jun. 30, 2016	Dec. 31, 2015
Current assets:
Cash and cash equivalents	$ 1,038,567	$ 228,194
Prepaid expenses	67,621	0
Current assets from discontinued operations	0	6,229,646
Total current assets	1,106,188	6,457,840
Property and equipment:
Property and equipment	139,004	139,004
Less accumulated depreciation	(105,221)	(97,857)
Total property and equipment, net	33,783	41,147
Investment in Blackridge Holding Company, LLC	52,853	0
Non-current assets from discontinued operations	0	31,808,230
Total assets	1,192,824	38,307,217
Current liabilities:
Current liabilities from discontinued operations	0	68,312,897
Accounts payable	114,106	0
Due to Black Ridge Holding Company, LLC	967,141	0
Accrued expenses	3,404	0
Total current liabilities	1,084,651	68,312,897
Noncurrent liabilities from discontinued operations	0	368,089
Total liabilities	1,084,651	68,680,986
Commitments and contingencies (See note 17)
Stockholders' equity (deficit):
Preferred stock, $0.001 par value, 20,000,000 shares authorized, no shares issued and outstanding	0	0
Common stock, $0.001 par value, 500,000,000 shares authorized, 47,979,990 shares issued and outstanding	47,980	47,980
Additional paid-in capital	34,591,062	34,275,414
Accumulated deficit	(34,530,869)	(64,697,163)
Total stockholders' equity (deficit)	108,173	(30,373,769)
Total liabilities and stockholders' equity (deficit)	$ 1,192,824	$ 38,307,217

CONDENSED BALANCE SHEETS (Unau3

CONDENSED BALANCE SHEETS (Unaudited) (Parenthetical) - $ / shares	Jun. 30, 2016	Dec. 31, 2015
Stockholders' equity:
Preferred stock, par value (in Dollars per share)	$ 0.001	$ 0.001
Preferred stock, shares authorized	20,000,000	20,000,000
Preferred stock, shares issued	0	0
Preferred stock, shares outstanding	0	0
Common stock, par value (in Dollars per share)	$ 0.001	$ 0.001
Common stock, shares authorized	500,000,000	500,000,000
Common stock, shares issued	47,979,990	47,979,990
Common stock, shares outstanding	47,979,990	47,979,990

CONDENSED STATEMENTS OF OPERATI

CONDENSED STATEMENTS OF OPERATIONS (Unaudited) - USD ($)	3 Months Ended		6 Months Ended
	Jun. 30, 2016	Jun. 30, 2015	Jun. 30, 2016	Jun. 30, 2015
Income Statement [Abstract]
Management fee income	$ 49,451	$ 0	$ 49,451	$ 0
Total revenues	49,451	0	49,451	0
Operating expenses:
General and administrative	614,661	645,837	1,299,569	1,332,724
Depreciation and amortization	3,479	4,009	7,364	8,276
Total operating expenses	618,140	649,846	1,306,933	1,341,000
Net operating income (loss)	(568,689)	(649,846)	(1,257,482)	(1,341,000)
Other income (expense):
Other income	0	6,707	0	6,707
Gain on debt restructuring	41,621,150	0	41,621,150	0
Total other income (expense)	41,621,150	6,707	41,621,150	6,707
Income (loss) before provision for income taxes	41,052,461	(643,139)	40,363,668	(1,334,293)
Provision for income taxes	0	0	0	0
Income (loss) from continuing operations, net of income taxes	41,052,461	(643,139)	40,363,668	(1,334,293)
Loss from discontinued operations, net of income taxes	(2,970,654)	(18,026,499)	(10,197,374)	(18,608,281)
Net income (loss)	$ 38,081,807	$ (18,669,638)	$ 30,166,294	$ (19,942,574)
Weighted average common shares outstanding - basic	47,979,990	47,979,990	47,979,990	47,979,990
Weighted average common shares outstanding - fully diluted	48,058,679	47,979,990	48,056,573	47,979,990
Net income (loss) per common share - basic	$ 0.79	$ (.39)	$ .63	$ (.42)
Net income (loss) per common share - fully diluted	$ 0.79	$ (0.39)	$ 0.63	$ (0.42)

CONDENSED STATEMENTS OF CASH FL

CONDENSED STATEMENTS OF CASH FLOWS (Unaudited) - USD ($)	6 Months Ended
	Jun. 30, 2016	Jun. 30, 2015
CASH FLOWS FROM OPERATING ACTIVITIES
Net income (loss)	$ 30,166,294	$ (19,942,574)
Loss from discontinued operations, net of taxes	(10,197,374)	(18,608,281)
Income (loss) from continuing operations, net of income taxes	40,363,668	(1,334,293)
Adjustments to reconcile net income (loss) to net cash provided by operating activities:
Depreciation and amortization	7,364	8,276
Gain on debt restructuring	(41,621,150)	0
Common stock options issued to employees and directors	315,648	313,751
Decrease (increase) in current assets:
Prepaid expenses	(30,521)	(5,470)
Increase (decrease) in current liabilities:
Accounts payable	87,892	18,553
Due to Black Ridge Holding Company , LLC	967,141	0
Accrued expenses	4,114	30,441
Net cash provided by (used in ) operating activities from continuing operations	94,156	(968,742)
Net cash provided by operating activities from discontinued operations	3,829,723	6,512,822
Net cash provided by operating activities	3,923,879	5,544,080
CASH FLOWS FROM INVESTING ACTIVITIES
Net cash used in investing activities from continuing operations	0	0
Net cash used in investing activities from discontinued operations	(4,763,506)	(12,574,179)
Net cash used in investing activities	(4,763,506)	(12,574,179)
CASH FLOWS FROM FINANCING ACTIVITIES
Net cash used in financing activities from continuing operations	0	0
Net cash used in financing activities from discontinued operations	1,650,000	7,150,000
Net cash provided by financing activities	1,650,000	7,150,000
NET CHANGE IN CASH	810,373	119,901
CASH AT BEGINNING OF PERIOD	228,194	94,682
CASH AT END OF PERIOD	1,038,567	214,583
SUPPLEMENTAL INFORMATION:
Interest paid	1,429,564	2,174,153
Income taxes paid	0	0
NON-CASH INVESTING AND FINANCING ACTIVITIES:
Investment in Black Ridge Holding Company, LLC	(41,568,297)	0
Net change in accounts payable for purchase of oil and gas properties	(3,744,487)	(161,409)
Capitalized asset retirement costs, net of revision in estimate	$ 4,737	$ 41,965

1. Organization and Nature of B

1. Organization and Nature of Business	6 Months Ended
	Jun. 30, 2016
Organization, Consolidation and Presentation of Financial Statements [Abstract]
Organization and Nature of Business	Effective April 2, 2012, Ante5, Inc. changed its corporate name to Black Ridge Oil & Gas, Inc., and continues to be quoted on the OTCQB under the trading symbol “ANFC”. Black Ridge Oil & Gas, Inc. (formerly Ante5, Inc.) (the “Company”) became an independent company in April 2010. We became a publicly traded company when our shares began trading on July 1, 2010. Since October 2010, we had been engaged in the business of acquiring oil and gas leases and participating in the drilling of wells in the Bakken and Three Forks trends in North Dakota and Montana. On June 21, 2016 we closed on a debt restructuring transaction with our secured lenders as described in Note 4 – Debt Restructuring. Following the transaction, our focus is on managing the oil and gas assets in which we will continue to have an indirect minority interest. In addition, we will continue to pursue distressed asset acquisitions in the Bakken and/or Three Forks and other formations that may be acquired with capital from our secured lenders as part of the restructuring terms, existing joint venture partners or other capital providers.

2. Basis of Presentation and Si

2. Basis of Presentation and Significant Accounting Policies	6 Months Ended
	Jun. 30, 2016
Accounting Policies [Abstract]
Basis of Presentation and Significant Accounting Policies	The interim condensed financial statements included herein, presented in accordance with United States generally accepted accounting principles and stated in US dollars, have been prepared by the Company, without audit, pursuant to the rules and regulations of the Securities and Exchange Commission. Certain information and footnote disclosures normally included in financial statements prepared in accordance with generally accepted accounting principles have been condensed or omitted pursuant to such rules and regulations, although the Company believes that the disclosures are adequate to not make the information presented misleading. These statements reflect all adjustments, which in the opinion of management, are necessary for fair presentation of the information contained therein. Except as otherwise disclosed, all such adjustments are of a normal recurring nature. It is suggested that these interim condensed financial statements be read in conjunction with the audited financial statements for the year ended December 31, 2015, which were included in our Annual Report on Form 10-K. The Company follows the same accounting policies in the preparation of interim reports. Reclassifications In the current year, the Company classified assets and liabilities subject to our restructuring transaction outlined in Note 4 – Restructuring as assets and liabilities from discontinued operations in the balance sheet and income, expense and cash flows from the restructured operations are shown as net income and cash flows from discontinued operations. For comparative purposes, amounts in the prior periods have been reclassified to conform to current year presentation. Use of Estimates The preparation of financial statements in conformity with generally accepted accounting principles requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities and disclosure of contingent assets and liabilities at the date of the financial statements and the reported amount of revenues and expenses during the reporting period. Actual results could differ from those estimates. Environmental Liabilities The oil and gas industry is subject, by its nature, to environmental hazards and clean-up costs. At this time, management knows of no substantial losses from environmental accidents or events which would have a material effect on the Company. Cash and Cash Equivalents Cash equivalents include money market accounts which have maturities of three months or less. For the purpose of the statements of cash flows, all highly liquid investments with an original maturity of three months or less are considered to be cash equivalents. Cash equivalents are stated at cost plus accrued interest, which approximates market value. No cash equivalents were on hand at June 30, 2016 and December 31, 2015. Cash in Excess of FDIC Insured Limits The Company maintains its cash in bank deposit accounts which, at times, may exceed federally insured limits. Accounts are guaranteed by the Federal Deposit Insurance Corporation (FDIC) and the Securities Investor Protection Corporation (SIPC) up to $250,000 and $500,000, respectively, under current regulations. The Company had approximately $538,567 and $-0- in excess of FDIC and SIPC insured limits at June 30, 2016 and December 31, 2015, respectively. The Company has not experienced any losses in such accounts. Advances to Operators The Company participates in the drilling of crude oil and natural gas wells with other working interest partners. Due to the capital intensive nature of crude oil and natural gas drilling activities, the working interest partner responsible for conducting the drilling operations may request advance payments from other working interest partners for their share of the costs. The Company expects such advances to be applied by working interest partners against joint interest billings for its share of the drilling operations within 120 days from when the advance is paid. Debt Issuance Costs Costs relating to obtaining our revolving credit facilities are capitalized and amortized over the term of the related debt using the straight-line method. The unamortized balance of debt issuance costs at June 30, 2016, and December 31, 2015, was $-0-. Amortization of debt issuance costs charged to interest expense were $-0- and $190,780 for the six months ended June 30, 2016 and 2015, respectively. Interest expense related to debt issuance costs is reflected as part of loss from discontinued operations on the statement of operations. When a loan is paid in full or becomes due on demand due to a default on the loan any unamortized financing costs are removed from the related accounts and charged to interest expense. Website Development Costs The Company accounts for website development costs in accordance with ASC 350-50, “Accounting for Website Development Costs” (“ASC 350-50”), wherein website development costs are segregated into three activities: 1) Initial stage (planning), whereby the related costs are expensed. 2) Development (web application, infrastructure, graphics), whereby the related costs are capitalized and amortized once the website is ready for use. Costs for development content of the website may be expensed or capitalized depending on the circumstances of the expenditures. 3) Post-implementation (after site is up and running: security, training, admin), whereby the related costs are expensed as incurred. Upgrades are usually expensed, unless they add additional functionality. We have capitalized a total of $56,660 of website development costs from inception through June 30, 2016. We depreciate our website development costs on a straight line basis over the estimated useful life of the assets, which is currently three years. We have recognized depreciation expense on these website costs of $-0- and $257 for the six months ended June 30, 2016 and 2015, respectively. As of June 30, 2016, all website development costs have been fully depreciated. Income Taxes The Company recognizes deferred tax assets and liabilities based on differences between the financial reporting and tax basis of assets and liabilities using the enacted tax rates and laws that are expected to be in effect when the differences are expected to be recovered. The Company provides a valuation allowance for deferred tax assets for which it does not consider realization of such assets to be more likely than not. Basic and Diluted Loss Per Share The basic net loss per share is computed by dividing the net loss (the numerator) by the weighted average number of common shares outstanding for the period (the denominator). Diluted net loss per common share is computed by dividing the net loss by the weighted average number of common shares and potential common shares outstanding (if dilutive) during each period. Potential common shares include stock options, warrants and restricted stock. The number of potential common shares outstanding relating to stock options, warrants and restricted stock is computed using the treasury stock method. The reconciliation of the denominators used to calculate basic EPS and diluted EPS for the three and six months ended June 30, 2016 and 2015 are as follows: Three Months Ended Six Months Ended June 30, June 30, 2016 2015 2016 2015 Weighted average common shares outstanding – basic 47,979,990 47,979,990 47,979,990 47,979,990 Plus: Potentially dilutive common shares: Stock options and warrants 78,689 – 76,583 – Weighted average common shares outstanding – diluted 48,058,679 47,979,990 48,056,573 47,979,990 Stock options and warrants excluded from the calculation of diluted EPS because their effect was anti-dilutive were 9,954,875 and 16,275,542 for the three months ended June 30, 2016 and 2015, respectively, and 9,954,875 and 16,275,542 for the six months ended June 30, 2016 and 2015, respectively. Fair Value of Financial Instruments Under FASB ASC 820-10-05, the Financial Accounting Standards Board establishes a framework for measuring fair value in generally accepted accounting principles and expands disclosures about fair value measurements. This Statement reaffirms that fair value is the relevant measurement attribute. The adoption of this standard did not have a material effect on the Company’s financial statements as reflected herein. The carrying amounts of cash, accounts payable and accrued expenses reported on the balance sheets are estimated by management to approximate fair value primarily due to the short term nature of the instruments. The Company had no items that required fair value measurement on a recurring basis. Property and Equipment Property and equipment that are not oil and gas properties are recorded at cost and depreciated using the straight-line method over their estimated useful lives of three to seven years. Expenditures for replacements, renewals, and betterments are capitalized. Maintenance and repairs are charged to operations as incurred. Long-lived assets, other than oil and gas properties, are evaluated for impairment to determine if current circumstances and market conditions indicate the carrying amount may not be recoverable. The Company has not recognized any impairment losses on non-oil and gas long-lived assets. Depreciation expense was $7,364 and $8,276 for the six months ended June 30, 2016 and 2015, respectively. Revenue Recognition The Company recognizes oil and gas revenues from its interests in producing wells when production is delivered to, and title has transferred to, the purchaser and to the extent the selling price is reasonably determinable. The Company uses the sales method of accounting for gas balancing of gas production and would recognize a liability if the existing proven reserves were not adequate to cover an imbalance situation. Oil and gas revenues are reflected as part of discontinued operations on the statement of operations. Asset Retirement Obligations The Company records the fair value of a liability for an asset retirement obligation in the period in which the well is spud or the asset is acquired and a corresponding increase in the carrying amount of the related long-lived asset. The liability is accreted to its present value each period, and the capitalized cost is depreciated over the useful life of the related asset. If the liability is settled for an amount other than the recorded amount, a gain or loss is recognized. The capitalized cost and asset retirement obligation as of December 31, 2015 and the expense related to accretion of the discount on the asset retirement liability are reflected as part of discontinued operations on the balance sheet and statement of operations. Full Cost Method The Company follows the full cost method of accounting for oil and gas operations whereby all costs related to the exploration and development of oil and gas properties are initially capitalized into a single cost center ("full cost pool"). Such costs include land acquisition costs, geological and geophysical expenses, carrying charges on non-producing properties, costs of drilling directly related to acquisition, and exploration activities. Internal costs that are capitalized are directly attributable to acquisition, exploration and development activities and do not include costs related to the production, general corporate overhead or similar activities. Costs associated with production and general corporate activities are expensed in the period incurred. Capitalized costs are summarized as follows for the six months ended June 30, 2016 and 2015, respectively: Six Months Ended June 30, 2016 2015 Capitalized Certain Payroll and Other Internal Costs $ – $ – Capitalized Interest Costs 7,219 295,331 Total $ 7,219 $ 295,331 Proceeds from sales of proved properties will generally be credited to the full cost pool, with no gain or loss recognized, unless such a sale would significantly alter the relationship between capitalized costs and the proved reserves attributable to these costs. A significant alteration would typically involve a sale of 20% or more of the proved reserves related to a single full cost pool. The Company assesses all items classified as unevaluated property on a quarterly basis for possible impairment or reduction in value. The assessment includes consideration of the following factors, among others: intent to drill; remaining lease term; geological and geophysical evaluations; drilling results and activity; the assignment of proved reserves; and the economic viability of development if proved reserves are assigned. During any period in which these factors indicate an impairment, the cumulative drilling costs incurred to date for such property and all or a portion of the associated leasehold costs are transferred to the full cost pool and are then subject to amortization. Capitalized costs associated with impaired properties and properties having proved reserves, estimated future development costs, and asset retirement costs under FASB ASC 410-20-25 are depleted and amortized on the unit-of-production method based on the estimated gross proved reserves as determined by independent petroleum engineers. The costs of unproved properties are withheld from the depletion base until such time as they are either developed or abandoned. Capitalized costs of oil and gas properties (net of related deferred income taxes) may not exceed an amount equal to the present value, discounted at 10% per annum, of the estimated future net cash flows from proved oil and gas reserves plus the cost of unproved properties (adjusted for related income tax effects). Should capitalized costs exceed this ceiling, impairment is recognized. The present value of estimated future net cash flows is computed by applying the arithmetic average first day price of oil and natural gas for the preceding twelve months to estimated future production of proved oil and gas reserves as of the end of the period, less estimated future expenditures to be incurred in developing and producing the proved reserves and assuming continuation of existing economic conditions. Such present value of proved reserves' future net cash flows excludes future cash outflows associated with settling asset retirement obligations. Should this comparison indicate an excess carrying value, the excess is charged to earnings as an impairment expense. As a result of currently prevailing low commodity prices and their effect on the proved reserve values of properties throughout 2015 and 2016, we recorded non-cash ceiling test impairments of $5,219,000 and $21,639,000 for the six months ended June 30, 2016 and 2015, respectively. The impairment charges affected our reported net income but did not reduce our cash flow. The impairment charges are reflected as part of discontinued operations on the statement of operations. Stock-Based Compensation The Company adopted FASB guidance on stock based compensation upon inception at April 9, 2010. Under FASB ASC 718-10-30-2, all share-based payments to employees, including grants of employee stock options, are recognized in the income statement based on their fair values. Expense related to common stock and stock options issued for services and compensation totaled $315,648 and $313,751 for the six months ended June 30, 2016 and 2015, respectively, using the Black-Scholes options pricing model and an effective term of 6 to 6.5 years based on the weighted average of the vesting periods and the stated term of the option grants and the discount rate on 5 to 7 year U.S. Treasury securities at the grant date. In addition, $-0- and $321,763 of warrant related debt discounts were amortized during the six months ended June 30, 2016 and 2015, respectively, and treated as interest expense and reflected as part of discontinued operations on the statement of operation. The fair value of warrants is determined similar to the method used in determining the fair value of employee stock options and the fair value is amortized over the life of the related credit facility and accelerated in the event of termination of the related credit facility or if the related credit facility becomes payable on demand due to a default on the related credit facility. The amortization of the debt discount attributable to the warrants was accelerated in 2015 to fully amortize the discount as of December 31, 2015 when the related debt became payable on demand due to a default on the related debt. As part of the debt restructuring all related warrants were retired and cancelled. Uncertain Tax Positions Effective upon inception at April 9, 2010, the Company adopted standards for accounting for uncertainty in income taxes. These standards prescribe a recognition threshold and measurement attribute for the financial statement recognition and measurement of a tax position taken or expected to be taken in a tax return. These standards also provide guidance on de-recognition, classification, interest and penalties, accounting in interim periods, disclosure, and transition. Various taxing authorities may periodically audit the Company’s income tax returns. These audits include questions regarding the Company’s tax filing positions, including the timing and amount of deductions and the allocation of income to various tax jurisdictions. In evaluating the exposures connected with these various tax filing positions, including state and local taxes, the Company records allowances for probable exposures. A number of years may elapse before a particular matter, for which an allowance has been established, is audited and fully resolved. Black Ridge Oil & Gas, Inc. has not yet undergone an examination by any taxing authorities. The assessment of the Company’s tax position relies on the judgment of management to estimate the exposures associated with the Company’s various filing positions. Derivative Instruments and Price Risk Management The Company enters into derivative contracts, including price swaps, caps and floors, which require payments to (or receipts from) counterparties based on the differential between a fixed price and a variable price for a fixed quantity of crude oil without the exchange of underlying volumes. The notional amounts of these financial instruments are based on a portion of the expected production from existing wells. The Company has, and may continue to use exchange traded futures contracts and option contracts to hedge the delivery price of crude oil at a future date. Any realized gains and losses are recorded to gain (loss) on settled derivatives and unrealized gains or losses as a result of mark-to market valuations are recorded to gain (loss) on the mark-to-market of derivatives on the statements of operations. Recent Accounting Pronouncements New accounting pronouncements are issued by the Financial Accounting Standards Board (“FASB”) that are adopted by the Company as of the specified effective date. If not discussed below, management believes there have been no developments to recently issued accounting standards, including expected dates of adoption and estimated effects on our financial statements, from those disclosed in our Annual Report on Form 10-K for the year ended December 31, 2015. In November 2015, the Financial Accounting Standards Board (“FASB”) issued Accounting Standards Update (“ASU”) 2015-17, Balance Sheet Classification of Deferred Taxes, which eliminates the current requirement to present deferred tax liabilities and assets as current and noncurrent amounts in a classified statement of financial position. Instead, entities will be required to classify all deferred tax assets and liabilities as noncurrent in a statement of financial position. This standard is effective financial statements issued for annual periods beginning after December 15, 2016, and interim periods within those annual periods. Early application is permitted. The Company elected early application of this ASU as of December 31, 2015, and has applied its provisions prospectively. In April 2015, the FASB issued ASU No. 2015-03, Interest–Imputation of Interest (Subtopic 835-30)

3. Going Concern

3. Going Concern	6 Months Ended
	Jun. 30, 2016
Organization, Consolidation and Presentation of Financial Statements [Abstract]
Going Concern	In August 2014, the FASB issued ASU No. 2014-15, "Presentation of Financial Statements - Going Concern (Subtopic 205-40)". The Company chose to adopt this pronouncement in 2015 due to the applicability to our current condition. The new guidance addresses management's responsibility to evaluate whether there is substantial doubt about an entity's ability to continue as a going concern and in certain circumstances to provide related footnote disclosures. As shown in the accompanying financial statements, the Company has incurred losses from operations resulting in an accumulated deficit of ($34,530,869) as of June 30, 2016, which was reduced in the current quarter by a gain on debt restructuring of $41,621,150. While the debt restructuring outlined in Note 4 – Debt Restructuring leaves the Company debt free, it also eliminated the asset base from which the Company derived the majority of its cash flow. The management fees from the management agreement entered into as part of the debt restructuring should be sufficient to cover the Company’s overhead costs for the balance of 2016. However, the management agreement can be cancelled by either party without penalty after January 1, 2017. While the Company is actively working to secure additional joint ventures with assets to manage, to date the Company has not found other sources of revenue. These factors raise substantial doubt about the Company’s ability to continue as a going concern. The financial statements do not include any adjustments that might result from the outcome of any uncertainty as to the Company’s ability to continue as a going concern. These financial statements also do not include any adjustments relating to the recoverability and classification of recorded asset amounts, or amounts and classifications of liabilities that might be necessary should the Company be unable to continue as a going concern.

4. Debt Restructuring

4. Debt Restructuring	6 Months Ended
	Jun. 30, 2016
Restructuring and Related Activities [Abstract]
4. Debt Restructuring	On March 29, 2016, the Company entered into an Asset Contribution Agreement with Black Ridge Holding Company, LLC, a Delaware limited liability company (“BRHC”) which was recently formed by the Company to contribute and assign to BRHC, all of the Company's (i) oil and gas assets (including working capital and tangible and intangible assets) (the “Assets”), (ii) outstanding balances under that certain Credit Agreement between the Company, as borrower, and Cadence Bank, N.A. (“Cadence”), as lender (the “Cadence Credit Facility”) and the outstanding balances under that certain Credit Agreement between the Company, as borrower, and the several banks and other financial institutions or entities from time to time parties thereto (the “Chambers”), and Chambers, as administrative agent (the “Chambers Credit Facility”) and (iii) all current liabilities related to the Assets, in exchange for 5% of the issued and outstanding Class A Units (the “Class A Units”) in BRHC (the “Asset Contribution”). On March 29, 2016, affiliates of Chambers Energy Management, LP (“Chambers”) (specifically, Chambers Energy Capital II, LP and CEC II TE, LLC (collectively, the “Chambers Affiliates”)) entered into a Debt Contribution Agreement between BRHC and the Chambers Affiliates, pursuant to which BRHC will issue a number of Class A Units representing 95% of the Class A Units of BRHC to the Chambers Affiliates in exchange for the release of BRHC's obligations under the Chambers Credit Facility (the “Satisfaction of Debt” and, together with the Asset Contribution, the “BRHC Transaction”). Concurrent with the Satisfaction of Debt, each warrant originally issued with the Chambers Credit Facility was automatically retired and cancelled. The closing of the BRHC Transaction was subject to the Company obtaining the approval of stockholders holding a majority of its outstanding capital stock and to the Company having assigned the Cadence Credit Agreement to BRHC with Cadence’s consent, and BRHC and Cadence entering into any applicable amendment agreements related to such assignment and waiver of financial covenant ratio compliance for the quarter ended December 31, 2015 and quarter ending March 31, 2016. On June 21, 2016, the Company satisfied all of these conditions and, for accounting purposes, the BRHC Transaction was closed. The parties have agreed that the BRHC Transaction, the Asset Contribution and the Satisfaction of Debt are effective, for valuation purposes, as of April 1, 2016. The terms of the Class A Units of BRHC are set forth in the limited liability company agreement of BRHC (the “LLC Agreement”), which became effective upon the closing of the BRHC Transaction. All distributions by BRHC of cash or other property, and whether upon liquidation or otherwise, will be made as follows: · First, 100% to the Class A Members, pro rata, until each Class A Member has received distributions in aggregate totaling the then Class A Preference, which is an amount equal to a 10.0% internal rate of return on the invested capital amount. · Second, 90% to the Class A Members, pro rata, and 10% to the Class B Members, pro rata, until such time as the aggregate distributions to Chambers equals 250% of the capital contribution of its Class A Units. · Third, 80% to the Class A Members, pro rata, and 20% to the Class B Members, pro rata. BRHC will be managed by the BRHC Board, which will be responsible for the conduct of the day-to-day business of BRHC and the management, oversight and disposition of the assets of BRHC. The initial BRHC Board will be comprised of three managers, consisting of two managers appointed by Chambers and one member from the Company. In addition, under the LLC Agreement, Chambers committed to contribute up to $30 million cash (the “Chambers Investment Commitment”) to BRHC in exchange for Class A Units. At Closing, Chambers funded $10 million (the “Initial Chambers Investment”) of the Chambers Investment Commitment, the proceeds of which were used to reduce outstanding amounts owed by BRHC to Cadence under the Cadence Credit Facility and for general corporate purposes. The remaining $20 million (the “Subsequent Chambers Investment”), subject to certain conditions, may be called from time to time during the Investment Period by the board of managers of BRHC (the “BRHC Board”). The Initial Chambers Investment and any Subsequent Chambers Investment shall serve to proportionately reduce the Company's Class A Units percentage ownership in BRHC. The investment period shall be the lesser of three years or such time as the entire Chambers Investment Commitment has been called by the BRHC Board (the “Investment Period”). Any portion of Chambers Investment Commitment not called by the BRHC Board prior to the expiration of the Investment Period will be cancelled. In no event will Chambers be required to make a capital contribution in an amount in excess of its undrawn commitment. The Company was granted 1,000,000 Class B Units in BRHC at the Closing of the BRHC Transaction. At the discretion of the BRHC’s Board of Managers, the Company may be granted additional Class B Units in BRHC, and in turn, the Company may transfer such Class B Units to certain members of the Company's management. Subject to certain conditions, the Class B Units will entitle the holders to participate in any future distributions of BRHC after distributions equal to the capital contributions and preferred return have been made to the holders of Class A Units of BRHC. At the closing of the BRHC Transaction, the Company entered into a Management Services Agreement with BRHC. Under the Management Services Agreement, the Company will provide services to BRHC with respect to the business operations of BRHC, including but not limited to locating, investigating and analyzing potential non-operator oil and gas projects and day-to-day operations related to such projects. The Company will be paid a fee under the Management Services Agreement intended to cover the costs of providing such services and will be reimbursed for certain third party expenses. The term of the Management Services Agreement commenced on the closing of the BRHC Transaction and continues indefinitely, unless terminated. The Management Services Agreement provides termination provisions upon reasonable notice for both BRHC and the Company as well as upon a change of control, provided that if the Management Services Agreement is terminated before December 31, 2016 that BRHC shall pay the Company a termination fee equal to the amount that would have been paid if the Management Services Agreement was in place until December 31, 2016. The Company believes that the BRHC Transaction and related actions will allow the Company to continue as a manager of the oil and gas assets in which we will continue to have an indirect minority interest. In addition, it will give us the flexibility to pursue distressed asset acquisitions in the Bakken and/or Three Forks formation that may be acquired with capital from our secured lenders as part of the restructuring terms, existing joint venture partners or other capital providers. As a result of the transaction, the Company recorded a gain on debt restructuring of $41,621,150 calculated as the difference between our final ownership interest in BRHC, after conversion of debt to equity and the equity contribution of the Initial Chambers Investment within BRHC and our retention of a 3.88% ownership interest in BRHC, and the net book value of the assets and liabilities we transferred to BRHC. The income and expense for the associated with the operating activities (through June 21, 2016, the date of the BRHC transaction) contributed in the BRHC Transaction are reflected as “Loss from discontinued items, net of income taxes” on our condensed statement of operations for all periods presented herein. The items included in “Loss from discontinued operations, net of income taxes” are as follows: For the Three Months For the Six Months Ended June 30, Ended June 30, 2016 2015 2016 2015 Oil and gas sales $ 2,877,058 $ 5,050,080 $ 5,539,613 $ 7,936,536 Gain on settled derivatives 1,043,026 847,198 1,043,026 1,980,619 Loss on the mark-to-market of derivatives (4,272,849 ) (1,956,155 ) (4,288,736 ) (1,588,826 ) Total revenues (352,765 ) 3,941,123 2,293,903 8,328,329 Operating expenses: Production expenses 652,882 1,153,663 1,400,639 2,143,520 Production taxes 292,080 555,152 568,028 841,344 General and administrative 311,061 84,608 476,461 207,729 Depletion of oil and gas properties 1,091,843 2,937,744 3,114,347 5,567,776 Impairment of oil and gas properties – 21,639,000 5,219,000 21,639,000 Accretion of discount on asset retirement obligations 8,125 7,932 16,258 15,861 Total operating expenses 2,355,991 26,378,099 10,794,733 30,415,230 Net operating loss (2,708,756 ) (22,436,976 ) (8,500,830 ) (22,086,901 ) Other income (expense): Interest expense (261,898 ) (1,547,172 ) (1,696,544 ) (3,114,420 ) Total other income (expense) (261,898 ) (1,547,172 ) (1,696,544 ) (3,114,420 ) Loss before provision for income taxes (2,970,654 ) (23,984,148 ) (10,197,374 ) (25,201,321 ) Provision for income taxes – 5,957,649 – 6,593,040 Net income (loss) $ (2,970,654 ) $ (18,026,499 ) $ (10,197,374 ) $ (18,608,281 ) The assets and liabilities subject to the BRHC Transaction have been retroactively reclassified as assets and liabilities from discontinued operations on the Company’s balance sheet as of December 31, 2015. Assets and liabilities reclassified as assets and liabilities from discontinued operations as of December 31, 2015 consisted of the following: December 31, 2015 ASSETS Assets from discontinued operations, current Derivative instruments $ 1,154,400 Accounts receivable 5,038,146 Prepaid expenses 37,100 Total assets from discontinued operations, current 6,229,646 Assets from discontinued operations, long term Oil and natural gas properties, full cost method of accounting Proved properties 131,168,906 Unproved properties 10,394 Total oil and natural gas properties, full cost method of accounting 131,179,300 Less, accumulated depletion and allowance for impairment (99,371,070 ) Total assets from discontinued operations, long term 31,808,230 Total assets from discontinued operations $ 38,037,876 LIABILITIES Liabilities from discontinued operations, current Accounts payable $ 7,906,438 Accrued expenses 55,830 Current portion of revolving credit facility and long term debt 60,350,629 Total liabilities from discontinued operations, current 68,312,897 Liabilities from discontinued operations, long term Asset retirement obligations 368,089 Total liabilities from discontinued operations, long term 368,089 Total liabilities from discontinued operations $ 68,680,986

5. Joint Venture

5. Joint Venture	6 Months Ended
	Jun. 30, 2016
Equity Method Investments and Joint Ventures [Abstract]
Joint Venture	On July 20, 2015, the Company signed a definitive agreement with an affiliate of Merced Capital (“Merced”) to form a joint venture that will acquire and develop Williston Basin non-operated assets. The joint venture will be funded by Merced with an initial investment target of $50 Million. Investments will be subject to Merced approval, and will be managed by the Company. The joint venture assets will be managed by the Company in exchange for a management fee and reimbursement of third party expenses, and, after certain investor hurdles are met, the Company will receive a share of profits in the joint venture. The Company will also have the option to co-invest up to 25% on acquisitions and capital expenditures alongside the venture and any such co-investments will reside directly with the Company. Upon the sale of joint venture assets, the Company will also have the option to bid and acquire the assets. We have not yet commenced operations pursuant to this joint venture, but continue to actively evaluate investment opportunities with Merced.

6. Property and Equipment

6. Property and Equipment	6 Months Ended
	Jun. 30, 2016
Property and equipment:
Property and Equipment	Property and equipment at June 30, 2016 and December 31, 2015, consisted of the following: June 30, December 31, 2016 2015 Property and equipment $ 139,004 $ 139,004 Less: Accumulated depreciation and amortization (105,221 ) (97,857 ) Total property and equipment, net $ 33,783 $ 41,147 All of the oil and gas assets have been classified as non-current assets from discontinued operations on the balance sheet as of December 31, 2015 as the Company effectively disposed of those assets as part of the restructuring discussed in Note 4 – Debt Restructuring. The following table shows depreciation, depletion, and amortization expense by type of asset: Six Months Ended June 30, 2016 2015 Depletion of costs for evaluated oil and gas properties (1) $ 3,114,347 $ 5,567,776 Depreciation and amortization of other property and equipment 7,364 8,276 Total depreciation, amortization and depletion $ 3,121,711 $ 5,576,052 (1) Impairment of Oil and Gas Properties As a result of currently prevailing low commodity prices and their effect on the proved reserve values of properties in 2016, we recorded non-cash ceiling test impairments of $5,219,000 and $21,639,000 for the six months ended June 30, 2016 and 2015, respectively. The expense associated with the impairments is presented as part of loss from discontinued operations, net of income taxes. The impairment charges affected our reported net income but did not reduce our cash flow.

7. Oil and Gas Properties

7. Oil and Gas Properties	6 Months Ended
	Jun. 30, 2016
Extractive Industries [Abstract]
Oil and Gas Properties	The following table summarizes gross and net productive oil wells by state at June 21, 2016 (prior to their disposition through our debt restructuring) and June 30, 2015. A net well represents our percentage ownership of a gross well. The following table does not include wells in which our interest is limited to royalty and overriding royalty interests. The following table also does not include wells which were awaiting completion, in the process of completion or awaiting flow back subsequent to fracture stimulation. June 21, 2016 June 30, 2015 Gross Net Gross Net North Dakota 352 10.64 286 8.59 Montana 5 0.37 5 0.37 Total 357 11.01 291 8.96 The Company’s oil and gas properties consisted of all acreage acquisition costs (including cash expenditures and the value of stock consideration), drilling costs and other associated capitalized costs. As of June 21, 2016 (prior to their disposition through our debt restructuring) and June 30, 2015, our principal oil and gas assets included approximately 7,016 and 8,566 net acres, respectively, located in North Dakota and Montana. The following table summarizes our capitalized costs for the purchase and development of our oil and gas properties for the six months ended June 30, 2016 and 2015, respectively: Six Months Ended June 30, 2016 2015 Purchases of oil and gas properties and development costs for cash $ 4,858,134 $ 12,677,179 Purchase of oil and gas properties accrued at period-end 3,155,016 9,203,387 Purchase of oil and gas properties accrued at beginning of period (prior to disposition) (6,899,503 ) (9,364,796 ) Capitalized asset retirement costs 4,737 41,695 Total purchase and development costs, oil and gas properties $ 1,118,384 $ 12,557,465 2016 Acquisitions During the six months ended June 30, 2016, we did not purchase any oil and gas properties. 2016 Divestitures During the six months ended June 30, 2016, we sold approximately 14 net leasehold acres oil and gas properties for total proceeds of $94,628. No gain or loss was recorded pursuant to the sales. 2016 Disposition in Debt Restructuring On June 21, 2016 we disposed of all of our oil gas properties, with net carrying costs of $24,498,638, as part of our debt restructuring as outlined in Note 4 – Debt Restructuring. 2015 Acquisitions During the six months ended June 30, 2015, we purchased a total of approximately 9 net leasehold acres of oil and gas properties. In consideration for the assignment, we paid the sellers a total of approximately $102,928. 2015 Divestitures During the six months ended June 30, 2015, we sold approximately 9 net leasehold acres of oil and gas properties for total proceeds of $103,000. No gain or loss was recorded pursuant to the sales. Undeveloped Acreage Expirations During the six months ended June 30, 2016, we had leases encompassing 1,079 net acres expire with carrying costs of $650,816 that had been reserved and transferred to the full cost pool subject to depletion in 2015.

8. Asset Retirement Obligation

8. Asset Retirement Obligation	6 Months Ended
	Jun. 30, 2016
Asset Retirement Obligation Disclosure [Abstract]
Asset Retirement Obligation	The Company has asset retirement obligations (ARO) associated with the future plugging and abandonment of proved properties and related facilities. Under the provisions of FASB ASC 410-20-25, the fair value of a liability for an asset retirement obligation is recorded in the period in which it is incurred and a corresponding increase in the carrying amount of the related long lived asset. The liability is accreted to its present value each period, and the capitalized cost is depreciated over the useful life of the related asset. If the liability is settled for an amount other than the recorded amount, a gain or loss is recognized. The Company has no assets that are legally restricted for purposes of settling ARO. The following table summarizes the Company’s asset retirement obligation transactions recorded in accordance with the provisions of FASB ASC 410-20-25 during the six months ended June 30, 2016 and 2015: Six Months Ended June 30, 2016 2015 Beginning ARO $ 368,089 $ 286,804 Liabilities incurred for new wells placed in production 4,737 41,695 Accretion of discount on ARO 16,258 15,861 Liability relieved in debt restructuring (389,084 ) – Ending ARO $ – $ 344,360 The ARO as of December 31, 2015 has been reclassified to non-current liabilities from discontinued operations on the balance sheet.

9. Related Party

9. Related Party	6 Months Ended
	Jun. 30, 2016
Related Party Transactions [Abstract]
Related Party	We leased office space on a month to month basis where the lessor is an entity owned by our former CEO and current Chairman of the Board of Directors, Bradley Berman. Pursuant to the lease, we occupied approximately 2,813 square feet of office space. We terminated the lease concurrent with our move to another location on June 30, 2016. The lease had base rents of $2,110 per month, plus common area operations and maintenance charges, and monthly parking fees of $240 per month, for the period from November 15, 2013 to October 31, 2014, and was subject to increases of $117 per month beginning November 1, 2014 and for each of the subsequent annual periods. We paid a total of $36,183 and $35,128 to this entity during the six months ended June 30, 2016 and 2015, respectively.

10. Derivative Instruments

10. Derivative Instruments	6 Months Ended
	Jun. 30, 2016
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Derivative Instruments	The Company is required to recognize all derivative instruments on the balance sheet as either assets or liabilities measured at fair value. The Company has not designated its derivative instruments as cash flow hedges for accounting purposes and, as such, marks its derivative instruments to fair value and recognizes the realized and unrealized changes in fair value in its statements of operations under the captions “Loss on settled derivatives” and “Loss on the mark-to-market of derivatives.” The Company has utilized swap and collar derivative contracts. While the use of these derivative instruments limits the downside risk of adverse price movements, their use also limits the upside revenue potential of upward price movements. For a fixed price swap contract, the counterparty is required to make a payment to the Company if the settlement price for any settlement period is less than the swap price and the Company is required to make a payment to the counterparty if the settlement price for any period is greater than the swap price. For a collar contract, the counterparty is required to make a payment to the Company if the settlement price for any settlement period is below the floor price, the Company is required to make a payment to the counterparty if the settlement price for any settlement period is above the ceiling price and no payment is required by either party if the settlement price for any settlement period is between the floor price and the ceiling price. The Company’s derivative contracts are settled based on reported settlement prices on commodity exchanges, with crude oil derivative settlements based on NYMEX West Texas Intermediate (“WTI”) pricing. As of June 30, 2016, the Company had no outstanding derivative contracts. All of our then outstanding derivative contracts, with a mark-to-market liability valuation of $3,134,336, were transferred to BRHC as part of the debt restructuring. Derivative Gains and Losses The following table presents realized and unrealized gains and losses on derivative instruments for the periods presented: Six Months Ended June 30, 2016 2015 Realized gain on derivatives: Crude oil fixed price swaps $ 922,872 $ 1,589,818 Crude oil collars 120,154 390,801 Realized gain on derivatives, net $ 1,043,026 $ 1,980,619 Loss on the mark-to-market of derivatives: Crude oil fixed price swaps $ (4,157,491 ) $ (1,161,398 ) Crude oil collars (131,245 ) (427,428 ) Loss on the mark-to-market of derivatives, net $ (4,288,736 ) $ (1,588,826 ) Balance Sheet Offsetting of Derivative Assets and Liabilities In accordance with FASB issued ASU No. 2011-11, Balance Sheet (Topic 210)-Disclosures about Offsetting Assets and Liabilities, all of the Company’s derivative contracts are carried at their fair value in the condensed balance sheets under the captions “Derivative instruments” and “Noncurrent derivative instruments”. Derivative instruments from the same counterparty that are subject to contractual terms which provide for net settlement are reported on a net basis in the condensed balance sheets. The following tables present the gross amounts of recognized derivative assets and liabilities, the amounts offset under the netting arrangements with counterparties, and the resulting net amounts presented in the condensed balance sheets as part of discontinued operations for the periods presented, all at fair value. December 31, 2015 Gross Net Gross amounts amounts of amounts of offset assets recognized on balance on balance assets sheet sheet Commodity derivative assets $ 1,154,417 $ (17 ) $ 1,154,400 December 31, 2015 Gross Net Gross amounts amounts of amounts of offset liabilities recognized on balance on balance liabilities sheet sheet Commodity derivative liabilities $ – $ – $ – The following table reconciles the net amounts disclosed above to the individual financial statement line items in the condensed balance sheets: December 31, 2015 Current assets from discontinued operations $ 1,154,400 Non-current assets from discontinued operations – Net amount of assets on the balance sheet 1,154,400 Current liabilities from discontinued operations – Non-current liabilities from discontinued operations – Net amounts of liabilities on the balance sheet – Total derivative assets, net $ 1,154,400

11. Fair Value of Financial Ins

11. Fair Value of Financial Instruments	6 Months Ended
	Jun. 30, 2016
Fair Value Disclosures [Abstract]
Fair Value of Financial Instruments	The Company adopted FASB ASC 820-10 upon inception at April 9, 2010. Under FASB ASC 820-10-5, fair value is defined as 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 (an exit price). The standard outlines a valuation framework and creates a fair value hierarchy in order to increase the consistency and comparability of fair value measurements and the related disclosures. Under GAAP, certain assets and liabilities must be measured at fair value, and FASB ASC 820-10-50 details the disclosures that are required for items measured at fair value. The Company has revolving credit facilities that must be measured under the new fair value standard. The Company’s financial assets and liabilities are measured using inputs from the three levels of the fair value hierarchy. The three levels are as follows: Level 1 - Inputs are unadjusted quoted prices in active markets for identical assets or liabilities that the Company has the ability to access at the measurement date. Level 2 - Inputs include quoted prices for similar assets and liabilities in active markets, quoted prices for identical or similar assets or liabilities in markets that are not active, inputs other than quoted prices that are observable for the asset or liability (e.g., interest rates, yield curves, etc.), and inputs that are derived principally from or corroborated by observable market data by correlation or other means (market corroborated inputs). Level 3 - Unobservable inputs that reflect our assumptions about the assumptions that market participants would use in pricing the asset or liability. The following schedule summarizes the valuation of financial instruments at fair value on a recurring basis in the balance sheets as of June 30, 2016 and December 31, 2015: Fair Value Measurements at June 30, 2016 Level 1 Level 2 Level 3 Assets Cash and cash equivalents $ 1,038,567 $ – $ – Derivative Instruments (crude oil swaps and collars) – – – Total assets 1,038,567 – – Liabilities Derivative Instruments (crude oil swaps and collars) – – – Revolving credit facilities and long term debt – – – Total Liabilities – – – $ 1,038,567 $ – $ – Fair Value Measurements at December 31, 2015 Level 1 Level 2 Level 3 Assets Cash and cash equivalents $ 228,194 $ – $ – Derivative Instruments (crude oil swaps and collars) – 1,154,400 – Total assets 228,194 1,154,400 – Liabilities Revolving credit facilities and long term debt – 60,350,629 – Total Liabilities – 60,350,629 – $ 228,194 $ (59,196,229) $ – There were no transfers of financial assets or liabilities between Level 1 and Level 2 inputs for the six months ended June 30, 2016 and 2015. Level 2 liabilities include Revolving credit facilities. No fair value adjustment was necessary during the six months ended June 30, 2016 and 2015. The derivative instruments and revolving credit facilities are reflected on the balance sheets as part of assets or liabilities from discontinued operations as detailed in Note 4 – Debt Restructuring.

12. Revolving Credit Facilities

12. Revolving Credit Facilities and Long Term Debt	6 Months Ended
	Jun. 30, 2016
Debt Disclosure [Abstract]
Revolving Credit Facilities and Long Term Debt	The Company, as borrower, entered into a Credit Agreement dated August 8, 2013 and amendments thereto dated December 13, 2013, March 24, 2014, April 21, 2014, September 11, 2014, March 30, 2015 and August 10, 2015 (as amended, the “Senior Credit Agreement ” Availability under the Senior Credit Facility was at all times subject to the then-applicable borrowing base, determined by Cadence in a manner consistent with the normal and customary oil and gas lending practices of Cadence. Availability was initially set at $7 million and was subject to periodic redeterminations. Subject to availability under the borrowing base, the Company could borrow, repay and re-borrow funds in amounts of $250,000 or more. At the Company’s election, the unpaid principal balance of any borrowings under the Senior Credit Facility may bear interest at either (i) the Base Rate, as defined in the Senior Credit Facility, plus the applicable margin, which varies from 1.00% to 1.50% or (ii) the LIBOR rate, as defined in the Senior Credit Facility, plus the applicable margin, which varies from 3.00% to 3.50%. Interest was payable for Base Rate loans on the last business day of the month and for LIBOR loans on the last LIBOR business day of each LIBOR interest period. The Company was also required to pay a quarterly fee of 0.50% on any unused portion of the borrowing base, as well as a facility fee of 0.90% of the initial and any subsequent additions to the borrowing base. The Senior Credit Facility’s maturity date of August 8, 2016, was subsequently amended to January 15, 2017 pursuant to the amendment on March 30, 2015. The Company could prepay the entire amount of Base Rate loans at any time, and could prepay the entire amount of LIBOR loans upon at least three business days’ notice to Cadence. The Senior Credit Facility was secured by first priority interests in mortgages on substantially all of the Company’s assets, including but not limited to the Company’s mineral interests in North Dakota and Montana. As part of the debt restructuring outline in Note 4 – Debt Restructuring, the Company transferred the obligation with a balance outstanding of $29,400,000 under the Senior Credit Facility to BRHC. The Company had borrowings of $27.75 million outstanding under the Senior Credit Agreement as of December 31, 2015. Subordinated Credit Facility The Company, as borrower, entered into a Second Lien Credit Agreement dated August 8, 2013 and amendments thereto dated December 13, 2013, March 24, 2014, April 21, 2014, September 11, 2014, March 30, 2015, and August 10, 2015 (as amended, the “Subordinated Credit Agreement”) by and among the Company, as borrower, Chambers Energy Management, LP, as administrative agent (“Chambers”), and the several other lenders named therein (the “Subordinated Credit Facility”). Under the Subordinated Credit Facility, term loans in the aggregate principal amount of up to $75 million are available from time to time (i) to repay the Previous Credit Facility, (ii) for fees and closing costs in connection with both the Senior Credit Facility and the Subordinated Credit Facility (together, the “Credit Facilities”), and (iii) general corporate purposes. The Subordinated Credit Agreement provided initial commitment availability of $25 million, which was subsequently amended to the current availability of $30 million, with the remaining commitments subject to the approval of Chambers and other customary conditions. The Company may borrow the available commitments in amounts of $5 million or more and shall not request borrowings of such loans more than once a month, provided that the initial draw was at least $15 million. Loans under the Subordinated Credit Facility shall be funded net of a 2% OID. The unpaid principal balance of borrowings under the Subordinated Credit Facility bears interest at the Cash Interest Rate plus the PIK Interest Rate. The Cash Interest Rate is 9.00% per annum plus a rate per annum equal to the greater of (i) 1.00% and (ii) the offered rate for three-month deposits in U.S. dollars that appears on Reuters Screen LIBOR 01 as of 11:00 a.m. (London time) on the second full LIBOR business day preceding the first day of each calendar quarter. The PIK Interest Rate is equal to 4.00% per annum. Interest is payable on the last day of each month. The Company is also required to pay an annual nonrefundable administration fee of $50,000 and a monthly availability fee computed at a rate of 0.50% per annum on the average daily amount of any unused portion of the available amount under the commitment. The Subordinated Credit Facility matured on June 30, 2017. Upon at least three business days’ written notice, the Company could prepay the entire amount under the loans, together with accrued interest. Each prepayment made prior to the second anniversary of the funding date, as defined in the Subordinated Credit Facility, would be accompanied by a make-whole amount, as defined in the Subordinated Credit Agreement. Prepayments made on or after the second anniversary of the funding date were accompanied by an applicable premium, as set forth in the Subordinated Credit Agreement. The Subordinated Credit Facility was secured by second priority interests on substantially all of the Company’s assets, including but not limited to second priority mortgages on the Company’s mineral interests in North Dakota and Montana. The first funding from the Subordinated Credit Facility occurred on September 9, 2013 at which time we drew $14,700,000, net of a $300,000 original issue discount, from the Subordinated Credit Agreement and used $10,226,057 of those proceeds to repay and terminate a previously outstanding revolving credit facility. We had drawn an additional $14,700,000, net of $300,000 original issue discounts, through December 31, 2015. The Company had borrowings of $30.0 million outstanding under the Subordinated Credit Facility as of December 31, 2015. The obligations under the Subordinated Credit Facility, $30.0 million of principal and $2,931,369 of PIK interest payable, were transferred to BRHC and converted to equity in BRHC as part of the debt restructuring outlined in Note 4- Debt Restructuring. Intercreditor Agreements and Covenants Cadence and Chambers had entered into an Intercreditor Agreement dated August 8, 2013 (the “Intercreditor Agreement”). The Intercreditor Agreement provides that any liens on the assets of the Company securing indebtedness under the Subordinated Credit Facility are subordinate to liens on the assets securing indebtedness under the Senior Credit Facility and sets forth the respective rights, obligations and remedies of the lenders under the Senior Credit Facility with respect to their first priority liens and the lenders under the Subordinated Credit Facility with respect to their second priority liens. The Credit Facilities, as amended, required customary affirmative and negative covenants for credit facilities of the respective types and sizes for companies operating in the oil and gas industry, as well as customary events of default. Furthermore, the Credit Facilities contain financial covenants that require the Company to satisfy certain specified financial ratios. The Senior Credit Agreement requires the Company to maintain, as of the last day of each fiscal quarter of the Company, (i) a collateral coverage ratio (reserve value plus consolidated working capital to adjusted indebtedness) of at least 0.65 to 1.00 through the quarter ending June 30, 2014, 0.70 to 1.00 for the quarters ending September 30, 2014 and December 31, 2014, was waived for the quarters ending March 31, 2015 and June 30, 2015, and 0.70 to 1.00 for the quarter ending September 30, 2015, and 0.80 to 1.00 for the quarter ending December 31, 2015 and thereafter, (ii) a ratio of current assets, including debt facility available to be drawn, to current liabilities of a minimum of 1.0 to 1.0, except for the quarter ending June 30, 2014, which was waived, (iii) a net debt to EBITDAX, as defined in the Senior Credit Agreement, ratio of 3.75 to 1.00 for the quarter ended March 31, 2014, 4.25 to 1.00 for the quarters ended June 30, 2014 and September 30, 2014, 4.00 to 1.00 for the quarter ended December 31, 2014, was waived for the quarters ended March 31, 2015 and June 30, 2015, and 3.50 to 1.00 for the quarter ending September 30, 2015, and 3.65 to 1.00 for the quarter ending December 31, 2015, and 3.50 to 1.00 for the quarter ending March 31, 2016 and thereafter, in each case calculated on a modified trailing four quarter basis, (iv) a maximum senior leverage ratio of not more than 2.5 to 1.0 calculated on a modified trailing four quarter basis, and (v) a minimum interest coverage ratio of not less than 3.0 to 1.0. The Subordinated Credit Agreement requires the Company to maintain, as of the last day of each fiscal quarter of the Company, (i) a collateral coverage ratio (reserve value plus consolidated working capital to adjusted indebtedness) of at least 0.65 to 1.00 through the quarter ending June 30, 2014, 0.70 to 1.00 for the quarters ending September 30, 2014 and December 31, 2014, was waived for the quarters ending March 31, 2015 and June 30, 2015, and 0.70 to 1.00 for the quarter ending September 30, 2015, and 0.80 to 1.00 for the quarter ending December 31, 2015 and thereafter, (ii) a consolidated net leverage ratio (adjusted total indebtedness less the amount of unrestricted cash equivalents to consolidated EBITDA) of no more than 3.75 to 1.00 for the quarter ending March 31, 2014, 4.25 to 1.00 for the quarters ending June 30, 2014 and September 30, 2014, 4.00 to 1.00 for the quarter ending December 31, 2014, was waived for the quarters ending March 31, 2015 and June 30, 2015, and 3.50 to 1.00 for the quarter ending September 30, 2015, and 3.65 to 1.00 for the quarter ending December 31, 2015, and 3.50 to 1.00 for the quarter ending March 31, 2016 and thereafter, calculated on a modified trailing four quarter basis, (iii) a consolidated cash interest coverage ratio (consolidated EBITDA to consolidated cash interest expense) of no less than 2.5 to 1.0, calculated on a modified trailing four quarter basis and (iv) a ratio of consolidated current assets to consolidated current liabilities of at least 1.0 to 1.0, except for the quarter ending June 30, 2015 when the covenant was waived. In addition, each of the Credit Facilities required that the Company enter into hedging agreements based on anticipated oil production from currently producing wells as agreed to by the lenders. Covenant Violations The Company was out of compliance with the collateral coverage ratio covenant as of March 31, 2016 and December 31, 2015 and the current ratio covenant as defined by the Subordinated Credit Facility as of March 31, 2016. Additionally, the audit report the Company received with respect to its financial statements as of December 31, 2015 contains an explanatory paragraph expressing uncertainty as to the Company’s ability to continue as a going concern, the delivery of which constitutes a default under both its Senior Credit Facility and Subordinated Credit Facility. See Note 3, “Going Concern”, for additional information. The Company received a waiver for all debt covenants as of December 31, 2015 and March 31, 2016 as part of the debt restructuring outlined in Note 4 – Debt Restructuring. Debt Discount, Detachable Warrants In connection with the Subordinated Credit Facility, the Company agreed to issue to the lenders detachable warrants to purchase up to 5,000,000 shares of the Company’s common stock at an exercise price of $0.65 per share. The warrants expire on August 8, 2018. Proceeds from the loan were allocated between the debt and equity based on the relative fair values at the time of issuance, resulting in a debt discount of $2,473,576 at issuance that is presented as a debt discount on the balance sheet and is being amortized using the effective interest method over the life of the credit facility, which matures on June 30, 2017. A total of $-0- and $321,763 was amortized during the six months ended June 30, 2016 and 2015. The remaining unamortized balance of the debt discount attributable to the warrants is $-0- as of June 30, 2016. The amortization of the debt discount attributable to the warrants was accelerated in 2015 to fully amortize the discount as of December 31, 2015 when the related debt became payable on demand due to a default on the related debt. As part of the debt restructuring all related warrants were retired and cancelled. Amounts outstanding under revolving credit facilities and long term debts consisted of the following as of December 31, 2015: December 31, 2015 Senior Revolving Credit Facility, Cadence Bank, N.A. $ 27,750,000 Subordinated Credit Agreement, Chambers 30,000,000 PIK Interest on Subordinated Credit Agreement, Chambers 2,600,629 Total credit facilities and long term debts 60,350,629 Less: Unamortized OID – Less: Unamortized debt discount attributable to warrants – Total credit facilities and long term debts, net of discounts 60,350,629 Less: current maturities (1) (60,350,629 ) Long term portion of credit facilities and long term debts $ – (1) Due to existing and anticipated covenant violations, the Company’s Senior Credit Facility and Subordinated Credit Facility were classified as current December 31, 2015 and are presented as part of current liabilities from discontinued operations on the balance sheet. Net proceeds of $29.4 million was received from our $30 million in advances due to $600,000 of OID pursuant to the Subordinated Credit Agreement at issuance that is presented as a debt discount on the balance sheet and was being amortized using the effective interest method over the life of the credit facility, which matures on June 30, 2017. A total of $-0- and $84,858 was amortized during the six months ended June 30, 2016 and 2015, respectively. The remaining unamortized balance of the debt discount attributable to the OID is $-0- as of June 30, 2016 and December 31, 2015 as the amortization was accelerated in 2015 to fully amortize the discount as of December 31, 2015 when the related debt became payable on demand due to a default on the related debt. The following presents components of interest expense, presented as a component of loss from discontinued operations, for the six months ended June 30, 2016 and 2015, respectively: Six Months Ended June 30, 2016 2015 Accrued PIK interest $ 330,740 $ 634,919 Amortization of OID – 84,858 Interest and commitment fees 1,373,023 2,177,431 Amortization of debt issuance costs – 190,780 Amortization of warrant costs – 321,763 Less interest capitalized to the full cost pool of our proved oil & gas properties (7,219 ) (295,331 ) $ 1,696,544 $ 3,114,420

13. Changes in Stockholders' Eq

13. Changes in Stockholders' Equity	6 Months Ended
	Jun. 30, 2016
Equity [Abstract]
Changes in Stockholders' Equity	Preferred Stock The Company has 20,000,000 authorized shares of $0.001 par value preferred stock. No shares have been issued to date. Common Stock The Company has 500,000,000 authorized shares of $0.001 par value common stock.

14. Options

14. Options	6 Months Ended
	Jun. 30, 2016
Disclosure of Compensation Related Costs, Share-based Payments [Abstract]
Options	Options Granted No options were granted during the six months ended June 30, 2016. The Company recognized a total of $315,648, and $313,751 of compensation expense during the six months ended June 30, 2016 and 2015, respectively, on common stock options issued to Employees and Directors that are being amortized over the implied service term, or vesting period, of the options. The remaining unamortized balance of these options is $1,176,572 as of June 30, 2016. Options Exercised No options were exercised during the six months ended June 30, 2016 and 2015. Options Forfeited No options were forfeited during the six months ended June 30, 2016 and 2015.

15. Warrants

15. Warrants	6 Months Ended
	Jun. 30, 2016
Warrants and Rights Note Disclosure [Abstract]
Warrants	Warrants Granted No warrants were granted during the six months ended June 30, 2016 and 2015. We recognized a total of $-0- and $321,763 of finance expense during the six months ended June 30, 2016 and 2015, respectively, on common stock warrants issued to lenders. All warrants granted pursuant to debt financings are amortized over the remaining life of the respective loan. Warrants Exercised No warrants were exercised during the six months ended June 30, 2016 and 2015. Warrants Expired and Cancelled A total of 500,000 warrants, all at an exercise price of $0.95, expired during the six months ended June 30, 2016. Additionally 5,000,000 warrants, at an exercise price of $0.65, were cancelled and retired as part of the debt restructuring outlined in Note 4 – Debt restructuring. No options were forfeited during the six months ended June 30, 2015.

16. Income Taxes

16. Income Taxes	6 Months Ended
	Jun. 30, 2016
Income Tax Disclosure [Abstract]
Income Taxes	The Company accounts for income taxes under ASC Topic 740, Income Taxes, We currently estimate that our effective tax rate for the year ending December 31, 2016 will be 0%. Losses incurred during the period from April 9, 2011 (inception) to June 30, 2016 could be used to offset future tax liabilities. Accounting standards require the consideration of a valuation allowance for deferred tax assets if it is “more likely than not” that some component or all of the benefits of deferred tax assets will not be realized. As of June 30, 2016, net deferred tax assets were $11,537,106, after an offsetting reduction in deferred tax liabilities of $4,962, primarily related to net operating loss carryforwards. A valuation allowance of approximately $11,537,106 was applied to the remaining net deferred tax assets. We have not provided any valuation allowance against our deferred tax liabilities, which were netted against our deferred tax assets. The tax benefit for the six months ended June 30, 2016 was $-0- as the Company utilized a portion of the Company’s deferred tax asset, which was offset by a corresponding reduction in the valuation allowance on the utilized deferred tax asset. In accordance with FASB ASC 740, the Company has evaluated its tax positions and determined there are no significant uncertain tax positions as of any date on, or before June 30, 2016.

17. Commitments and Contingenci

17. Commitments and Contingencies	6 Months Ended
	Jun. 30, 2016
Commitments and Contingencies Disclosure [Abstract]
Commitments and Contingencies	The Company from time to time may be involved in various inquiries, administrative proceedings and litigation relating to matters arising in the normal course of business. The Company is not aware of any inquiries or administrative proceedings and is not currently a defendant in any material litigation and is not aware of any threatened litigation that could have a material effect on the Company. The Company periodically maintains cash balances at banks in excess of federally insured amounts. The extent of loss, if any, to be sustained as a result of any future failure of a bank or other financial institution is not subject to estimation at this time.

18. Subsequent Events

18. Subsequent Events	6 Months Ended
	Jun. 30, 2016
Subsequent Events [Abstract]
Subsequent Events	There were no subsequent events to report through the date of this filing.

2. Basis of Presentation and 24

2. Basis of Presentation and Significant Accounting Policies (Policies)	6 Months Ended
	Jun. 30, 2016
Accounting Policies [Abstract]
Reclassifications	Reclassifications In the current year, the Company classified assets and liabilities subject to our restructuring transaction outlined in Note 4 – Restructuring as assets and liabilities from discontinued operations in the balance sheet and income, expense and cash flows from the restructured operations are shown as net income and cash flows from discontinued operations. For comparative purposes, amounts in the prior periods have been reclassified to conform to current year presentation.
Use of Estimates	Use of Estimates The preparation of financial statements in conformity with generally accepted accounting principles requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities and disclosure of contingent assets and liabilities at the date of the financial statements and the reported amount of revenues and expenses during the reporting period. Actual results could differ from those estimates.
Environmental Liabilities	Environmental Liabilities The oil and gas industry is subject, by its nature, to environmental hazards and clean-up costs. At this time, management knows of no substantial losses from environmental accidents or events which would have a material effect on the Company.
Cash and Cash Equivalents	Cash and Cash Equivalents Cash equivalents include money market accounts which have maturities of three months or less. For the purpose of the statements of cash flows, all highly liquid investments with an original maturity of three months or less are considered to be cash equivalents. Cash equivalents are stated at cost plus accrued interest, which approximates market value. No cash equivalents were on hand at June 30, 2016 and December 31, 2015.
Cash in Excess of FDIC Insured Limits	Cash in Excess of FDIC Insured Limits The Company maintains its cash in bank deposit accounts which, at times, may exceed federally insured limits. Accounts are guaranteed by the Federal Deposit Insurance Corporation (FDIC) and the Securities Investor Protection Corporation (SIPC) up to $250,000 and $500,000, respectively, under current regulations. The Company had approximately $538,567 and $-0- in excess of FDIC and SIPC insured limits at June 30, 2016 and December 31, 2015, respectively. The Company has not experienced any losses in such accounts.
Advances to Operators	Advances to Operators The Company participates in the drilling of crude oil and natural gas wells with other working interest partners. Due to the capital intensive nature of crude oil and natural gas drilling activities, the working interest partner responsible for conducting the drilling operations may request advance payments from other working interest partners for their share of the costs. The Company expects such advances to be applied by working interest partners against joint interest billings for its share of the drilling operations within 120 days from when the advance is paid.
Debt Issuance Costs	Debt Issuance Costs Costs relating to obtaining our revolving credit facilities are capitalized and amortized over the term of the related debt using the straight-line method. The unamortized balance of debt issuance costs at June 30, 2016, and December 31, 2015, was $-0-. Amortization of debt issuance costs charged to interest expense were $-0- and $190,780 for the six months ended June 30, 2016 and 2015, respectively. Interest expense related to debt issuance costs is reflected as part of loss from discontinued operations on the statement of operations. When a loan is paid in full or becomes due on demand due to a default on the loan any unamortized financing costs are removed from the related accounts and charged to interest expense.
Website Development Costs	Website Development Costs The Company accounts for website development costs in accordance with ASC 350-50, “Accounting for Website Development Costs” (“ASC 350-50”), wherein website development costs are segregated into three activities: 1) Initial stage (planning), whereby the related costs are expensed. 2) Development (web application, infrastructure, graphics), whereby the related costs are capitalized and amortized once the website is ready for use. Costs for development content of the website may be expensed or capitalized depending on the circumstances of the expenditures. 3) Post-implementation (after site is up and running: security, training, admin), whereby the related costs are expensed as incurred. Upgrades are usually expensed, unless they add additional functionality. We have capitalized a total of $56,660 of website development costs from inception through June 30, 2016. We depreciate our website development costs on a straight line basis over the estimated useful life of the assets, which is currently three years. We have recognized depreciation expense on these website costs of $-0- and $257 for the six months ended June 30, 2016 and 2015, respectively. As of June 30, 2016, all website development costs have been fully depreciated.
Income Taxes	Income Taxes The Company recognizes deferred tax assets and liabilities based on differences between the financial reporting and tax basis of assets and liabilities using the enacted tax rates and laws that are expected to be in effect when the differences are expected to be recovered. The Company provides a valuation allowance for deferred tax assets for which it does not consider realization of such assets to be more likely than not.
Basic and Diluted Loss Per Share	Basic and Diluted Loss Per Share The basic net loss per share is computed by dividing the net loss (the numerator) by the weighted average number of common shares outstanding for the period (the denominator). Diluted net loss per common share is computed by dividing the net loss by the weighted average number of common shares and potential common shares outstanding (if dilutive) during each period. Potential common shares include stock options, warrants and restricted stock. The number of potential common shares outstanding relating to stock options, warrants and restricted stock is computed using the treasury stock method. The reconciliation of the denominators used to calculate basic EPS and diluted EPS for the three and six months ended June 30, 2016 and 2015 are as follows: Three Months Ended Six Months Ended June 30, June 30, 2016 2015 2016 2015 Weighted average common shares outstanding – basic 47,979,990 47,979,990 47,979,990 47,979,990 Plus: Potentially dilutive common shares: Stock options and warrants 78,689 – 76,583 – Weighted average common shares outstanding – diluted 48,058,679 47,979,990 48,056,573 47,979,990 Stock options and warrants excluded from the calculation of diluted EPS because their effect was anti-dilutive were 9,954,875 and 16,275,542 for the three months ended June 30, 2016 and 2015, respectively, and 9,954,875 and 16,275,542 for the six months ended June 30, 2016 and 2015, respectively.
Fair Value of Financial Instruments	Fair Value of Financial Instruments Under FASB ASC 820-10-05, the Financial Accounting Standards Board establishes a framework for measuring fair value in generally accepted accounting principles and expands disclosures about fair value measurements. This Statement reaffirms that fair value is the relevant measurement attribute. The adoption of this standard did not have a material effect on the Company’s financial statements as reflected herein. The carrying amounts of cash, accounts payable and accrued expenses reported on the balance sheets are estimated by management to approximate fair value primarily due to the short term nature of the instruments. The Company had no items that required fair value measurement on a recurring basis.
Property and Equipment	Property and Equipment Property and equipment that are not oil and gas properties are recorded at cost and depreciated using the straight-line method over their estimated useful lives of three to seven years. Expenditures for replacements, renewals, and betterments are capitalized. Maintenance and repairs are charged to operations as incurred. Long-lived assets, other than oil and gas properties, are evaluated for impairment to determine if current circumstances and market conditions indicate the carrying amount may not be recoverable. The Company has not recognized any impairment losses on non-oil and gas long-lived assets. Depreciation expense was $7,364 and $8,276 for the six months ended June 30, 2016 and 2015, respectively.
Revenue Recognition	Revenue Recognition The Company recognizes oil and gas revenues from its interests in producing wells when production is delivered to, and title has transferred to, the purchaser and to the extent the selling price is reasonably determinable. The Company uses the sales method of accounting for gas balancing of gas production and would recognize a liability if the existing proven reserves were not adequate to cover an imbalance situation. Oil and gas revenues are reflected as part of discontinued operations on the statement of operations.
Asset Retirement Obligations	Asset Retirement Obligations The Company records the fair value of a liability for an asset retirement obligation in the period in which the well is spud or the asset is acquired and a corresponding increase in the carrying amount of the related long-lived asset. The liability is accreted to its present value each period, and the capitalized cost is depreciated over the useful life of the related asset. If the liability is settled for an amount other than the recorded amount, a gain or loss is recognized. The capitalized cost and asset retirement obligation as of December 31, 2015 and the expense related to accretion of the discount on the asset retirement liability are reflected as part of discontinued operations on the balance sheet and statement of operations.
Full Cost Method	Full Cost Method The Company follows the full cost method of accounting for oil and gas operations whereby all costs related to the exploration and development of oil and gas properties are initially capitalized into a single cost center ("full cost pool"). Such costs include land acquisition costs, geological and geophysical expenses, carrying charges on non-producing properties, costs of drilling directly related to acquisition, and exploration activities. Internal costs that are capitalized are directly attributable to acquisition, exploration and development activities and do not include costs related to the production, general corporate overhead or similar activities. Costs associated with production and general corporate activities are expensed in the period incurred. Capitalized costs are summarized as follows for the six months ended June 30, 2016 and 2015, respectively: Six Months Ended June 30, 2016 2015 Capitalized Certain Payroll and Other Internal Costs $ – $ – Capitalized Interest Costs 7,219 295,331 Total $ 7,219 $ 295,331 Proceeds from sales of proved properties will generally be credited to the full cost pool, with no gain or loss recognized, unless such a sale would significantly alter the relationship between capitalized costs and the proved reserves attributable to these costs. A significant alteration would typically involve a sale of 20% or more of the proved reserves related to a single full cost pool. The Company assesses all items classified as unevaluated property on a quarterly basis for possible impairment or reduction in value. The assessment includes consideration of the following factors, among others: intent to drill; remaining lease term; geological and geophysical evaluations; drilling results and activity; the assignment of proved reserves; and the economic viability of development if proved reserves are assigned. During any period in which these factors indicate an impairment, the cumulative drilling costs incurred to date for such property and all or a portion of the associated leasehold costs are transferred to the full cost pool and are then subject to amortization. Capitalized costs associated with impaired properties and properties having proved reserves, estimated future development costs, and asset retirement costs under FASB ASC 410-20-25 are depleted and amortized on the unit-of-production method based on the estimated gross proved reserves as determined by independent petroleum engineers. The costs of unproved properties are withheld from the depletion base until such time as they are either developed or abandoned. Capitalized costs of oil and gas properties (net of related deferred income taxes) may not exceed an amount equal to the present value, discounted at 10% per annum, of the estimated future net cash flows from proved oil and gas reserves plus the cost of unproved properties (adjusted for related income tax effects). Should capitalized costs exceed this ceiling, impairment is recognized. The present value of estimated future net cash flows is computed by applying the arithmetic average first day price of oil and natural gas for the preceding twelve months to estimated future production of proved oil and gas reserves as of the end of the period, less estimated future expenditures to be incurred in developing and producing the proved reserves and assuming continuation of existing economic conditions. Such present value of proved reserves' future net cash flows excludes future cash outflows associated with settling asset retirement obligations. Should this comparison indicate an excess carrying value, the excess is charged to earnings as an impairment expense. As a result of currently prevailing low commodity prices and their effect on the proved reserve values of properties throughout 2015 and 2016, we recorded non-cash ceiling test impairments of $5,219,000 and $21,639,000 for the six months ended June 30, 2016 and 2015, respectively. The impairment charges affected our reported net income but did not reduce our cash flow. The impairment charges are reflected as part of discontinued operations on the statement of operations.
Stock-Based Compensation	Stock-Based Compensation The Company adopted FASB guidance on stock based compensation upon inception at April 9, 2010. Under FASB ASC 718-10-30-2, all share-based payments to employees, including grants of employee stock options, are recognized in the income statement based on their fair values. Expense related to common stock and stock options issued for services and compensation totaled $315,648 and $313,751 for the six months ended June 30, 2016 and 2015, respectively, using the Black-Scholes options pricing model and an effective term of 6 to 6.5 years based on the weighted average of the vesting periods and the stated term of the option grants and the discount rate on 5 to 7 year U.S. Treasury securities at the grant date. In addition, $-0- and $321,763 of warrant related debt discounts were amortized during the six months ended June 30, 2016 and 2015, respectively, and treated as interest expense and reflected as part of discontinued operations on the statement of operation. The fair value of warrants is determined similar to the method used in determining the fair value of employee stock options and the fair value is amortized over the life of the related credit facility and accelerated in the event of termination of the related credit facility or if the related credit facility becomes payable on demand due to a default on the related credit facility. The amortization of the debt discount attributable to the warrants was accelerated in 2015 to fully amortize the discount as of December 31, 2015 when the related debt became payable on demand due to a default on the related debt. As part of the debt restructuring all related warrants were retired and cancelled.
Uncertain Tax Positions	Uncertain Tax Positions Effective upon inception at April 9, 2010, the Company adopted standards for accounting for uncertainty in income taxes. These standards prescribe a recognition threshold and measurement attribute for the financial statement recognition and measurement of a tax position taken or expected to be taken in a tax return. These standards also provide guidance on de-recognition, classification, interest and penalties, accounting in interim periods, disclosure, and transition. Various taxing authorities may periodically audit the Company’s income tax returns. These audits include questions regarding the Company’s tax filing positions, including the timing and amount of deductions and the allocation of income to various tax jurisdictions. In evaluating the exposures connected with these various tax filing positions, including state and local taxes, the Company records allowances for probable exposures. A number of years may elapse before a particular matter, for which an allowance has been established, is audited and fully resolved. Black Ridge Oil & Gas, Inc. has not yet undergone an examination by any taxing authorities. The assessment of the Company’s tax position relies on the judgment of management to estimate the exposures associated with the Company’s various filing positions.
Derivative Instruments and Price Risk Management	Derivative Instruments and Price Risk Management The Company enters into derivative contracts, including price swaps, caps and floors, which require payments to (or receipts from) counterparties based on the differential between a fixed price and a variable price for a fixed quantity of crude oil without the exchange of underlying volumes. The notional amounts of these financial instruments are based on a portion of the expected production from existing wells. The Company has, and may continue to use exchange traded futures contracts and option contracts to hedge the delivery price of crude oil at a future date. Any realized gains and losses are recorded to gain (loss) on settled derivatives and unrealized gains or losses as a result of mark-to market valuations are recorded to gain (loss) on the mark-to-market of derivatives on the statements of operations.
Recent Accounting Pronouncements	Recent Accounting Pronouncements New accounting pronouncements are issued by the Financial Accounting Standards Board (“FASB”) that are adopted by the Company as of the specified effective date. If not discussed below, management believes there have been no developments to recently issued accounting standards, including expected dates of adoption and estimated effects on our financial statements, from those disclosed in our Annual Report on Form 10-K for the year ended December 31, 2015. In November 2015, the Financial Accounting Standards Board (“FASB”) issued Accounting Standards Update (“ASU”) 2015-17, Balance Sheet Classification of Deferred Taxes, which eliminates the current requirement to present deferred tax liabilities and assets as current and noncurrent amounts in a classified statement of financial position. Instead, entities will be required to classify all deferred tax assets and liabilities as noncurrent in a statement of financial position. This standard is effective financial statements issued for annual periods beginning after December 15, 2016, and interim periods within those annual periods. Early application is permitted. The Company elected early application of this ASU as of December 31, 2015, and has applied its provisions prospectively. In April 2015, the FASB issued ASU No. 2015-03, Interest–Imputation of Interest (Subtopic 835-30)

2. Basis of Presentation and 25

2. Basis of Presentation and Significant Accounting Policies (Tables)	6 Months Ended
	Jun. 30, 2016
Accounting Policies [Abstract]
Weighted average shares common and diluted	Three Months Ended Six Months Ended June 30, June 30, 2016 2015 2016 2015 Weighted average common shares outstanding – basic 47,979,990 47,979,990 47,979,990 47,979,990 Plus: Potentially dilutive common shares: Stock options and warrants 78,689 – 76,583 – Weighted average common shares outstanding – diluted 48,058,679 47,979,990 48,056,573 47,979,990
Schedule of Capitalized Costs	Six Months Ended June 30, 2016 2015 Capitalized Certain Payroll and Other Internal Costs $ – $ – Capitalized Interest Costs 7,219 295,331 Total $ 7,219 $ 295,331

4. Debt Restructuring (Tables)

4. Debt Restructuring (Tables)	6 Months Ended
	Jun. 30, 2016
Restructuring and Related Activities [Abstract]
Loss from discontinued operations, net of income taxes	For the Three Months For the Six Months Ended June 30, Ended June 30, 2016 2015 2016 2015 Oil and gas sales $ 2,877,058 $ 5,050,080 $ 5,539,613 $ 7,936,536 Gain on settled derivatives 1,043,026 847,198 1,043,026 1,980,619 Loss on the mark-to-market of derivatives (4,272,849 ) (1,956,155 ) (4,288,736 ) (1,588,826 ) Total revenues (352,765 ) 3,941,123 2,293,903 8,328,329 Operating expenses: Production expenses 652,882 1,153,663 1,400,639 2,143,520 Production taxes 292,080 555,152 568,028 841,344 General and administrative 311,061 84,608 476,461 207,729 Depletion of oil and gas properties 1,091,843 2,937,744 3,114,347 5,567,776 Impairment of oil and gas properties – 21,639,000 5,219,000 21,639,000 Accretion of discount on asset retirement obligations 8,125 7,932 16,258 15,861 Total operating expenses 2,355,991 26,378,099 10,794,733 30,415,230 Net operating loss (2,708,756 ) (22,436,976 ) (8,500,830 ) (22,086,901 ) Other income (expense): Interest expense (261,898 ) (1,547,172 ) (1,696,544 ) (3,114,420 ) Total other income (expense) (261,898 ) (1,547,172 ) (1,696,544 ) (3,114,420 ) Loss before provision for income taxes (2,970,654 ) (23,984,148 ) (10,197,374 ) (25,201,321 ) Provision for income taxes – 5,957,649 – 6,593,040 Net income (loss) $ (2,970,654 ) $ (18,026,499 ) $ (10,197,374 ) $ (18,608,281 ) The assets and liabilities subject to the BRHC Transaction have been retroactively reclassified as assets and liabilities from discontinued operations on the Company’s balance sheet as of December 31, 2015. Assets and liabilities reclassified as assets and liabilities from discontinued operations as of December 31, 2015 consisted of the following: December 31, 2015 ASSETS Assets from discontinued operations, current Derivative instruments $ 1,154,400 Accounts receivable 5,038,146 Prepaid expenses 37,100 Total assets from discontinued operations, current 6,229,646 Assets from discontinued operations, long term Oil and natural gas properties, full cost method of accounting Proved properties 131,168,906 Unproved properties 10,394 Total oil and natural gas properties, full cost method of accounting 131,179,300 Less, accumulated depletion and allowance for impairment (99,371,070 ) Total assets from discontinued operations, long term 31,808,230 Total assets from discontinued operations $ 38,037,876 LIABILITIES Liabilities from discontinued operations, current Accounts payable $ 7,906,438 Accrued expenses 55,830 Current portion of revolving credit facility and long term debt 60,350,629 Total liabilities from discontinued operations, current 68,312,897 Liabilities from discontinued operations, long term Asset retirement obligations 368,089 Total liabilities from discontinued operations, long term 368,089 Total liabilities from discontinued operations $ 68,680,986

6. Property and Equipment (Tabl

6. Property and Equipment (Tables)	6 Months Ended
	Jun. 30, 2016
Property and equipment:
Property and equipment	June 30, December 31, 2016 2015 Property and equipment $ 139,004 $ 139,004 Less: Accumulated depreciation and amortization (105,221 ) (97,857 ) Total property and equipment, net $ 33,783 $ 41,147
Depreciation, depletion, and amortization expense	Six Months Ended June 30, 2016 2015 Depletion of costs for evaluated oil and gas properties (1) $ 3,114,347 $ 5,567,776 Depreciation and amortization of other property and equipment 7,364 8,276 Total depreciation, amortization and depletion $ 3,121,711 $ 5,576,052

7. Oil and Gas Properties (Tabl

7. Oil and Gas Properties (Tables)	6 Months Ended
	Jun. 30, 2016
Extractive Industries [Abstract]
Gross and net productive oil wells	June 21, 2016 June 30, 2015 Gross Net Gross Net North Dakota 352 10.64 286 8.59 Montana 5 0.37 5 0.37 Total 357 11.01 291 8.96
Capitalized costs	Six Months Ended June 30, 2016 2015 Purchases of oil and gas properties and development costs for cash $ 4,858,134 $ 12,677,179 Purchase of oil and gas properties accrued at period-end 3,155,016 9,203,387 Purchase of oil and gas properties accrued at beginning of period (prior to disposition) (6,899,503 ) (9,364,796 ) Capitalized asset retirement costs 4,737 41,695 Total purchase and development costs, oil and gas properties $ 1,118,384 $ 12,557,465

8. Asset Retirement Obligation

8. Asset Retirement Obligation (Tables)	6 Months Ended
	Jun. 30, 2016
Asset Retirement Obligation Disclosure [Abstract]
Asset retirement obligation	Six Months Ended June 30, 2016 2015 Beginning ARO $ 368,089 $ 286,804 Liabilities incurred for new wells placed in production 4,737 41,695 Accretion of discount on ARO 16,258 15,861 Liability relieved in debt restructuring (389,084 ) – Ending ARO $ – $ 344,360

10. Derivative Instruments (Tab

10. Derivative Instruments (Tables)	6 Months Ended
	Jun. 30, 2016
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Realized and unrealized gains and losses on derivative instruments	Six Months Ended June 30, 2016 2015 Realized gain on derivatives: Crude oil fixed price swaps $ 922,872 $ 1,589,818 Crude oil collars 120,154 390,801 Realized gain on derivatives, net $ 1,043,026 $ 1,980,619 Loss on the mark-to-market of derivatives: Crude oil fixed price swaps $ (4,157,491 ) $ (1,161,398 ) Crude oil collars (131,245 ) (427,428 ) Loss on the mark-to-market of derivatives, net $ (4,288,736 ) $ (1,588,826 )
Gross amounts of recognized derivative assets and liabilities	December 31, 2015 Gross Net Gross amounts amounts of amounts of offset assets recognized on balance on balance assets sheet sheet Commodity derivative assets $ 1,154,417 $ (17 ) $ 1,154,400 December 31, 2015 Gross Net Gross amounts amounts of amounts of offset liabilities recognized on balance on balance liabilities sheet sheet Commodity derivative liabilities $ – $ – $ –
Reconciliation of derivative assets and liabilities	December 31, 2015 Current assets from discontinued operations $ 1,154,400 Non-current assets from discontinued operations – Net amount of assets on the balance sheet 1,154,400 Current liabilities from discontinued operations – Non-current liabilities from discontinued operations – Net amounts of liabilities on the balance sheet – Total derivative assets, net $ 1,154,400

11. Fair Value of Financial I31

11. Fair Value of Financial Instruments (Tables)	6 Months Ended
	Jun. 30, 2016
Fair Value Disclosures [Abstract]
Valuation of financial instruments at fair value	Fair Value Measurements at June 30, 2016 Level 1 Level 2 Level 3 Assets Cash and cash equivalents $ 1,038,567 $ – $ – Derivative Instruments (crude oil swaps and collars) – – – Total assets 1,038,567 – – Liabilities Derivative Instruments (crude oil swaps and collars) – – – Revolving credit facilities and long term debt – – – Total Liabilities – – – $ 1,038,567 $ – $ – Fair Value Measurements at December 31, 2015 Level 1 Level 2 Level 3 Assets Cash and cash equivalents $ 228,194 $ – $ – Derivative Instruments (crude oil swaps and collars) – 1,154,400 – Total assets 228,194 1,154,400 – Liabilities Revolving credit facilities and long term debt – 60,350,629 – Total Liabilities – 60,350,629 – $ 228,194 $ (59,196,229) $ –

12. Revolving Credit Faciliti32

12. Revolving Credit Facilities and Long Term Debt (Tables)	6 Months Ended
	Jun. 30, 2016
Debt Disclosure [Abstract]
Revolving credit facility	December 31, 2015 Senior Revolving Credit Facility, Cadence Bank, N.A. $ 27,750,000 Subordinated Credit Agreement, Chambers 30,000,000 PIK Interest on Subordinated Credit Agreement, Chambers 2,600,629 Total credit facilities and long term debts 60,350,629 Less: Unamortized OID – Less: Unamortized debt discount attributable to warrants – Total credit facilities and long term debts, net of discounts 60,350,629 Less: current maturities (1) (60,350,629 ) Long term portion of credit facilities and long term debts $ –
Components of interest expense	Six Months Ended June 30, 2016 2015 Accrued PIK interest $ 330,740 $ 634,919 Amortization of OID – 84,858 Interest and commitment fees 1,373,023 2,177,431 Amortization of debt issuance costs – 190,780 Amortization of warrant costs – 321,763 Less interest capitalized to the full cost pool of our proved oil & gas properties (7,219 ) (295,331 ) $ 1,696,544 $ 3,114,420

2. Basis of Presentation and 33

2. Basis of Presentation and Significant Accounting Policies (Details Denominators) - shares	3 Months Ended		6 Months Ended
	Jun. 30, 2016	Jun. 30, 2015	Jun. 30, 2016	Jun. 30, 2015
Accounting Policies [Abstract]
Weighted average common shares outstanding - basic	47,979,990	47,979,990	47,979,990	47,979,990
Plus: Potentially dilutive common shares:
Stock options and warrants	78,689	0	76,583	0
Weighted average common shares outstanding - diluted	48,058,679	47,979,990	48,056,573	47,979,990

2. Basis of Presentation and 34

2. Basis of Presentation and Significant Accounting Policies (Details-Capitalized costs) - USD ($)	6 Months Ended
	Jun. 30, 2016	Jun. 30, 2015
Total capitalized costs	$ 7,219	$ 295,331
Certain Payroll and Other Internal Costs
Total capitalized costs	0	0
Capitalized Interest Costs
Total capitalized costs	$ 7,219	$ 295,331

2. Basis of Presentation and 35

2. Basis of Presentation and Significant Accounting Policies (Details Narrative) - USD ($)	3 Months Ended		6 Months Ended
	Jun. 30, 2016	Jun. 30, 2015	Jun. 30, 2016	Jun. 30, 2015	Dec. 31, 2015
Accounting Policies [Abstract]
Cash equivalents	$ 0		$ 0		$ 0
Cash in excess of insured limits	538,567		538,567		0
Unamortized balance of debt issuance costs	0		0		$ 0
Amortization of debt issuance costs charged to interest expense			0	$ 190,780
Website development costs capitalized	$ 56,660		56,660
Depreciation expense on website development costs			$ 0	$ 257
Stock options and warrants excluded to to being antidilutive	9,954,875	16,275,542	9,954,875	16,275,542
Depreciation of Non-Oil and Gas Property and Equipment			$ 7,364	$ 8,276
Non-cash ceiling test impairments			5,219,000	21,639,000
Share-based compensation expense			315,648	313,751
Amortization of warrant costs			$ 0	$ 321,763

4. Debt Restructuring (Details

4. Debt Restructuring (Details - Income Statement) - USD ($)	3 Months Ended		6 Months Ended
	Jun. 30, 2016	Jun. 30, 2015	Jun. 30, 2016	Jun. 30, 2015
Operating expenses:
Depletion of oil and gas properties			$ 3,114,347	$ 5,567,776
Other income (expense):
Net income (loss)	$ (2,970,654)	$ (18,026,499)	(10,197,374)	(18,608,281)
Discontinued Operations [Member]
Loss from discontinued items, net of income taxes
Oil and gas sales	2,877,058	5,050,080	5,539,613	7,936,536
Gain on settled derivatives	1,043,026	847,198	1,043,026	1,980,619
Loss on the mark-to-market of derivatives	(4,272,849)	(1,956,155)	(4,288,736)	(1,588,826)
Total revenues	(352,765)	3,941,123	2,293,903	8,328,329
Operating expenses:
Production expenses	652,882	1,153,663	1,400,639	2,143,520
Production taxes	292,080	555,152	568,028	841,344
General and administrative	311,061	84,608	476,461	207,729
Depletion of oil and gas properties	1,091,843	2,937,744	3,114,347	5,567,776
Impairment of oil and gas properties		21,639,000	5,219,000	21,639,000
Accretion of discount on asset retirement obligations	8,125	7,932	16,258	15,861
Total operating expenses	2,355,991	26,378,099	10,794,733	30,415,230
Net operating loss	(2,708,756)	(22,436,976)	(8,500,830)	(22,086,901)
Other income (expense):
Interest expense	(261,898)	(1,547,172)	(1,696,544)	(3,114,420)
Total other income (expense)	(261,898)	(1,547,172)	(1,696,544)	(3,114,420)
Loss before provision for income taxes	(2,970,654)	(23,984,148)	(10,197,374)	(25,201,321)
Provision for income taxes	0	5,957,649	0	6,593,040
Net income (loss)	$ (2,970,654)	$ (18,026,499)	$ (10,197,374)	$ (18,608,281)

4. Debt Restructuring (Detail37

4. Debt Restructuring (Details - Balance Sheet) - USD ($)	Jun. 30, 2016	Dec. 31, 2015
Assets from discontinued operations, current
Total assets from discontinued operations, current	$ 0	$ 6,229,646
Assets from discontinued operations, long term
Total assets from discontinued operations, long term	0	31,808,230
Liabilities from discontinued operations, current
Total liabilities from discontinued operations, current	0	68,312,897
Liabilities from discontinued operations, long term
Total liabilities from discontinued operations, long term	$ 0	368,089
Discontinued Operations [Member]
Assets from discontinued operations, current
Derivative instruments		1,154,400
Accounts receivable		5,038,146
Prepaid expenses		37,100
Total assets from discontinued operations, current		6,229,646
Assets from discontinued operations, long term
Proved properties		131,168,906
Unproved properties		10,394
Total oil and natural gas properties, full cost method of accounting		131,179,300
Less, accumulated depletion and allowance for impairment		(99,371,070)
Total assets from discontinued operations, long term		31,808,230
Total assets from discontinued operations		38,037,876
Liabilities from discontinued operations, current
Accounts payable		7,906,438
Accrued expenses		55,830
Current portion of revolving credit facility and long term debt		60,350,629
Total liabilities from discontinued operations, current		68,312,897
Liabilities from discontinued operations, long term
Asset retirement obligations		368,089
Total liabilities from discontinued operations, long term		368,089
Total liabilities from discontinued operations		$ 68,680,986

4. Debt Restructuring (Detail38

4. Debt Restructuring (Details Narrative) - USD ($)	3 Months Ended		6 Months Ended
	Jun. 30, 2016	Jun. 30, 2015	Jun. 30, 2016	Jun. 30, 2015
Gain on debt restructuring	$ 41,621,150	$ 0	$ 41,621,150	$ 0
Black Ridge Holding Company [Member]
Ownership percentage	3.88%		3.88%

6. Property and Equipment (Deta

6. Property and Equipment (Details-Property and equipment) - USD ($)	Jun. 30, 2016	Dec. 31, 2015
Property and equipment:
Property and equipment	$ 139,004	$ 139,004
Less: Accumulated depreciation, amortization and depletion	(105,221)	(97,857)
Total property and equipment, net	$ 33,783	$ 41,147

6. Property and Equipment (De40

6. Property and Equipment (Details-Depreciation) - USD ($)	3 Months Ended		6 Months Ended
	Jun. 30, 2016	Jun. 30, 2015	Jun. 30, 2016	Jun. 30, 2015
Property and equipment:
Depletion of costs for evaluated oil and gas properties			$ 3,114,347	$ 5,567,776
Depreciation and amortization of other property and equipment	$ 3,479	$ 4,009	7,364	8,276
Total depreciation, amortization and depletion			$ 3,121,711	$ 5,576,052

6. Property and Equipment (De41

6. Property and Equipment (Details Narrative) - USD ($)	6 Months Ended
	Jun. 30, 2016	Jun. 30, 2015
Property and equipment:
Non-cash ceiling test impairments	$ 5,219,000	$ 21,639,000

7. Oil and Gas Properties (Deta

7. Oil and Gas Properties (Details-Wells) - Wells	Jun. 30, 2016	Jun. 30, 2015
Productive oil wells, gross	357	291
Productive oil wells, net	11.01	8.96
North Dakota
Productive oil wells, gross	352	286
Productive oil wells, net	10.64	8.59
Montana
Productive oil wells, gross	5	5
Productive oil wells, net	.37	0.37

7. Oil and Gas Properties (De43

7. Oil and Gas Properties (Details-Development costs) - USD ($)	6 Months Ended
	Jun. 30, 2016	Jun. 30, 2015
Extractive Industries [Abstract]
Purchases of oil and gas properties and development costs for cash	$ 4,858,134	$ 12,677,179
Purchase of oil and gas properties accrued at period-end	3,155,016	9,203,387
Purchase of oil and gas properties accrued at the beginning of period (prior to disposition)	(6,899,503)	(9,364,796)
Advances to operators applied to development of oil and gas properties	0	4,285,575
Capitalized asset retirement costs, net of revision in estimate	4,737	41,695
Total purchase and development costs, oil and gas properties	$ 1,118,384	$ 12,557,465

7. Oil and Gas Properties (De44

7. Oil and Gas Properties (Details Narrative)	6 Months Ended
	Jun. 30, 2016USD ($)a	Jun. 30, 2015USD ($)a
Oil and Gas Exploration and Production Industries Disclosures [Abstract]
Oil and gas assets, net acres | a	7,016	8,566
Oil and gas acreage acquired | a	0	9
Oil and gas properties acquired, cost | $	$ 0	$ 102,928
Oil and gas acreage sold | a	14	9
Proceeds from oil and gas diverstitures | $	$ 94,628	$ 103,000
Disposition of oil and gas properties | $	$ 24,498,638
Undeveloped acreage expirations | a		1,079
Undeveloped agreage expirations carrying costs | $		$ 650,816

8. Asset Retirement Obligatio45

8. Asset Retirement Obligation (Details) - USD ($)	6 Months Ended
	Jun. 30, 2016	Jun. 30, 2015
Asset retirement rollforward
Beginning Asset Retirement Obligation	$ 368,089	$ 286,804
Liabilities incurred for new wells placed in production	4,737	41,695
Accretion of discount on asset retirement obligations	16,258	15,861
Liability relieved in debt restructuring	(389,084)	0
Ending asset retirement obligation	$ 0	$ 344,360

9. Related Party (Details Narra

9. Related Party (Details Narrative) - USD ($)	6 Months Ended
	Jun. 30, 2016	Jun. 30, 2015
Related Party Transactions [Abstract]
Rent expense	$ 36,183	$ 35,128

10. Derivative Instruments (Det

10. Derivative Instruments (Details-Derivative Gains and Losses) - USD ($)	6 Months Ended
	Jun. 30, 2016	Jun. 30, 2015
Realized gain on derivatives, net	$ 1,043,026	$ 1,980,619
Loss on the mark-to-market of derivatives, net	(4,288,736)	(1,588,826)
Crude Oil Fixed Price Swap [Member]
Realized gain on derivatives, net	922,872	1,589,818
Loss on the mark-to-market of derivatives, net	(4,157,491)	(1,161,398)
Crude Oil Collars [Member]
Realized gain on derivatives, net	120,154	390,801
Loss on the mark-to-market of derivatives, net	$ (131,245)	$ (427,428)

10. Derivative Instruments (D48

10. Derivative Instruments (Details-Balance sheet derivatives)	Dec. 31, 2015USD ($)
Commodity derivative assets	$ 1,154,400
Commodity derivative liabilities	0
Gross amounts recognized
Commodity derivative assets	1,154,417
Commodity derivative liabilities	0
Gross amounts offset on balance sheet
Commodity derivative assets	(17)
Commodity derivative liabilities	$ 0

10. Derivative Instruments (D49

10. Derivative Instruments (Details-Reconciliation of derivatives)	Dec. 31, 2015USD ($)
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Current assets from discontinued operations	$ 1,154,000
Non-current assets from discontinued operations	0
Net amount of assets on the balance sheet	1,154,400
Current liabilities from discontinued operations	0
Non-current liabilities from discontinued operations	0
Net amounts of liabilities on the balance sheet	0
Total derivative assets, net	$ 1,154,400

10. Derivative Instruments (D50

10. Derivative Instruments (Details Narrative)	Jun. 30, 2016USD ($)Integer
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Outstanding derivative contracts | Integer	0
Value of derivative contracts transferred | $	$ 3,134,336

11. Fair Value of Financial I51

11. Fair Value of Financial Instruments (Details-Recurring basis) - USD ($)	Jun. 30, 2016	Dec. 31, 2015
Fair Value Inputs Level1 [Member]
Assets
Cash and cash Equivalents		$ 228,194
Derivative Instruments (crude oil swaps and collars)		0
Total assets		228,194
Liabilities
Revolving credit facilities and long term debt, net of discounts		0
Total Liabilities		0
Total Assets and Liablilties		228,194
Fair Value Inputs Level2 [Member]
Assets
Cash and cash Equivalents		0
Derivative Instruments (crude oil swaps and collars)		1,154,400
Total assets		1,154,400
Liabilities
Revolving credit facilities and long term debt, net of discounts		60,350,629
Total Liabilities		60,350,629
Total Assets and Liablilties		(59,196,229)
Fair Value Inputs Level3 [Member]
Assets
Cash and cash Equivalents		0
Derivative Instruments (crude oil swaps and collars)		0
Total assets		0
Liabilities
Revolving credit facilities and long term debt, net of discounts		0
Total Liabilities		0
Total Assets and Liablilties		$ 0
Fair Value, Measurements, Recurring [Member] | Fair Value Inputs Level1 [Member]
Assets
Cash and cash Equivalents	$ 1,038,567
Derivative Instruments (crude oil swaps and collars)	0
Total assets	1,038,567
Liabilities
Revolving credit facilities and long term debt, net of discounts	0
Total Liabilities	0
Total Assets and Liablilties	1,038,567
Fair Value, Measurements, Recurring [Member] | Fair Value Inputs Level2 [Member]
Assets
Cash and cash Equivalents	0
Derivative Instruments (crude oil swaps and collars)	0
Total assets	0
Liabilities
Revolving credit facilities and long term debt, net of discounts	0
Total Liabilities	0
Total Assets and Liablilties	0
Fair Value, Measurements, Recurring [Member] | Fair Value Inputs Level3 [Member]
Assets
Cash and cash Equivalents	0
Derivative Instruments (crude oil swaps and collars)	0
Total assets	0
Liabilities
Revolving credit facilities and long term debt, net of discounts	0
Total Liabilities	0
Total Assets and Liablilties	$ 0

12. Revolving Credit Faciliti52

12. Revolving Credit Facilities and Long Term Debt (Details)	Dec. 31, 2015USD ($)
Total credit facilities and long term debts	$ 60,350,629
Less: Unamortized OID	0
Less: Unamortized debt discount attributable to warrants	0
Total credit facilities and long term debts, net of discounts	60,350,629
Less: current maturities	(60,350,629)
Long term portion of credit facilities and long term debts	0
Senior Revolving Credit Facility, Cadence Bank, N.A. [Member]
Total credit facilities and long term debts	27,750,000
Subordinated Credit Agreement, Chambers [Member]
Total credit facilities and long term debts	30,000,000
PIK Interest on Subordinated Credit Agreement, Chambers [Member]
Total credit facilities and long term debts	$ 2,600,629

12. Revolving Credit Faciliti53

12. Revolving Credit Facilities and Long Term Debt (Details-Interest expense) - USD ($)	6 Months Ended
	Jun. 30, 2016	Jun. 30, 2015
Interest expense, debt	$ 1,696,544	$ 3,114,420
Accrued PIK interest
Interest expense, debt	330,740	634,919
Amortization of OID
Interest expense, debt	0	84,858
Interest and commitment fees
Interest expense, debt	1,373,023	2,177,431
Amortization of debt issuance costs
Interest expense, debt	0	190,780
Amortization of warrant costs
Interest expense, debt	0	321,763
Interest capitalized
Interest expense, debt	$ (7,219)	$ (295,331)

12. Revolving Credit Faciliti54

12. Revolving Credit Facilities and Long Term Debt (Details Narrative) - Line of Credit [Member] - USD ($)	12 Months Ended
	Dec. 31, 2015	Jun. 30, 2016
Senior Credit Facility
Maximum borrowing capacity	$ 32,000,000
Line of credit outstanding	27,750,000
Senior Credit Facility | Black Ridge Holding Company [Member]
Line of credit outstanding		$ 0
Line of credit balance transferred to BRHC		29,400,000
Subordinated Credit Facility
Line of credit outstanding	$ 30,000,000
Warrants issued with debt	5,000,000
Warrant expiration date	Aug. 8, 2018
Subordinated Credit Facility | Black Ridge Holding Company [Member]
Line of credit outstanding		0
Line of credit balance transferred to BRHC		30,000,000
Accrued interest transferred to BRHC		$ 2,931,369

13. Changes in Stockholders' 55

13. Changes in Stockholders' Equity (Details Narrative) - $ / shares	Jun. 30, 2016	Dec. 31, 2015
Equity [Abstract]
Preferred stock, par value (in Dollars per share)	$ 0.001	$ 0.001
Preferred stock, shares authorized	20,000,000	20,000,000
Common stock, par value (in Dollars per share)	$ 0.001	$ 0.001
Common stock, shares authorized	500,000,000	500,000,000

14. Options (Details Narrative)

14. Options (Details Narrative) - USD ($)	6 Months Ended
	Jun. 30, 2016	Jun. 30, 2015
Compensation expense	$ 315,648	$ 313,751
Unamortized fair value of options	$ 1,176,572
Options exercised	0	0
Options forfeited	0	0
Options
Options granted	0	0

15. Warrants (Details Narrative

15. Warrants (Details Narrative) - USD ($)	6 Months Ended
	Jun. 30, 2016	Jun. 30, 2015
Amortization of warrant costs	$ 0	$ 321,763
Warrants
Warrants granted	0	0
Warrants exercised	0	0
Warrants expired	500,000
Warrants cancelled	5,000,000
Warrants forfeited	0

16. Income Taxes (Details Narra

16. Income Taxes (Details Narrative) - USD ($)	3 Months Ended		6 Months Ended
	Jun. 30, 2016	Jun. 30, 2015	Jun. 30, 2016	Jun. 30, 2015
Income Tax Disclosure [Abstract]
Deferred tax assets, net	$ 11,537,106		$ 11,537,106
Deferred tax liabilities	4,962		4,962
Deferred tax assets, valuation allowance	11,537,106		11,537,106
Tax benefit	0	$ 0	0	$ 0
Uncertain tax positions	$ 0		$ 0
Effective tax rate			0.00%