Saratoga Resources (SARAQ) 10-K 15 Apr 15 2014 FY Annual report Financial data

Document_and_Entity_Informatio

Document and Entity Information (USD $)	12 Months Ended
	Dec. 31, 2014	Apr. 10, 2015	Jun. 30, 2014
Document And Entity Information
Entity Registrant Name	SARATOGA RESOURCES INC /TX
Entity Central Index Key	1096339
Document Type	10-K
Document Period End Date	31-Dec-14
Amendment Flag	FALSE
Current Fiscal Year End Date	-19
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 Public Float			$27,300,000
Entity Common Stock, Shares Outstanding		30,986,601
Document Fiscal Period Focus	FY
Document Fiscal Year Focus	2014

Consolidated_Balance_Sheets

Consolidated Balance Sheets (USD $)	Dec. 31, 2014	Dec. 31, 2013
Current assets:
Cash and cash equivalents	$10,911,070	$32,547,380
Accounts receivable	3,778,808	6,758,572
Prepaid expenses and other	1,006,758	1,056,350
Other current assets	150,000	150,000
Total current assets	15,846,636	40,512,302
Property and equipment:
Oil and gas properties, proved (successful efforts method)	301,399,079	286,441,663
Other	1,031,779	892,694
Less: Accumulated depreciation, depletion and amortization	-226,716,401	-101,088,696
Total property and equipment, net	75,714,457	186,245,661
Other assets, net	20,350,655	21,665,830
Total assets	111,911,748	248,423,793
Current liabilities:
Accounts payable	6,722,116	5,391,648
Revenue and severance tax payable	2,711,229	3,754,812
Accrued liabilities	13,006,617	9,807,935
Derivative liabilities, short term	117	837,758
Short-term notes payable	329,964	338,512
First lien notes, net of discount	54,448,831	0
Second lien notes, net of discount	124,352,053	0
Total current liabilities	201,570,927	20,130,665
Long-term liabilities:
Asset retirement obligation	16,397,804	12,649,458
Long-term debt, net of unamortized discount	0	178,196,984
Derivative liabilities	0	182,174
Total long-term liabilities	16,397,804	191,028,616
Commitment and contingencies (see notes)
Stockholders' equity (deficit):
Common stock	30,987	30,947
Additional paid-in capital	78,754,854	78,165,364
Retained deficit	-184,842,824	-40,931,799
Total stockholders' equity (deficit)	-106,056,983	37,264,512
Total liabilities and stockholders' equity (deficit)	$111,911,748	$248,423,793

Consolidated_Balance_Sheets_Pa

Consolidated Balance Sheets (Parenthetical) (USD $)	Dec. 31, 2014	Dec. 31, 2013
Statement of Financial Position [Abstract]
First lien notes payable unamortized discount	$151,169	$0
Second lien notes payable unamortized discount	847,947	0
Long-term debt unamortized discount	$0	$1,603,016
Common stock par value (in U.S. dollars per share)	$0.00	$0.00
Common stock authorized	100,000,000	100,000,000
Common stock issued	30,986,601	30,946,601
Common stock outstanding	30,986,601	30,946,601

Consolidated_Statements_of_Ope

Consolidated Statements of Operations and Other Comprehensive Loss (USD $)	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2013
Revenues:
Oil and gas revenues	$52,325,716	$68,696,055
Oil and gas hedging	1,550,871	-1,701,569
Other revenues	477,493	420,429
Total revenues	54,354,080	67,414,915
Operating Expense:
Lease operating expense	24,631,620	21,685,103
Workover expense	4,537,031	2,475,541
Exploration expense	706,904	900,255
Loss on plugging and abandonment	0	701,241
Depreciation, depletion and amortization	17,853,499	17,269,349
Impairment expense	107,774,206	2,179,075
Accretion expense	1,793,865	2,552,381
Gain on revision of asset retirement obligations	-75,178	-564,719
General and administrative	9,549,430	9,253,600
Severance taxes	3,649,814	7,274,808
Arbitration loss	3,400,000	0
Total operating expenses	173,821,191	63,726,634
Operating income (loss)	-119,467,111	3,688,281
Other income (expense):
Interest income	48,328	16,197
Interest expense	-24,302,387	-21,466,162
Total other expense	-24,254,059	-21,449,965
Net loss before reorganization expenses and income taxes	-143,721,170	-17,761,684
Reorganization expense	0	2,319
Net loss before income taxes	-143,721,170	-17,764,003
Income tax expense (benefit)	189,855	8,630,456
Net loss	-143,911,025	-26,394,459
Other Comprehensive Income
Unrealized gain (loss) on derivative instruments	0	171,086
Total comprehensive loss	($143,911,025)	($26,223,373)
Net income per share:
Basic	($4.65)	($0.85)
Diluted	($4.65)	($0.85)
Weighted average number of common shares outstanding:
Basic	30,967,533	30,932,541
Diluted	30,967,533	30,932,541

Consolidated_Statements_of_Sto

Consolidated Statements of Stockholders' Equity (Deficit) (USD $)	Common Stock	Additional Paid-In Capital	Net (Loss)	Other Comprehensive Loss	Total
Beginning balance at Dec. 31, 2012	$30,905	$77,140,451	($14,537,340)	($171,086)	$62,462,930
Beginning balance - shares at Dec. 31, 2012	30,905,101
Common stock options exercised	7	9,938			9,945
Common stock options exercised - shares	6,500
Common stock warrants exercised	35	13,815			13,850
Common stock warrants exercised - shares	35,000
Stock-based employee compensation		1,001,160			1,001,160
Other comprehensive income (loss)				171,086	171,086
Net loss			-26,394,459		-26,394,459
Ending balance at Dec. 31, 2013	30,947	78,165,364	-40,931,799	0	37,264,512
Ending balance - shares at Dec. 31, 2013	30,946,601
Common stock options exercised	40	61,160			61,200
Common stock options exercised - shares	40,000
Stock-based employee compensation		528,330			528,330
Other comprehensive income (loss)				0	0
Net loss			-143,911,025		-143,911,025
Ending balance at Dec. 31, 2014	$30,987	$78,754,854	($184,842,824)	$0	($106,056,983)
Ending balance - shares at Dec. 31, 2014	30,986,601

Consolidated_Statements_of_Cas

Consolidated Statements of Cash Flows (USD $)	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2013
Cash flows from operating activities:
Net income (loss)	($143,911,025)	($26,394,459)
Adjustments to reconcile net income (loss) to net cash used in operating activities:
Depreciation, depletion and amortization	17,853,499	17,269,349
Impairment expense	107,774,206	2,179,075
Accretion expense	1,793,865	2,552,381
Amortization of debt issuance costs and debt discount	3,171,973	1,959,218
Unrealized (gain) loss on hedges	-1,640,315	1,019,932
Stock-based compensation	528,330	1,001,160
Loss on plugging and abandonment	0	701,241
Gain on revision of asset retirement obligations	-75,178	-564,719
Deferred tax provision (benefit)	0	8,499,575
Changes in operating assets and liabilities:
Accounts receivable	2,979,764	5,671,586
Prepaids and other	1,656,870	1,735,926
Accounts payable	1,961,581	-3,419,534
Revenue and severance tax payable	-1,043,583	-2,375,055
Payments to settle asset retirement obligations	0	-1,229,042
Accrued liabilities	3,898,982	-1,058,909
Net cash provided by (used) by operating activities	-5,051,031	7,547,725
Cash flows from investing activities:
Additions to oil and gas property	-13,638,670	-29,776,182
Additions to other property and equipment	-139,085	-97,556
Other assets	-959,571	-1,157,161
Net cash used by investing activities	-14,737,326	-31,030,899
Cash flows from financing activities:
Proceeds from issuance of common stock	61,200	23,795
Proceeds from long term debt	0	27,300,000
Repayment of short-term notes payable	-1,615,826	-1,558,152
Debt issuance costs of long-term debt	-293,327	-2,037,402
Net cash provided by (used ) by financing activities	-1,847,953	23,728,241
Net increase (decrease) in cash and cash equivalents	-21,636,310	245,067
Cash and cash equivalents, beginning of period	32,547,380	32,302,313
Cash and cash equivalents, end of period	10,911,070	32,547,380
Supplemental disclosures of cash flow information:
Cash paid for income taxes	157,355	130,881
Cash paid for interest	19,765,423	19,815,440
Non-cash investing and financing activities:
Unrealized gain (loss) on derivative instruments	0	171,086
Accounts payable for oil and gas additions	920,824	1,551,937
Accrued liabilities for oil and gas additions	0	79,800
Revisions to asset retirement obligations	2,004,893	-6,509,866
Additions to asset retirement obligations	24,766	62,808
Prepaid insurance financed with debt	1,607,278	1,523,305
Senior secured notes exchanged for first lien notes	$0	$23,000,000

Organization_and_Summary_of_Si

Organization and Summary of Significant Accounting Policies	12 Months Ended
	Dec. 31, 2014
Organization, Consolidation and Presentation of Financial Statements [Abstract]
Organization and Summary of Significant Accounting Policies	NOTE 1. ORGANIZATION AND SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES
	Organization and Principles of Consolidation
	Saratoga Resources, Inc. is an independent oil and natural gas company engaged in the production, development, acquisition and exploitation of natural gas and crude oil properties.
	Our financial statements include the accounts of Saratoga Resources, Inc., a Texas corporation, and its subsidiaries. We proportionately consolidate our interests in oil and gas exploration and production ventures and partnerships in accordance with industry practice. All significant intercompany balances and transactions have been eliminated. Unless otherwise specified or the context otherwise requires, all references in these notes to “Saratoga”, “Company” “we,” “us” or “our” are to Saratoga Resources, Inc., and its subsidiaries.
	Accounting for Reorganization
	On March 31, 2009, Saratoga and its subsidiaries, all of which are 100%-owned: Harvest Oil and Gas, LLC, The Harvest Group, LLC, Lobo Operating, Inc. and Lobo Resources, Inc. (collectively the “Debtors”), filed voluntary petitions under Chapter 11 of the U.S. Bankruptcy Code. The Debtors operated under Chapter 11 protection from the filing date on March 31, 2009 until the effective date of the Debtors’ plan of reorganization (the “Plan of Reorganization”) and exit from Chapter 11 on May 14, 2010. The accompanying consolidated financial statements of Saratoga have been prepared in accordance with FASB ASC 852, Reorganizations. The Company incurred expenses relating to the Plan of Reorganization of $2,319, during the year ended December 31, 2013.
	Use of Estimates
	The preparation of financial statements in conformity with accounting principles generally accepted in the United States of America requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities at the date of the financial statements and the reported amounts of revenues and expenses during the reporting period. Actual results could differ from those estimates. Material estimates that are particularly susceptible to significant change in the near term include the determination of depreciation, depletion and amortization, plugging and abandonment liabilities, and the valuation of oil and gas property.
	Reclassifications
	Certain reclassifications have been made to prior years’ reported amounts in order to conform to the current year presentation. These reclassifications did not impact our net income, stockholders’ equity or cash flows.
	Dependence on Oil and Gas Prices
	As an independent oil and gas producer, our revenue, profitability and future rate of growth are substantially dependent on prevailing prices for natural gas and oil. Historically, the energy markets have been very volatile, and there can be no assurance that oil and gas prices will not be subject to wide fluctuations in the future. Prices for crude oil have recently declined materially. Any continued and extended decline in oil or gas prices could have a material adverse effect on our financial position, results of operations, cash flows and access to capital and on the quantities of oil and gas reserves that we can economically produce.
	Revenue Recognition
	We recognize oil and gas revenue from interests in producing wells as the oil and gas is sold. Revenue from the purchase, transportation, and sale of natural gas is recognized upon completion of the sale and when transported volumes are delivered. We recognize revenue related to gas balancing agreements based on the sales method. Our net imbalance position at December 31, 2014 and 2013 was immaterial.
	Concentration of Credit Risk
	Financial instruments that potentially subject the Company to a concentration of credit risk include cash, cash equivalents and any marketable securities. The Company had cash deposits of approximately $10.7 million and $32.3 million in excess of FDIC insured limits at December 31, 2014 and 2013, respectively. The Company has not experienced any losses on its deposits of cash and cash equivalents.
	Major Customers
	Sales of oil and gas production to Shell Trading (US) Company and Shell Energy North America (US), L.P. (collectively “Shell”) and Chevron Natural Gas, Inc. and Chevron Products Company (collectively “Chevron”) accounted for 50% and 37%, respectively, of our consolidated sales in 2014. Sales of oil and gas production to Shell and Chevron accounted for 57% and 32%, respectively, of our consolidated sales in 2013. We believe that the loss of any of these purchasers would not have a material adverse effect on us because alternative purchasers are readily available.
	Other Revenue
	Other revenues consist principally of production handling charges and an insurance reimbursement for a loss incurred in a prior year.
	Cash and Cash Equivalents
	For the purpose of the Statement of Cash Flows, we consider all highly liquid investments with an original maturity of three months or less to be cash equivalents.
	Accounts Receivable
	Receivables are carried at original invoice amount. Uncollectible accounts receivable are charged directly against earnings when they are determined to be uncollectible. Use of this method does not result in a material difference from the valuation method required by generally accepted accounting principles. At December 31, 2014 and 2013, no reserve for allowance for doubtful accounts was needed.
	Oil and Gas Operations
	Oil and gas exploration and development costs are accounted for using the successful efforts method of accounting.
	Oil and gas leasehold acquisition costs are capitalized and included in the balance sheet caption properties, plants and equipment. Leasehold impairment is recognized based on exploratory experience and management’s judgment. Upon achievement of all conditions necessary for the classification of reserves as proved, the associated leasehold costs are reclassified into proved properties.
	Oil and gas exploration costs and the costs of carrying and retaining undeveloped properties are expensed as incurred. Exploratory well costs are capitalized, or “suspended,” on the balance sheet pending further evaluation of whether economically recoverable reserves have been found. If economically recoverable reserves are not found, exploratory well costs are expensed as dry holes. If exploratory wells encounter potentially economic quantities of oil and gas, the well costs remain capitalized on the balance sheet as long as sufficient progress assessing the reserves and the economic and operating viability of the project is being made. For complex exploratory discoveries, it is not unusual to have exploratory wells remain suspended on the balance sheet for several years while we perform additional appraisal drilling and seismic work on the potential oil and gas field, or while we seek government or co-venture approval of development plans or seek environmental permitting. Once all required approvals and permits have been obtained, the projects are moved into the development phase, and the oil and gas reserves are designated as proved reserves.
	Oil and gas development costs incurred to drill and equip development wells, including unsuccessful development wells, are capitalized.
	Depreciation, depletion and amortization of the cost of proved oil and gas properties is calculated using the unit-of-production method. The reserve base used to calculate depreciation, depletion and amortization for leasehold acquisition costs and the cost to acquire proved properties is the sum of proved developed reserves and proved undeveloped reserves. With respect to lease and well equipment costs, which include development costs and successful exploration drilling costs, the reserve base includes only proved developed reserves. Estimated future dismantlement, restoration and abandonment costs, net of salvage values, are taken into account. Depletion expense for the years ended December 31, 2014 and 2013 was $17,741,322 and $17,145,473, respectively.
	Assets are grouped in accordance with the Extractive Industries - Oil and Gas Topic of the Financial Accounting Standards Board (FASB) Accounting Standards Codification (ASC). The basis for grouping is a reasonable aggregation of properties with a common geological structural feature or stratigraphic condition, such as a reservoir or field.
	Amortization rates are updated quarterly to reflect: 1) the addition of capital costs, 2) reserve revisions (upwards or downwards) and additions, 3) property acquisitions and/or property dispositions and 4) impairments.
	When circumstances indicate that an asset may be impaired, Saratoga compares expected undiscounted future cash flows at a producing field level to the unamortized capitalized cost of the asset. If the future undiscounted cash flows, based on Saratoga’s estimate of future natural gas and crude oil prices, operating costs, anticipated production from proved reserves and other relevant data, are lower than the unamortized capitalized cost, the capitalized cost is reduced to fair value. Fair value is calculated by discounting the future cash flows at an appropriate risk-adjusted discount rate. During the years ended December 31, 2014 and 2013, Saratoga recorded impairment expense of $107,774,206 and $2,179,075, respectively. The impairment expense during 2014 reflected the reclassification of certain reserves out of the proved undeveloped category and into the probable category due to application of the SEC's "five year rule" and the steep decline in commodity prices which resulted in the expected undiscounted future cash flows at a producing field level to be less than the unamortized capitalized cost of assets in several fields. The impairment expense during 2013 related to the loss of a lease, and associated reserves, at one field.
	We record the fair value of legal obligations to retire and remove long-lived assets in the period in which the obligation is incurred (typically when the asset is installed at the production location). When the liability is initially recorded, we capitalize this cost by increasing the carrying amount of the related properties, plants and equipment. Over time the liability is increased for the change in its present value, and the capitalized cost in properties, plants and equipment is depreciated over the useful life of the related asset.
	Environmental expenditures are expensed or capitalized, depending upon their future economic benefit. Expenditures that relate to an existing condition caused by past operations, and do not have a future economic benefit, are expensed. Liabilities for environmental expenditures are recorded on an undiscounted basis (unless acquired in a purchase business combination) when environmental assessments or cleanups are probable and the costs can be reasonably estimated. Recoveries of environmental remediation costs from other parties, such as state reimbursement funds, are recorded as assets when their receipt is probable and estimable.
	See Note 8 – “Oil and Gas Assets”.
	Derivative Instruments and Hedging Activities
	All derivative instruments are recorded in our consolidated balance sheets as either an asset or liability and measured at fair value. Changes in the derivative instrument’s fair value are recognized currently in earnings, unless the derivative instrument has been designated as a cash flow hedge and specific cash flow hedge accounting criteria are met. Under cash flow hedge accounting, unrealized gains and losses are reflected in shareholders’ equity as accumulated other comprehensive income (loss) (OCI) until the forecasted transaction occurs. The derivative’s gains or losses are then offset against related results on the hedged transaction in the statements of operations.
	The Company must formally document, designate and assess the effectiveness of transactions that receive hedge accounting. Only derivative instruments that are expected to be highly effective in offsetting anticipated gains or losses on the hedged cash flows and that are subsequently documented to have been highly effective can qualify for hedge accounting. Effectiveness must be assessed both at inception of the hedge and on an ongoing basis. Any ineffectiveness in hedging instruments whereby gains or losses do not exactly offset anticipated gains or losses of hedged cash flows is measured and recognized in earnings in the period in which it occurs. When using hedge accounting, we assess hedge effectiveness quarterly based on total changes in the derivative instrument’s fair value by performing regression analysis. A hedge is considered effective if certain statistical tests are met. We record hedge ineffectiveness in oil and gas hedging. At December 31, 2014, none of our hedges qualified for hedge accounting. At December 31, 2013, none of our hedges met the statistical tests for effectiveness.
	We designate our commodity derivative instruments as cash flow hedges. Changes in the fair value commodity derivative instruments used as cash flow hedges are reported in OCI, to the extent the hedge is effective, until the forecasted transaction occurs, at which time they are recognized in earnings.
	See Note 6 – “Derivative Instruments and Hedging Activities”.
	Depreciation of Other Property and Equipment
	Furniture, fixtures, equipment, and other assets are depreciated using the straight-line method over the estimated useful lives of the assets. The estimated lives of these assets range from three to five years.
	Debt Issuance Costs and Debt Discount
	Debt issuance costs incurred are capitalized and amortized, using the interest method, over the term of the related debt.
	The amount of discount at which debt is has been issued is amortized into interest expense, using the interest method, over the term of the related debt.
	Stock Based Compensation
	In accordance with the provisions of the Stock Compensation Topic of the ASC (ASC Topic 718), Saratoga measures the cost of employee services received in exchange for an award of equity instruments based on the grant-date fair value of the award.
	Income Taxes
	We account for income taxes under the provisions of the Income Taxes Topic of the ASC (ASC Topic 740). ASC Topic 740 requires the asset and liability approach for accounting for income taxes. Under this approach, deferred tax assets and liabilities are recognized based on anticipated future tax consequences attributable to differences between financial statement carrying amounts of assets and liabilities and their respective tax basis.
	We routinely assess the realizability of our deferred tax assets. If we conclude that it is more likely than not that some portion or all of the deferred tax assets will not be realized under accounting standards, the tax asset is reduced by a valuation allowance. At December 31, 2014 and 2013, a valuation allowance was provided for the entire balance of the net deferred tax asset in the amount of $64,480,235 and $13,837,850, respectively. In addition we routinely assess uncertain tax positions, and accrue for tax positions that are not more-likely-than-not to be sustained upon examination by taxing authorities.
	See Note 12 – “Income Taxes”.
	Net Income Per Share
	Basic net income per share is computed on the basis of the weighted-average number of common shares outstanding during the periods. Diluted net income per share is computed based upon the weighted-average number of common shares plus the assumed issuance of common shares for all potentially dilutive securities (see Note 11 – “Common Stock”).
	Recently Issued Accounting Standards and Developments
	In May 2014, the Financial Accounting Standards Board ("FASB") issued Accounting Standards Update ("ASU") 2014?09, Revenue from Contracts with Customers (Topic 606) ("ASU 2014-09"), which supersedes nearly all existing revenue recognition guidance under existing generally accepted accounting principles. This new standard is based upon the principal that revenue is recognized to depict the transfer of goods or services to customers in an amount that reflects the consideration to which the entity expects to be entitled in exchange for those goods or services. ASU 2014-09 also requires additional disclosure about the nature, amount, timing and uncertainty of revenue and cash flows arising from customer contracts. ASU 2014-09 is effective for annual and interim periods beginning after December 15, 2016. Early adoption is not permitted and entities have the option of using either a retrospective or modified approach to adopt ASU 2014-09. The Company is currently evaluating the new guidance and has not determined the impact this standard may have on its financial statements or decided upon the method of adoption.
	In August 2014, the FASB issued ASU No. 2014-15, Presentation of Financial Statements - Going Concern (Subtopic 205-40): Disclosure of Uncertainties about an Entity's Ability to Continue as a Going Concern ("ASU 2014-15"). ASU 2014-15 provides guidance about management's responsibility to evaluate whether there is substantial doubt about an entity's ability to continue as a going concern and sets rules for how this information should be disclosed in the financial statements. ASU 2014-15 is effective for annual periods ending after December 15, 2016 and interim periods thereafter. The Company plans to adopt ASU 2014-15 prospectively for the annual period ending December 31, 2016. Pursuant to ASU 2014-15, the Company is required to consider whether there are adverse conditions or events that raise substantial doubt about the Company's ability to continue as a going concern within one year after the date that the financial statements are issued and the probability that management's plans will mitigate the adverse conditions or events (if any). Adverse conditions or events would include, but not be limited to, negative financial trends (such as recurring operating losses, working capital deficiencies, or insufficient liquidity), a need to restructure outstanding debt to avoid default, and industry developments (for example commodity price declines and regulatory changes).

Going_Concern

Going Concern	12 Months Ended
	Dec. 31, 2014
Going Concern
Going Concern	NOTE 2. GOING CONCERN
	The accompanying consolidated financial statements have been prepared in conformity with accounting principles accepted in the United States of America which contemplate the continuation of the Company as a going concern. The Company incurred a loss from operations of $119,467,111 for the year ended December 31, 2014 and has a working capital deficit of $185,724,291 at December 31, 2014. These conditions raise substantial doubt as to the Company’s ability to continue as a going concern. These financial statements do not include any adjustments that might be necessary if the Company is unable to continue as a going concern.
	To address these matters, the Company is seeking to restructure its debt, or find alternative sources of financing. There can be no assurance that the Company will be successful in its efforts.

Chapter_11_Reorganization

Chapter 11 Reorganization	12 Months Ended
	Dec. 31, 2014
Reorganizations [Abstract]
Chapter 11 Reorganization	NOTE 3. CHAPTER 11 REORGANIZATION
	On March 31, 2009, Saratoga and its subsidiaries, all of which are 100%-owned: Harvest Oil and Gas, LLC, The Harvest Group, LLC, Lobo Operating, Inc. and Lobo Resources, Inc. (collectively the “Debtors”), filed voluntary petitions under Chapter 11 of the U.S. Bankruptcy Code.
	On May 14, 2010, the Company satisfied all of the conditions set forth in its Plan of Reorganization and the Company exited from bankruptcy.
	During the years ended December 31, 2013, the Company incurred $2,319, in reorganization costs.

Other_Assets

Other Assets	12 Months Ended
	Dec. 31, 2014
Other Assets [Abstract]
Other Assets	NOTE 4. OTHER ASSETS
	Other assets consist of the following:
		December 31,
		2014		2013
	Site specific trust accounts – P&A escrow	$	5,564,129	$	5,521,913
	Debt issuance cost, net		4,077,060		6,351,806
	Restricted cash – P&A bond		10,628,903		9,738,353
	Other		80,563		53,758
		$	20,350,655	$	21,665,830
	Site Specific Trust Accounts – P&A Escrow
	The Company maintains an escrow agreement that has been established for the purpose of assuring maintenance and administration of a performance bond which secures certain plugging and abandonment obligations assumed in the acquisition of oil and gas properties in certain fields. Changes in the escrow accounts reflect additional contributions and interest earned during 2014. See Note 9 – “Asset Retirement Obligations”.
	Debt Issuance Costs, Net
	The Company capitalizes certain debt issuance costs and amortizes those costs as additional interest expense over the lives of the associated debt. Net debt issuance costs at December 31, 2014 and 2013 reflect the issuance of the 12½% Second Lien Notes in December 2012 and July 2011 and the issuance of the 10% First Lien Notes in November 2013. See Note 5 – “Debt”.
	Restricted Cash – P&A Bond
	Restricted Cash – P&A Bond consists of cash collateral held in escrow to assure maintenance and administration of performance bonds which secures certain plugging and abandonment obligations imposed by state law. The cash collateral is reflected as a long term asset to correspond with the expected timing of the related asset retirement obligation liability. See Note 9 – “Asset Retirement Obligations”.

Debt

Debt	12 Months Ended
	Dec. 31, 2014
Debt Disclosure [Abstract]
Debt	NOTE 5. DEBT
	Debt consists of the following:
		December 31,
		2014		2013
	10% First Lien Notes due 2015	$	54,600,000	$	54,600,000
	12 ½% Second Lien Notes due 2016		125,200,000		125,200,000
	Less unamortized discount		-999,116		-1,603,016
		$	178,800,884	$	178,196,984
	10.0% First Lien Notes
	In November 2013, the Company, and its wholly-owned subsidiaries (the “Guarantors”), issued $54.6 million in aggregate principal amount of 10.0% Senior Secured Notes due 2015 (the “First Lien Notes”) to two institutional accredited investors (the “Purchasers”).
	The First Lien Notes were issued pursuant to Purchase Agreements (the “Purchase Agreement”), and under an Indenture (the “First Lien Indenture”), by and among the Company, the Guarantors named therein and The Bank of New York Mellon Trust Company, N.A., as trustee (the “First Lien Trustee”). The First Lien Notes are our senior secured obligations and are fully and unconditionally guaranteed (the “Guarantees”) on a senior secured basis by the Guarantors and will rank equally in right of payment with our, and the Guarantors’, existing and future senior indebtedness and senior in right of payment to Second Lien Notes (as defined below).
	The purchase price for the First Lien Notes and Guarantees was 100% of their principal amount. We received net proceeds from the issuance and sale of the First Lien Notes of approximately $25.4 million, after commissions and estimated offering expenses, and the surrender for retirement by the Purchasers of $27.3 million in face amount of 12½% Senior Secured Notes (the “Second Lien Notes”).
	The First Lien Notes mature on December 31, 2015, and interest, accruing at 10% per annum, is payable on the First Lien Notes on March 31, June 30, September 30 and December 31 of each year, commencing December 31, 2013.
	The First Lien Indenture includes customary events of default and places restrictions on the Company and certain of its subsidiaries with respect to additional indebtedness, liens, dividends and other payments to shareholders, repurchases or redemptions of the Company’s common stock, redemptions of senior notes, investments, acquisitions, mergers, asset dispositions, transactions with affiliates, hedging transactions and other matters.
	The Company has the option to redeem all or a portion of the First Lien Notes at any time at 100% of the principal amount to be redeemed plus accrued and unpaid interest. Upon the occurrence of a change of control, we are required to offer to purchase the First Lien Notes at a price equal to 101% of the aggregate principal amount of First Lien Notes repurchased plus accrued and unpaid interest. Further, upon the occurrence of certain asset sales, we are required to provide notice of the same and are required to offer to purchase a defined portion of the First Lien Notes at a price equal to 100% of the principal amount of First Lien Notes repurchased plus accrued and unpaid interest.
	In connection with the issuance and sale of the First Lien Notes, the Company, the First Lien Trustee and The Bank of New York Mellon Trust Company, N.A., in its capacity as trustee and collateral under the Second Lien Documents (as defined below)(the “Second Lien Trustee”) entered into an Intercreditor Agreement (the “Intercreditor Agreement”). Pursuant to the Intercreditor Agreement, parties agreed that the lien with respect to collateral securing the First Lien Indenture and related First Lien Notes and Guarantees (the “First Lien Obligations”) shall be senior in right, priority, operation, effect and all other respects to any lien with respect to collateral securing the obligations under that certain Indenture dated as of June 12, 2011, as supplemented or amended from time to time thereafter (the “Second Lien Indenture”), by and among our company, the Guarantors named therein and the Second Lien Trustee, and the related Second Lien Notes in the aggregate amount of $125.2 million (the “Second Lien Obligations”).
	Interest payable and owing as of December 31, 2014, in the amount of $1,365,000, was not paid as of the due date. Such interest was subsequently paid in connection with a Forbearance Agreement to First Lien Indenture. See “Note 14. Subsequent Events.”
	12½% Second Lien Notes
	In July 2011, the Company and the Guarantors entered into a Purchase Agreement with Imperial Capital, LLC (the “Initial Purchaser”), relating to the issuance and sale of $127.5 million in aggregate principal amount of 12½% Senior Secured Notes due 2016. The Second Lien Notes were sold at 98.221% of par in a transaction exempt from the registration requirements of the Securities Act and were resold to qualified institutional buyers in reliance on Rule 144A of the Securities Act and to persons outside of the U.S. pursuant to Regulation S.
	In December 2012, the Company and the Guarantors entered into another Purchase Agreement with the Initial Purchaser, relating to the issuance and sale of an additional $25 million in aggregate principal amount of the Second Lien Notes. The Second Lien Notes were sold at 98.58% of par in a transaction exempt from the registration requirements of the Securities Act and were resold to qualified institutional buyers in reliance on Rule 144A of the Securities Act and to persons outside of the U.S. pursuant to Regulation S.
	The Second Lien Notes were issued pursuant to the Second Lien Indenture among the Company, the Guarantors named therein and Second Lien Trustee, as trustee and collateral agent and, with respect to the Second Lien Notes issued in 2012, a First Supplemental Indenture, dated December 4, 2012. The Second Lien Notes are the senior secured obligations of the Company and are fully and unconditionally guaranteed on a senior secured basis by the Guarantors and will rank equally in right of payment with the Company’s and the Guarantors’ existing and future senior indebtedness, subject, however, to the Intercreditor Agreement pursuant to which the First Lien Notes are senior in right, priority, operation and effect to the lien securing the Second Lien Notes.
	The Second Lien Notes mature on July 1, 2016, and interest is payable on January 1 and July 1 of each year.
	The Second Lien Indenture includes customary events of default and places restrictions on the Company and certain of its subsidiaries with respect to additional indebtedness, liens, dividends and other payments to shareholders, repurchases or redemptions of the Company’s common stock, redemptions of senior notes, investments, acquisitions, mergers, asset dispositions, transactions with affiliates, hedging transactions and other matters.
	The Company has the option to redeem all or a portion of the Second Lien Notes at any time on or after January 1, 2014 at the redemption prices specified in the Indenture plus accrued and unpaid interest.
	Interest accrued and owing as of January 1, 2015, in the amount of $7,825,000, was not paid on its due date and, as a result, the Second Lien Notes are in default and are included as a current liability in the accompanying consolidated financial statements. The Company and the principal holders of the Second Lien Notes entered into a Forbearance Agreement to Second Lien Debenture in January 2015. See “Note 14- Subsequent Events.”

Derivative_Instruments_and_Hed

Derivative Instruments and Hedging Activities	12 Months Ended
	Dec. 31, 2014
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Derivative Instruments and Hedging Activities	NOTE 6. – DERIVATIVE INSTRUMENTS AND HEDGING ACTIVITIES
	Objective and Strategies for Using Commodity Derivative Instruments
	The Company periodically enters into commodity derivative instruments, primarily fixed price swaps, to manage its exposure to oil and gas price volatility. The oil and gas reference prices upon which the price hedging instruments are based reflect various market indices that have a high degree of historical correlation with actual prices received by the Company. The fixed price swap contracts entitle us (floating price payor) to receive settlement from the counterparty (fixed price payor) for each calculation period in amounts, if any, by which the settlement price for the scheduled trading days applicable for each calculation period is less than the fixed strike price. We would pay the counterparty if the settlement price for the scheduled trading days applicable for each calculation period is more than the fixed strike price. The amount payable by us, if the floating price is above the fixed price, is the product of the notional quantity per calculation period and the excess of the floating price over the fixed price with respect to each calculation period. The amount payable by the counterparty, if the floating price is below the fixed price, is the product of the notional quantity per calculation period and the excess of the fixed price over the floating price with respect to each calculation period.
	While these instruments mitigate the cash flow risk of future reductions in commodity, they may also curtail benefits from future increases in commodity prices.
	See Note 7 – “Fair Value Measurements” for a discussion of the methods and assumptions used to estimate the fair values of our commodity derivative instruments.
	The Company utilizes hedge accounting for our commodity derivative instruments, which are designated as cash flow hedges.
	Counterparty Credit Risk
	Commodity derivative instruments expose us to counterparty credit risk. The Company’s commodity derivative instruments were with one and two counterparties at December 31, 2014 and 2013, respectively. We monitor and manage our level of financial exposure with respect to the counterparties we use. Our commodity derivative contracts are executed under master agreements which allow us, in the event of default, to elect early termination of all contracts with the defaulting counterparty. If we choose to elect early termination, all asset and liability positions with the defaulting counterparty would be net settled at the time of election.
	We monitor the creditworthiness of our commodity derivatives counterparties. However, we are not able to predict sudden changes in counterparties’ creditworthiness. In addition, even if such changes are not sudden, we may be limited in our ability to mitigate an increase in counterparty credit risk.
	As of December 31, 2014, the Company had the following hedge contracts outstanding:
		Beginning		Ending		Fixed		Strike				Total
	Instrument	Date		Date		Price		Price		Premium		Bbls
	Covered Call	1-Apr-14		31-Mar-15		$	-	$	103.3	$	6.8	22,500
												22,500
	The following table presents the fair value of the Company’s commodity derivative instruments at December 31, 2014 and 2013:
		December 31,
	Description	2014			2013
	Current liabilities
	Commodity derivatives	$	117		$	837,758
		$	117		$	837,758
		December 31,
	Description	2014			2013
	Long-term liabilities
	Commodity derivatives	$	-		$	182,174
		$	-		$	182,174
	The following tables present the effect of commodity derivative instruments on our consolidated statements of operations and comprehensive income (loss) for the years ended December 31, 2014 and 2013:
		For the Year Ended December 31,
	Description	2014			2013
	Unrealized mark-to-market loss	$	-117		$	-1,019,932
	Realized gain (loss) on settlements		1,550,754			-681,637
	Total gain (loss) on commodity derivative instruments	$	1,550,637		$	-1,701,569
		For the Year Ended December 31,
	Description	2014			2013
	Unealized mark-to-market gain(loss) in other comprehensive income (loss)	$	-		$	171,086
	Total other comprehensive income (loss)	$	-		$	171,086

Fair_Value_Measurements

Fair Value Measurements	12 Months Ended
	Dec. 31, 2014
Fair Value Disclosures [Abstract]
Fair Value Measurements	NOTE 7. – FAIR VALUE MEASUREMENTS
	The Company has various financial instruments that are measured at fair value in the financial statements, including commodity derivatives. The Company’s financial assets and liabilities are measured using input from three levels of the fair value hierarchy. A financial asset or liability classification within the hierarchy is determined based on the lowest level input that is significant to the fair value measurement. 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 assets or liability 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 the Company’s judgments about the assumptions market participants would use in pricing the asset or liability since limited market data exists. The Company develops these inputs based on the best information available, using internal and external data.
	The following table presents the Company’s assets and liabilities recognized in the balance sheet and measured at fair value on a recurring basis as of December 31, 2014:
	Description	Level 1	Level 2		Level 3	Total
	Liabilities:
	Commodity derivatives	$	$	117	$	$	117
		$	$	117	$	$	117
	The following table presents the Company’s assets and liabilities recognized in the balance sheet and measured at fair value on a recurring basis as of December 31, 2013:
	Description	Level 1	Level 2		Level 3	Total
	Liabilities:
	Commodity derivatives	$	$	1,019,932	$	$	1,019,932
		$	$	1,019,932	$	$	1,019,932
	The Company uses various commodity derivative instruments, including fixed price swaps. We consider the fair value of our commodity derivative instruments to be level 2 on the fair value hierarchy. The fair value of commodity derivatives is determined using adjusted exchange prices, prices provided by brokers or pricing service companies that are all corroborated by market data.

Oil_and_Gas_Assets

Oil and Gas Assets	12 Months Ended
	Dec. 31, 2014
Oil and Gas Property [Abstract]
Oil and Gas Assets	NOTE 8. OIL AND GAS ASSETS
	Property and equipment consisted of the following:
		December 31,
		2014		2013
	Oil and gas properties (proved):
	Gross oil and gas properties (proved)	$	301,399,079	$	286,441,663
	Accumulated depreciation, depletion, amortization and impairment		-225,896,843		-100,381,317
	Net oil and gas properties (proved)		75,502,236		186,060,346
	Other property and equipment		1,031,779		892,694
	Accumulated depreciation and amortization		-819,558		-707,379
	Net other property and equipment		212,221		185,315
	Net property and equipment	$	75,714,457	$	186,245,661
	At December 31, 2014, there were $1,617,635 in costs associated with prospects, primarily federal leases in the shallow Gulf of Mexico shelf, which were included in oil and gas properties, but were not yet included in the depletion calculation.
	During the year ended December 31, 2014, the Company recorded impairment expense in the amount of $107,774,206. The impairment expense during 2014 reflected the reclassification of certain reserves out of the proved undeveloped category and into the probable category due to application of the SEC’s “five year rule” and the steep decline in commodity prices which resulted in the expected undiscounted future cash flows at a producing field level to be less than the unamortized capitalized cost of assets in several fields.
	During the year ended December 31, 2013, The Company recorded impairment expense in the amount $2,179,075. Impairment expense during 2013 related to the loss of a lease, and associated reserves, at one field.

Asset_Retirement_Obligations

Asset Retirement Obligations	12 Months Ended
	Dec. 31, 2014
Asset Retirement Obligation Disclosure [Abstract]
Asset Retirement Obligations	NOTE 9. ASSET RETIREMENT OBLIGATIONS
	The Company accounts for plugging and abandonment costs in accordance with FASB ASC 410-20, Accounting for Asset Retirement Obligations.
	The Company maintains an escrow agreement that has been established for the purpose of assuring maintenance and administration of a performance bond which secures certain plugging and abandonment obligations assumed in the acquisition of oil and gas properties in certain fields.
	At December 31, 2014 and 2013, the amount of the escrow account totaled $5.6 million and $5.5 million, respectively and is shown as other assets on the Company’s balance sheet. See Note 4 – “Other Assets”.
	During the years ended December 31, 2014 and 2013, downward revisions in the asset retirement obligations relating to certain properties exceeded the carrying amounts of the properties. Accordingly, during the years ended December 31, 2014 and 2013 the excess amounts, totaling $75,178 and $564,719, respectively, were recognized as gains.
	During the year ended December 31, 2013, plugging and abandonment costs related to two properties exceeded the amounts reflected in the asset retirement obligation liability. The wells plugged were the deepest and highest pressure wells in our entire inventory of wells to be plugged and included certain unanticipated conditions. Accordingly, during the year ended December 2013, the excess amount, which was $701,241 was recognized as a loss.
	A reconciliation of the beginning and ending aggregate carrying amount of asset retirement obligations are as follows:
	Balance at December 31, 2012	$	17,071,936
	Accretion expense		2,552,381
	Additions		62,808
	Revisions		-6,509,866
	Settlements		-527,801
	Balance at December 31, 2013	$	12,649,458
	Accretion expense		1,793,865
	Additions		24,766
	Revisions		1,929,715
	Settlements		-
	Balance at December 31, 2014	$	16,397,804

Commitments_and_Contingencies

Commitments and Contingencies	12 Months Ended
	Dec. 31, 2014
Commitments and Contingencies Disclosure [Abstract]
Commitments and Contingencies	NOTE 10. COMMITMENTS AND CONTINGENCIES
	Contractual Commitments
	We have commitments under a non-cancellable operating lease agreements for our offices in Houston, Texas and Covington, Louisiana.
	Rent expense with respect to our lease commitments for office space for the years ended December 31, 2014 and 2013 was $262,250 and $244,648, respectively.
	We have certain plugging and abandonment, reclamation, restoration, and clean up liabilities and obligations related to our oil and gas properties. To secure these liabilities, we maintain $7,750,000 in letters of credit. The letters of credit are secured by cash collateral.
	At December 31, 2014, total minimum commitments from debt, long-term non-cancelable operating leases, asset retirement obligations and other purchase obligations are as follows:
		Total		2015		2016 – 2017		2018 – 2019		Thereafter
	Debt	$	188,990,000	$	188,990,000	$	-	$	-	$	-
	Operating leases		432,667		168,167		264,500		-		-
	Asset retirement obligations		56,239,500		-		5,695,000		348,000		50,196,500
	Total	$	245,662,167	$	189,158,167	$	5,959,500	$	348,000	$	50,196,500
	Contingencies
	From time to time the Company may become involved in litigation in the ordinary course of business. At December 31, 2014, except as noted, the Company’s management was not aware, and as of the date of this report is not aware of any such litigation that could have a material adverse effect on its results of operations, cash flows or financial condition.
	The Company, as an owner or lessee and operator of oil and gas properties, is subject to various federal, state and local laws and regulations relating to discharge of materials into, and protection of, the environment. These laws and regulations may, among other things, impose liability on the lessee under an oil and gas lease for the cost of pollution clean-up resulting from operations and subject the lessee to liability for pollution damages. In some instances, the Company may be directed to suspend or cease operations in the affected area. The Company maintains insurance coverage, which it believes is customary in the industry, although the Company is not fully insured against all environmental risks. The Company is not aware of any environmental claims existing as of December 31, 2014, which have not been provided for, covered by insurance or otherwise have a material impact on its financial position or results of operations. There can be no assurance, however, that current regulatory requirements will not change, or past non-compliance with environmental laws will not be discovered on the Company’s properties.
	The Harvest Group, LLC, et al. v. Brian Carl Albrecht; Harvest Operating LLC v. The Harvest Group, LLC, et al.
	In February 2010, the Company filed a complaint in the United States Bankruptcy Court for the Western District of Louisiana against Barry Ray Salsbury, Brian Carl Albrecht, Shell Sibley, Willie Willard Powell and Carolyn Monica Greer, each being former owners of The Harvest Group LLC and/or Harvest Oil & Gas, LLC. The complaint alleged breach of the Purchase and Sale Agreements with the former owners arising from the underpayment or nonpayment of royalties to the State of Louisiana for periods prior to the Company’s acquisition of the Harvest Companies and related claims for damages. The claims against all parties other than Brian Carl Albrecht were subsequently settled and the claim against Mr. Albrecht was converted to an arbitration proceeding.
	Harvest Operating, LLC, a company controlled by Mr. Albrecht, brought a separate cause of action against The Harvest Group, LLC, Harvest Oil & Gas, LLC and Saratoga Resources, Inc. (the “Saratoga Parties”), which cause of action was consolidated with the arbitration proceedings noted above. Harvest Operating’s cause of action asserted a claim for damages based on the alleged wrongful termination of rights to use a pipeline owned and operated by the Saratoga Parties and the loss in value of a property operated by Harvest Operating based on its inability to transport production from that property via the pipeline in question.
	The consolidated arbitration proceeding was conducted before a single arbitrator and, in August 2014, the arbitrator issued an Award and Reasons ruling (1) in favor of Saratoga, as relates to the royalty claim, and awarding to Saratoga $355,879, and (2) in favor of Harvest Operating, as relates to the pipeline use claim, and awarding to Harvest Operating $3,757,050. As a result of such award, the Company recorded an arbitration award expense and an accrued liability of $3.4 million.
	The Company believes that the award based on the pipeline use claim is wholly unsupported by the facts or the law. In November 2014, Saratoga filed a motion with the arbitrator to reconsider and clarify the arbitration award. Separately, in November 2014, Saratoga filed a Motion for Clarification and Remittitur in the 19th District Court of East Baton Rouge Parish, Louisiana. Both the motion with the arbitrator and the Motion in the District Court seek to vacate the arbitrator’s award relating to the pipeline claim on multiple grounds. In December 2014, the arbitrator agreed to hear arguments as to the authority and grounds for reconsidering the arbitration award and the arbitrator’s decision in that matter is pending.
	Also, in November 2014, Saratoga filed a separate cause of action against Brian Albrecht in the 24th District Court of Jefferson Parish, Louisiana. The cause of action alleges breach of contract on the part of Mr. Albrecht and seeks damages in an amount equal to those awarded in the above arbitration proceeding. Saratoga asserts that the Purchase and Sale Agreement under which Saratoga secured beneficial ownership of the pipeline that is subject of the arbitration proceeding and the claims of Harvest Operating was illusory in that, if the reasoning of the arbitration award were to stand, Saratoga would not have received the rights associated with beneficial ownership and control of the pipeline and that, by withholding from Saratoga the ordinary rights associated with ownership of the pipeline, Mr. Albrecht was in breach of the terms of the Purchase and Sale Agreement.

Common_Stock

Common Stock	12 Months Ended
	Dec. 31, 2014
Disclosure of Compensation Related Costs, Share-based Payments [Abstract]
Common Stock	NOTE 11. COMMON STOCK
	Net Income per Common Share
	A reconciliation of the components of basic and diluted net income per common share is presented in the tables below:
			For the Year Ended December, 31
				2014			2013
	Income (loss) attributable to common stock		$	-143,911,025		$	-26,394,459
	Weighted average number of shares outstanding, basic			30,967,533			30,932,541
	Incremental shares from assumed conversion of dilutive stock options and warrants			-			-
	Weighted average number of shares outstanding, diluted:			30,967,533			30,932,541
	Net Income (loss) per share, basic			-4.65			-0.85
	Net Income (loss) per share, diluted			-4.65			-0.85
	Number of antidilutive stock options and warrants excluded from calculation above			1,799,498			1,754,497
	Common Stock Activity
	During the year ended December 31, 2013, the Company issued an aggregate of 6,500 shares of common stock upon the exercise of outstanding stock options by a former employee. The shares were issued for gross proceeds of $9,945, or $1.53 a share. See “-Stock Option Activity” below.
	During the year ended December 31, 2013, the Company issued an aggregate of 35,000 shares of common stock upon the exercise of outstanding warrants for gross proceeds of $13,850, or $0.40 per share. See “-Warrant Activity” below.
	During the year ended December 31, 2014, the Company issued an aggregate of 40,000 shares of common stock upon the exercise of outstanding stock options by a former employee. The shares were issued for gross proceeds of $61,200, or $1.53 per share. See “-Stock Option Activity” below.
	Stock-Based Compensation
	The Company periodically grants restricted stock and stock options to employees, directors and consultants. The Company is required to make estimates of the fair value of the related instruments when granted and recognize expense over the period benefited, usually the vesting period.
	In September 2011, the Company’s board of directors adopted, and in June 2012 the Company’s stockholders approved, the Saratoga Resources, Inc. 2011 Omnibus Equity Plan (the “2011 Plan”). The 2011 Plan reserves a total of 3,000,000 shares for issuance to eligible employees, officers, directors and other service providers pursuant to grants of options, restricted stock, performance stock and other equity based compensation agreements.
	In conjunction with the adoption of the 2011 Plan, the Company’s board of directors approved the termination of the Saratoga Resources, Inc. 2008 Long-term Incentive Plan (the “2008 Plan”) and the Saratoga Resources, Inc. 2006 Employee and Consultant Stock Plan (the “2006 Plan”). At the time of their termination, no awards were outstanding under the 2008 Plan or the 2006 Plan.
	Stock Option Activity
	In April 2013, the Company’s management approved a stock option grant to purchase an aggregate of 75,000 shares of common stock to two non-executive employees. The options are exercisable for a term of seven years at prices ranging from $2.34 to $2.42 per share and vest 1/3 on each of the first three grant date anniversaries. The grant date value of the options was $178,200. The options were valued using the Black-Scholes model with the following assumptions: 240% volatility; 4.5 year estimated life; zero dividends; 0.60% to 0.62% discount rate; and, quoted stock price and exercise price of $2.34 to $2.42.
	In June 2013, the Company’s board of directors approved a stock option grant to purchase an aggregate of 500,000 shares of common stock to two executive officers. The options are exercisable for a term of five years at $3.00 per share and vest 1/8 per quarter. The grant date value of the options was $505,000. The options were valued using the Black-Scholes model with the following assumptions: 83% volatility; 3.06 year estimated life; zero dividends; 0.57% discount rate; and, quoted stock price of $2.18.
	In June 2013, the Company’s board of directors approved a stock option grant to purchase an aggregate of 105,000 shares of common stock to non-employee directors. The options are exercisable for a term of seven years at $2.18 per share and vest ½ on the date of grant and ½ on the first anniversary of the grant date. The grant date value of the options was $174,300. The options were valued using the Black-Scholes model with the following assumptions: 121% volatility; 3.75 year estimated life; zero dividends; 0.77% discount rate; and, quoted stock price and exercise price of $2.18.
	In July 2013, the Company’s management approved a stock option grant to purchase an aggregate of 60,000 shares of common stock to a non-executive employee. The options are exercisable for a term of seven years at price of $1.53 per share and vest 1/3 on each of the first three grant date anniversaries. The grant date value of the options was $90,600. The options were valued using the Black-Scholes model with the following assumptions: 231% volatility; 4.5 year estimated life; zero dividends; 1.18% discount rate; and, quoted stock price and exercise price of $1.53.
	In August 2013, the Company’s management approved a stock option grant to purchase an aggregate of 90,000 shares of common stock to a non-executive employee. The options are exercisable for a term of seven years at price of $1.72 per share and vest 1/3 on each of the first three grant date anniversaries. The grant date value of the options was $150,300. The options were valued using the Black-Scholes model with the following assumptions: 204% volatility; 4.5 year estimated life; zero dividends; 1.18% discount rate; and, quoted stock price and exercise price of $1.72.
	During the year ended December 31, 2013, stock options to purchase 6,500 shares of common stock at $1.53 per share were exercised for cash proceeds totaling $9,945.
	In February 2014, the Company’s management approved a stock option grant to purchase an aggregate of 90,000 shares of common stock to a non-executive employee. The options are exercisable for a term of seven years at $1.32 per share and vest 1/3 on each of the first three grant date anniversaries. The grant date value of the options was $96,300. The options were valued using the Black-Scholes model with the following assumptions: 121% volatility; 4.5 year estimated life; zero dividends; 1.36% discount rate; and, quoted stock price and exercise price of $1.32.
	In April 2014, the Company’s management approved a stock option grant to purchase an aggregate of 60,000 shares of common stock to a non-executive employee. The options are exercisable for a term of seven years at $1.22 per share and vest 1/3 on each of the first three grant date anniversaries. The grant date value of the options was $57,000. The options were valued using the Black-Scholes model with the following assumptions: 113% volatility; 4.5 year estimated life; zero dividends; 1.47% discount rate; and, quoted stock price and exercise price of $1.22.
	In April 2014, the Company’s management approved a stock option grant to purchase an aggregate of 90,000 shares of common stock to a non-executive employee. The options are exercisable for a term of seven years at $1.18 per share and vest 1/3 after six months and 1/3 on each of the first two grant date anniversaries. The grant date value of the options was $70,200. The options were valued using the Black-Scholes model with the following assumptions: 92% volatility; 4.1 year estimated life; zero dividends, 1.25% discount rate; and, quoted stock price and exercise price of $1.18.
	In May 2014, the Company’s management approved a stock option grant to purchase an aggregate of 60,000 shares of common stock to a non-executive employee. The options are exercisable for a term of seven years at $1.30 per share and vest 1/3 after six months and 1/3 on each of the first two grant date anniversaries. The grant date value of the options was $47,400. The options were valued using the Black-Scholes model with the following assumptions: 83% volatility; 4.1 year estimated life; zero dividends; 1.26% discount rate; and, quoted stock price and exercise price of $1.30.
	In May 2014, the Company’s board of directors approved stock option grants to purchase an aggregate of 90,000 shares of common stock to two executive officers. The options are exercisable for a term of seven years at $1.30 per share and vest 1/3 after six months and 1/3 on each of the first two grant date anniversaries. The grant date value of the options was $71,100. The options were valued using the Black-Scholes model with the following assumptions: 83% volatility; 4.1 year estimated life; zero dividends; 1.26% discount rate; and, quoted stock price and exercise price of $1.30.
	In June 2014, the Company’s board of directors approved a stock option grant to purchase an aggregate of 105,000 shares of common stock to non-employee directors. The options are exercisable for a term of seven years at $1.89 per share and vest 1/2 on the date of grant and 1/2 on the first anniversary of the grant date. The grant date value of the options was $103,950. The options were valued using the Black-Scholes model with the following assumptions: 72% volatility; 3.75 year estimated life; zero dividends; 1.24% discount rate; and, quoted stock price and exercise price of $1.89.
	In September 2014, the Company’s management approved a stock option grant to purchase an aggregate of 30,000 shares of common stock to two non-executive employees. The options are exercisable for a term of seven years at $1.47 per share and vest 1/3 on each of the first three grant date anniversaries. The grant date value of the options was $29,700. The options were valued using the Black-Scholes model with the following assumptions: 90% volatility; 4.5 year estimated life; zero dividends; 1.62% discount rate; and, quoted stock price and exercise price of $1.47.
	During the year ended December 31, 2014, stock options to purchase 40,000 shares of common stock at $1.53 per share were exercised for cash proceeds totaling $61,200.
	Stock based compensation expense attributable to common shares and grants of options was $528,330 and $1,001,160, during the years ended December 31, 2014 and 2013, respectively. The unamortized amount of stock-based compensation that had not been recorded was $286,407 and $614,885 as of December 31, 2014 and 2013, respectively.
	The following table presents the options outstanding at December 31, 2014:
		Number of			Weighted			Weighted		Weighted	Aggregate
		Shares			Average			Average		Average	Intrinsic
		Underlying			Exercise			Grant		Remaining	Value (1)
		Options			Price per			Date Fair		Contractual
					Share			Value per		Life (in
								Share		Years)
	Outstanding at December 31, 2012		784,000		$	3.66		$	3.65	6.5	$	474,240
	Granted		830,000			2.6			1.32	5.2		-
	Exercised		-6,500			1.53			1.53	-		-
	Forfeited		-			-			-	-		-
	Outstanding at December 31, 2013		1,607,500		$	3.13		$	2.46	5.4	$	39,000
	Granted		525,000			1.4			0.91	6.4		-
	Exercised		-40,000			1.53			1.53	-		-
	Forfeited		-440,000			3.21			3.12	-		-
	Outstanding at December 31, 2014		1,652,500			2.59			1.81	4.8		-
	Exercisable at December 31, 2014		1,045,000		$	3.03		$	2.18	4.4	$	-
	____________________
	(1) The intrinsic value of an option is the amount by which the market value of our common stock at the indicated date, or at the time of exercise, exceeds the exercise price of the option. On December 31, 2014, the last reported sales price of our common stock on the NYSE MKT was $0.217 per share.
	The following table summarizes information about stock options outstanding and exercisable at December 31, 2014:
	Options Outstanding and Exercisable
	Exercise			Number of		Weighted			Weighted
	Price			Shares		Average			Average
				Underlying		Exercise			Remaining
				Options		Price per			Contractual
						Share			Life (in
									Years)
	$	0.36		50,000		$	0.02		0.2
	1.3		50,000			0.06		0.3
	1.39		10,000			0.01		0.01
	1.53		20,000			0.03		0.11
	1.71		2,500			0.04		0.01
	1.72		30,000			0.05		0.16
	1.89		52,500			0.09		0.32
	2.18		105,000			0.22		0.55
	2.34		5,000			0.01		0.03
	2.42		20,000			0.05		0.1
	2.75		30,000			0.08		0.18
	3		435,000			1.25		1.54
	3.05		70,000			0.2		0.21
	4.62		30,000			0.13		0.11
	5.11		30,000			0.15		0.11
	6.65		105,000			0.67		0.45
			1,045,000		$	3.03		4.39
Warrant Activity
In May and July 2013 service providers exercised warrants, originally issued in 2008, to purchase 35,000 shares of common stock at prices ranging from $0.17 to $1.75 per share for total proceeds of $13,850.
The following table presents the warrants outstanding at December 31, 2014:
	Number of			Weighted			Weighted		Weighted	Aggregate
	Shares			Average			Average		Average	Intrinsic
	Underlying			Exercise			Grant		Remaining	Value (1)
	Warrants			Price per			Date Fair		Contractual
				Share			Value per		Life (in
							Share		Years)
Outstanding at December 31, 2012		572,628		$	5.14		$	3.22	0.8	$	132,900
Granted		-			-			-	-		-
Exercised		-35,000			0.4			0.22	-		-
Forfeited		-390,630			5			2.69	-		-
Outstanding at December 31, 2013		146,998		$	6.64		$	5.33	0.8	$	-
Granted		-			-			-	-		-
Exercised		-			-			-	-		-
Forfeited		-			-			-	-		-
Outstanding at December 31, 2014		146,998		$	6.64		$	5.33	0.36	$	-
Exercisable at December 31, 2014		146,998		$	6.64		$	5.33	0.36	$	-
_____________________
(1) The intrinsic value of a warrant is the amount by which the market value of our common stock at the indicated date, or at the time of exercise, exceeds the exercise price of the warrant. On December 31, 2014, the last reported sales price of our common stock on the NYSE MKT was $0.217 per share.
The following table summarizes information about stock warrants outstanding and exercisable at December 31, 2014:
Warrants Outstanding and Exercisable
Exercise			Number of		Weighted			Weighted
Price			Shares		Average			Average
			Underlying		Exercise			Remaining
			Warrants		Price per			Contractual
					Share			Life (in
								Years)
$	3		40,000		$	0.82		0.08
	8		106,998			5.82		0.28
			146,998		$	6.64		0.36

Income_Taxes

Income Taxes	12 Months Ended
	Dec. 31, 2014
Income Tax Disclosure [Abstract]
Income Taxes	NOTE 12. INCOME TAXES
	The Company is subject to income tax in the United States. Current tax obligations associated with our provision for income taxes are reflected in the accompanying Balance Sheet as component of “Accrued liabilities” and the deferred tax obligations are reflected in “Deferred income taxes”.
	Our effective tax rates were different than our federal statutory tax rate due to state income taxes associated with income from various locations in which we have operations. Estimates of future taxable income can be significantly affected by changes in oil and natural gas prices, the timing, amount, and location of future production and future operating expenses and capital costs.
	Our provision (benefit) for income taxes at December 31, 2014 and 2013 consisted of the following:
			2014			2013
	Current:
	Federal		$	-		$	-
	State			189,855			130,881
				189,855			130,881
	Deferred:
	Federal			-			8,499,575
	State			-			-
				-			8,499,575
	Total tax provision (benefit)		$	189,855		$	8,630,456
	The U.S. federal statutory income tax rate is reconciled to the effective rate at December 31, 2014 and 2013 as follows:
			2014		2013
	Income tax expense at U.S. federal statutory rate		35.00%		35.00%
	Valuation allowance		-35.00%		-77.90%
	State and local income taxes, net of federal income tax benefit		-		-
	Permanent differences		-		-0.40%
	Temporary differences		-0.10%		-5.30%
	Effective tax rate		-0.10%		-48.60%
	The components of the net deferred tax assets (liabilities) at December 31, 2014 and 2013 are as follows:
	Deferred tax asset
	Net operating loss	$	40,218,636		$	25,864,942
	Stock-based compensation		2,712,889			2,527,973
	Debt issuance cost (amortization)		1,245,012			1,245,012
	Depletion on oil and gas properties		19,784,120			-
	Derivatives		416,856			59,880
	Depreciation and amortization		-6,802			-12,970
	Capital loss carryover		94,936			94,936
	Charitable contributions		14,588			14,588
	Total deferred tax assets		64,480,235			29,794,361
	Deferred tax liability
	Depletion on oil and gas properties		-			15,956,511
	Total deferred tax liabilities		-			15,956,511
	Less: valuation allowance		64,480,235			13,837,850
	Deferred tax asset (liability)	$	-		$	-
	At December 31, 2014, we had $114.9 million of federal net operating loss, or NOL, carryforwards; the federal NOL carryforwards have expiration dates through the year 2034.
	We recognize the expected future tax benefit from deferred tax assets when the tax benefit is considered to be more likely than not of being realized. Otherwise, a valuation allowance is applied against deferred tax assets reducing the value of such assets. Assessing the recoverability of deferred tax assets requires management to make significant estimates related to expectations of future taxable income. Estimates of future taxable income are based on forecasted income from operations and the application of existing tax laws in each jurisdiction. Oil and gas price estimates are a key component used in the determination of our ability to realize the expected future benefit of our deferred tax assets. To the extent that future taxable income differs significantly from estimates as a result of a decline in oil and gas prices or other factors, our ability to realize the deferred tax assets could be impacted. Additionally, significant future issuances of common stock or common stock equivalents could limit our ability to utilize our net operating loss carryforwards pursuant to Section 382 of the Internal Revenue Code. Future changes in tax law or changes in ownership structure could limit our ability to utilize our recorded tax assets. At December 31, 2014, a valuation allowance was provided for the entire balance of the net deferred tax asset in the amount of $64,190,333.

Supplemental_Oil_and_Gas_Discl

Supplemental Oil and Gas Disclosures - Unaudited	12 Months Ended
	Dec. 31, 2014
Oil and Gas Exploration and Production Industries Disclosures [Abstract]
Supplemental Oil and Gas Disclosures - Unaudited	NOTE 13. SUPPLEMENTAL OIL AND GAS DISCLOSURES - UNAUDITED
	Capitalized costs for our oil and gas producing activities consisted of the following at December 31, 2014 and 2013:
		2014		2013
	Proved properties	$	301,399,079	$	286,441,663
	Unproved properties		-		-
			301,399,079		286,441,663
	Accumulated depreciation, depletion, amortization and impairment		-225,896,843		-100,381,317
	Net capitalized costs	$	75,502,236	$	186,060,346
	Costs incurred for oil and gas property acquisitions, exploration and development for the years ended December 31, 2014 and 2013 are as follows:
		2014		2013
	Acquisitions of properties:
	Proved	$	-	$	1,380,000
	Unproved		-		-
	Exploration and dry hole costs		706,904		900,255
	Development		12,927,757		29,790,284
		$	13,634,661	$	32,070,539
	The following table sets forth the consolidated results of operations for the years ended December 31, 2014 and 2013:
		2014		2013
	Oil and gas revenues	$	52,325,716	$	68,696,055
	Lease operating expense		-24,631,620		-21,685,103
	Workover expense		-4,537,031		-2,475,541
	Exploration expense		-706,904		-900,255
	Loss on plugging and abandonment		-		-701,241
	Depreciation, depletion and amortization		-17,853,499		-17,269,349
	Impairment expense		-107,774,206		-2,179,075
	Accretion expense		-1,793,865		-2,552,381
	Gain on revision of asset retirement obligations		75,178		564,719
	Severance taxes		-3,649,814		-7,274,808
	Income before income taxes		-108,546,045		14,223,021
	Income tax benefit (provision)		-189,855		-8,630,456
	Results of operations for oil and gas producing activities (excluding Corporate overhead and financing costs)	$	-108,735,900	$	5,592,565
	Proved Oil and Gas Reserves
	Proved oil and gas reserves for the Company’s Louisiana properties were estimated by independent petroleum engineers. Proved reserves for the Company’s Gulf of Mexico properties were estimated internally. The reserves were based on the following assumptions:
	• Future revenues were based on an unweighted 12-month average of the first-day-of-the-month price held constant throughout the life of the properties.
	• Production and development costs were computed using year-end costs assuming no change in present economic conditions.
	• Future net cash flows were discounted at an annual rate of 10%.
	Reserve estimates are inherently imprecise and these estimates are expected to change as future information becomes available.
	The following summarizes our estimated total net proved reserves for the years in the two-year period ended December 31, 2014:
			Gas (Mcf)	Oil (Bbls)		Boe
	For the year ended December 31, 2013
	Beginning of year		52,918,300	8,406,600		17,226,317
	Acquisition of reserves		8,834,500	1,268,000		2,740,417
	Discoveries and extensions		3,011,500	261,200		763,116
	Improved recovery		-	-		-
	Revisions		-15,569,000	-92,900		-2,687,733
	Production		-1,198,800	-603,600		-803,400
	End of year		47,996,500	9,239,300		17,238,717
	Proved developed reserves
	Beginning of year		9,159,500	2,809,200		4,335,783
	End of year		6,880,800	3,245,700		4,392,500
	For the year ended December 31, 2014
	Beginning of year		47,996,500	9,239,300		17,238,717
	Acquisition of reserves		-	-		-
	Discoveries and extensions		-	-		-
	Improved recovery		-	-		-
	Revisions		-20,467,200	-2,935,300		-6,346,500
	Production		-950,100	-511,700		-670,050
	End of year		26,579,200	5,792,300		10,222,167
	Proved developed reserves
	Beginning of year		6,880,800	3,245,700		4,392,500
	End of year		5,204,700	2,898,500		3,765,950
	Standardized Measure of Discounted Future Net Cash Flows Relating to Proved Oil and Gas Reserves
	The following information was developed utilizing procedures prescribed by Accounting Standards Codification 932-235 (ASC 932-235), “Disclosures about Oil and Gas Producing Activities.” The information is based on estimates prepared by independent petroleum engineers. The “standardized measure of discounted future net cash flows” should not be viewed as representative of the current value of our proved oil and gas reserves. It and the other information contained in the following tables may be useful for certain comparative purposes, but should not be solely relied upon in evaluating us or our performance.
	In reviewing the information that follows, we believe that the following factors should be taken into account:
• future costs and sales prices will probably differ from those required to be used in these calculations;
• actual production rates for future periods may vary significantly from the rates assumed in the calculations;
• a 10% discount rate may not be reasonable relative to risk inherent in realizing future net oil and gas revenues; and
• future net revenues may be subject to different rates of income taxation.
Under the standardized measure, future cash inflows were estimated by applying year-end oil and gas prices applicable to our reserves to the estimated future production of year-end proved reserves. Future cash inflows do not reflect the impact of open hedge positions. Future cash inflows were reduced by estimated future development, abandonment and production costs based on year-end costs in order to arrive at net cash flows before tax. Future income tax expense has been computed by applying year-end statutory tax rates to aggregate future pre-tax net cash flows reduced by the tax basis of the properties involved and tax carryforwards. Use of a 10% discount rate and year-end prices and costs are required by ASC 932-235.
In general, management does not rely on the following information in making investment and operating decisions. Such decisions are based upon a wide range of factors, including estimates of probable as well as proved reserves and varying price and cost assumptions considered more representative of a range of possible outcomes.
The standardized measure of discounted future net cash flows from our estimated proved oil and gas reserves is as follows:
(dollars in thousands)	2014		2013
Future cash inflows	$	704,959	$	1,213,823
Future production costs		-242,110		-297,786
Future development costs		-167,409		-255,309
Future net cash flows before income taxes		295,440		660,728
Future income tax expense		-35,150		-181,935
Future net cash flows before 10% discount		260,290		478,793
10% annual discount for estimating timing of cash flows		-71,495		-178,003
Standardized measure of discounted future net cash flows	$	188,795	$	300,790
Set forth in the table below is a summary of the changes in the standardized measure of discounted future net cash flows for our proved oil and gas reserves:
(dollars in thousands)	2014		2013
Beginning of year	$	300,790	$	292,685
Sales of oil and gas produced, net of production costs		-19,507		-37,261
Net change in prices and production costs		-66,042		33,720
Extension, discoveries, and improved recovery, less related costs		-		18,639
Development costs incurred during the year		2,938		8,230
Net change in estimated future development costs		5,194		13,418
Revisions of previous quantity estimates		-209,654		-87,642
Net change from acquisitions of minerals in place		-		37,224
Net change in income taxes		89,473		4,235
Accretion of discount		41,075		40,688
Changes in timing and other		44,528		-23,146
End of year	$	188,795	$	300,790

Subsequent_Events

Subsequent Events	12 Months Ended
	Dec. 31, 2014
Subsequent Events [Abstract]
Subsequent Events	NOTE 14. SUBSEQUENT EVENTS
	Forbearance Agreements
	On January 30, 2015, the Company, along with its subsidiaries, Lobo Operating, Inc., Lobo Resources, Inc., Harvest Oil & Gas, LLC and The Harvest Group, LLC entered into a forbearance agreement (the “First Lien Forbearance Agreement”) with the holders (the “First Lien Lenders”) of certain notes (the “First Lien Notes”) issued under that certain Indenture dated as of November 22, 2013 (the “First Lien Indenture”), by and among the Company and The Bank of New York Mellon Trust Company, N.A., as trustee (the “First Lien Trustee”). Also on January 30, 2015, the Company entered into a forbearance agreement (the “Second Lien Forbearance Agreement”) with the holders (the “Second Lien Lenders”) of seventy-five percent (75%) or more in principal amount of the notes (the “Second Lien Notes”) issued under that certain Indenture dated as of July 12, 2011 (as supplemented or amended, the “Second Lien Indenture”), by and among the Company and The Bank of New York Mellon Trust Company, N.A., as trustee (the “Second Lien Trustee”).
	The First Lien Forbearance Agreement and the Second Lien Forbearance Agreement were entered into following (i) the Company’s failure to pay to the First Lien Lenders an interest installment in the amount of $1.3 million scheduled for payment on December 31, 2014, and constituting a default if not paid by January 30, 2015 (the “Anticipated First Lien Default”), and (ii) the Company’s failure to pay to the Second Lien Lenders an interest installment in the amount of $7.9 million scheduled for payment on January 1, 2015, and constituting a default if not paid by February 2, 2015 (the “Anticipated Second Lien Default,” and, together with the Anticipated First Lien Default, the “Specified Defaults”).
	The Company has received confirmation from the First Lien Lenders that they hold more than 75% of the principal amount of the outstanding Second Lien Notes and have each agreed, during the Forbearance Period (as defined below), not to provide any direction to the Second Lien Trustee or to take any steps to enforce any rights of the Second Lien Trustee or the holders of Second Lien Notes occasioned by the failure of the Company to make the January 1, 2015 interest payment.
	Pursuant to the First Lien Forbearance Agreement, the First Lien Lenders have agreed to forbear, until the earlier of March 16, 2015 or the occurrence of certain defaults defined in the First Lien Forbearance Agreement (the “Forbearance Period”), from exercising certain of their default-related rights and remedies against the Company with respect to the Specified Defaults in order to permit the Company an opportunity to effectuate a restructuring/refinancing or implement operational improvements.
	Under the terms of the First Lien Forbearance Agreement, among other things, the Company agreed to (i) pay, by February 2, 2015, the December 31, 2014 interest payment owing to the First Lien Lenders, with interest at the default rate, in the amount of $1,378,650; (ii) pay expenses incurred by the First Lien Lenders in connection with the Forbearance Agreement, including paying a retainer to counsel for the First Lien Lenders; (iii) retain, by March 2, 2015, a financial advisor acceptable to the First Lien Lenders on terms acceptable to the First Lien Lenders; (iv) deliver to the First Lien Lenders a 6-week operating budget in form and methodology acceptable to the First Lien Lenders and to abide by that budget within permitted variances; (v) deliver to the First Lien Lenders, not later than March 2, 2015, certain financial, operating and other information and, not later than March 15, 2015, a two year business plan and 2015 budget; and (vi) cause its officers, financial advisors, investment bankers and others to furnish information reasonably requested by the First Lien Lenders.
	Any breach by the Company of any covenant in the First Lien Forbearance Agreement, or the commencement of any bankruptcy, insolvency or creditor relief proceedings by or with respect to the Company, will constitute an event of default under the First Lien Forbearance Agreement.
	Pursuant to the Second Lien Forbearance Agreement, the Second Lien Lenders have agreed to forbear, during the Forbearance Period, from exercising certain of their default-related rights and remedies against the Company with respect to the Specified Defaults in order to permit the Company an opportunity to effectuate a restructuring/refinancing or implement operational improvements. Second Lien Forbearance Agreement is substantially identical to the First Lien Forbearance Agreement except that the January 1, 2015 interest payment on the First Lien Notes is not required to be made.
	On March 16, 2015, the Company entered into amendments to the First Lien Forbearance Agreement and the Second Lien Forbearance Agreement, extending the Forbearance Period to April 30, 2015.
	Stock Option Grants
	In February 2015, the Company granted stock options to three employees to purchase an aggregate of 75,000 shares of common stock. The options vest over two years and are exercisable for a term of seven years.
	Advisory Agreement
	In March 2015, pursuant to the terms of the Forbearance Agreements, the Company entered into an engagement letter (the “Engagement Letter”) with Conway MacKenzie Management Services, LLC (“CMS”). Pursuant to the Engagement Letter, the Company appointed principals of CMS to the Interim Chief Financial Officer and Strategic Alternatives Officer positions. Those officers are engaged to assist the Company in connection with its efforts to restructure or repay the First Lien Notes and Second Lien Notes. The Company will pay CMS a fee of $50,000 per month for services of the Interim Chief Financial Officer and pay hourly fees for services of other CMS personnel.

Accounting_Policies_Policies

Accounting Policies (Policies)	12 Months Ended
	Dec. 31, 2014
Accounting Policies [Abstract]
Organization and Principles of Consolidation	Organization and Principles of Consolidation
	Saratoga Resources, Inc. is an independent oil and natural gas company engaged in the production, development, acquisition and exploitation of natural gas and crude oil properties.
	Our financial statements include the accounts of Saratoga Resources, Inc., a Texas corporation, and its subsidiaries. We proportionately consolidate our interests in oil and gas exploration and production ventures and partnerships in accordance with industry practice. All significant intercompany balances and transactions have been eliminated. Unless otherwise specified or the context otherwise requires, all references in these notes to “Saratoga”, “Company” “we,” “us” or “our” are to Saratoga Resources, Inc., and its subsidiaries.
	Accounting for Reorganization
	On March 31, 2009, Saratoga and its subsidiaries, all of which are 100%-owned: Harvest Oil and Gas, LLC, The Harvest Group, LLC, Lobo Operating, Inc. and Lobo Resources, Inc. (collectively the “Debtors”), filed voluntary petitions under Chapter 11 of the U.S. Bankruptcy Code. The Debtors operated under Chapter 11 protection from the filing date on March 31, 2009 until the effective date of the Debtors’ plan of reorganization (the “Plan of Reorganization”) and exit from Chapter 11 on May 14, 2010. The accompanying consolidated financial statements of Saratoga have been prepared in accordance with FASB ASC 852, Reorganizations. The Company incurred expenses relating to the Plan of Reorganization of $2,319, during the year ended December 31, 2013.
Use of Estimates	Use of Estimates
	The preparation of financial statements in conformity with accounting principles generally accepted in the United States of America requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities at the date of the financial statements and the reported amounts of revenues and expenses during the reporting period. Actual results could differ from those estimates. Material estimates that are particularly susceptible to significant change in the near term include the determination of depreciation, depletion and amortization, plugging and abandonment liabilities, and the valuation of oil and gas property.
Reclassifications	Reclassifications
	Certain reclassifications have been made to prior years’ reported amounts in order to conform to the current year presentation. These reclassifications did not impact our net income, stockholders’ equity or cash flows.
Revenue Recognition	Revenue Recognition
	We recognize oil and gas revenue from interests in producing wells as the oil and gas is sold. Revenue from the purchase, transportation, and sale of natural gas is recognized upon completion of the sale and when transported volumes are delivered. We recognize revenue related to gas balancing agreements based on the sales method. Our net imbalance position at December 31, 2014 and 2013 was immaterial.
Concentration of Credit Risk	Concentration of Credit Risk
	Financial instruments that potentially subject the Company to a concentration of credit risk include cash, cash equivalents and any marketable securities. The Company had cash deposits of approximately $10.7 million and $32.3 million in excess of FDIC insured limits at December 31, 2014 and 2013, respectively. The Company has not experienced any losses on its deposits of cash and cash equivalents.
Major Customers	Major Customers
	Sales of oil and gas production to Shell Trading (US) Company and Shell Energy North America (US), L.P. (collectively “Shell”) and Chevron Natural Gas, Inc. and Chevron Products Company (collectively “Chevron”) accounted for 50% and 37%, respectively, of our consolidated sales in 2014. Sales of oil and gas production to Shell and Chevron accounted for 57% and 32%, respectively, of our consolidated sales in 2013. We believe that the loss of any of these purchasers would not have a material adverse effect on us because alternative purchasers are readily available.
Cash and Cash Equivalents	Cash and Cash Equivalents
	For the purpose of the Statement of Cash Flows, we consider all highly liquid investments with an original maturity of three months or less to be cash equivalents.
Accounts Receivable	Accounts Receivable
	Receivables are carried at original invoice amount. Uncollectible accounts receivable are charged directly against earnings when they are determined to be uncollectible. Use of this method does not result in a material difference from the valuation method required by generally accepted accounting principles. At December 31, 2014 and 2013, no reserve for allowance for doubtful accounts was needed.
Oil and Gas Operations	Oil and Gas Operations
	Oil and gas exploration and development costs are accounted for using the successful efforts method of accounting.
	Oil and gas leasehold acquisition costs are capitalized and included in the balance sheet caption properties, plants and equipment. Leasehold impairment is recognized based on exploratory experience and management’s judgment. Upon achievement of all conditions necessary for the classification of reserves as proved, the associated leasehold costs are reclassified into proved properties.
	Oil and gas exploration costs and the costs of carrying and retaining undeveloped properties are expensed as incurred. Exploratory well costs are capitalized, or “suspended,” on the balance sheet pending further evaluation of whether economically recoverable reserves have been found. If economically recoverable reserves are not found, exploratory well costs are expensed as dry holes. If exploratory wells encounter potentially economic quantities of oil and gas, the well costs remain capitalized on the balance sheet as long as sufficient progress assessing the reserves and the economic and operating viability of the project is being made. For complex exploratory discoveries, it is not unusual to have exploratory wells remain suspended on the balance sheet for several years while we perform additional appraisal drilling and seismic work on the potential oil and gas field, or while we seek government or co-venture approval of development plans or seek environmental permitting. Once all required approvals and permits have been obtained, the projects are moved into the development phase, and the oil and gas reserves are designated as proved reserves.
	Oil and gas development costs incurred to drill and equip development wells, including unsuccessful development wells, are capitalized.
	Depreciation, depletion and amortization of the cost of proved oil and gas properties is calculated using the unit-of-production method. The reserve base used to calculate depreciation, depletion and amortization for leasehold acquisition costs and the cost to acquire proved properties is the sum of proved developed reserves and proved undeveloped reserves. With respect to lease and well equipment costs, which include development costs and successful exploration drilling costs, the reserve base includes only proved developed reserves. Estimated future dismantlement, restoration and abandonment costs, net of salvage values, are taken into account. Depletion expense for the years ended December 31, 2014 and 2013 was $17,741,322 and $17,145,473, respectively.
	Assets are grouped in accordance with the Extractive Industries - Oil and Gas Topic of the Financial Accounting Standards Board (FASB) Accounting Standards Codification (ASC). The basis for grouping is a reasonable aggregation of properties with a common geological structural feature or stratigraphic condition, such as a reservoir or field.
	Amortization rates are updated quarterly to reflect: 1) the addition of capital costs, 2) reserve revisions (upwards or downwards) and additions, 3) property acquisitions and/or property dispositions and 4) impairments.
	When circumstances indicate that an asset may be impaired, Saratoga compares expected undiscounted future cash flows at a producing field level to the unamortized capitalized cost of the asset. If the future undiscounted cash flows, based on Saratoga’s estimate of future natural gas and crude oil prices, operating costs, anticipated production from proved reserves and other relevant data, are lower than the unamortized capitalized cost, the capitalized cost is reduced to fair value. Fair value is calculated by discounting the future cash flows at an appropriate risk-adjusted discount rate. During the years ended December 31, 2014 and 2013, Saratoga recorded impairment expense of $107,774,206 and $2,179,075, respectively. The impairment expense during 2014 reflected the reclassification of certain reserves out of the proved undeveloped category and into the probable category due to application of the SEC's "five year rule" and the steep decline in commodity prices which resulted in the expected undiscounted future cash flows at a producing field level to be less than the unamortized capitalized cost of assets in several fields. The impairment expense during 2013 related to the loss of a lease, and associated reserves, at one field.
	We record the fair value of legal obligations to retire and remove long-lived assets in the period in which the obligation is incurred (typically when the asset is installed at the production location). When the liability is initially recorded, we capitalize this cost by increasing the carrying amount of the related properties, plants and equipment. Over time the liability is increased for the change in its present value, and the capitalized cost in properties, plants and equipment is depreciated over the useful life of the related asset.
	Environmental expenditures are expensed or capitalized, depending upon their future economic benefit. Expenditures that relate to an existing condition caused by past operations, and do not have a future economic benefit, are expensed. Liabilities for environmental expenditures are recorded on an undiscounted basis (unless acquired in a purchase business combination) when environmental assessments or cleanups are probable and the costs can be reasonably estimated. Recoveries of environmental remediation costs from other parties, such as state reimbursement funds, are recorded as assets when their receipt is probable and estimable.
Derivative Instruments and Hedging Activities	Derivative Instruments and Hedging Activities
	All derivative instruments are recorded in our consolidated balance sheets as either an asset or liability and measured at fair value. Changes in the derivative instrument’s fair value are recognized currently in earnings, unless the derivative instrument has been designated as a cash flow hedge and specific cash flow hedge accounting criteria are met. Under cash flow hedge accounting, unrealized gains and losses are reflected in shareholders’ equity as accumulated other comprehensive income (loss) (OCI) until the forecasted transaction occurs. The derivative’s gains or losses are then offset against related results on the hedged transaction in the statements of operations.
	The Company must formally document, designate and assess the effectiveness of transactions that receive hedge accounting. Only derivative instruments that are expected to be highly effective in offsetting anticipated gains or losses on the hedged cash flows and that are subsequently documented to have been highly effective can qualify for hedge accounting. Effectiveness must be assessed both at inception of the hedge and on an ongoing basis. Any ineffectiveness in hedging instruments whereby gains or losses do not exactly offset anticipated gains or losses of hedged cash flows is measured and recognized in earnings in the period in which it occurs. When using hedge accounting, we assess hedge effectiveness quarterly based on total changes in the derivative instrument’s fair value by performing regression analysis. A hedge is considered effective if certain statistical tests are met. We record hedge ineffectiveness in oil and gas hedging. At December 31, 2014, none of our hedges qualified for hedge accounting. At December 31, 2013, none of our hedges met the statistical tests for effectiveness.
	We designate our commodity derivative instruments as cash flow hedges. Changes in the fair value commodity derivative instruments used as cash flow hedges are reported in OCI, to the extent the hedge is effective, until the forecasted transaction occurs, at which time they are recognized in earnings.
Depreciation of Other Property and Equipment	Depreciation of Other Property and Equipment
	Furniture, fixtures, equipment, and other assets are depreciated using the straight-line method over the estimated useful lives of the assets. The estimated lives of these assets range from three to five years.
Debt Issuance Costs and Debt Discount	Debt Issuance Costs and Debt Discount
	Debt issuance costs incurred are capitalized and amortized, using the interest method, over the term of the related debt.
	The amount of discount at which debt is has been issued is amortized into interest expense, using the interest method, over the term of the related debt.
Stock Based Compensation	Stock Based Compensation
	In accordance with the provisions of the Stock Compensation Topic of the ASC (ASC Topic 718), Saratoga measures the cost of employee services received in exchange for an award of equity instruments based on the grant-date fair value of the award.
Income Taxes	Income Taxes
	We account for income taxes under the provisions of the Income Taxes Topic of the ASC (ASC Topic 740). ASC Topic 740 requires the asset and liability approach for accounting for income taxes. Under this approach, deferred tax assets and liabilities are recognized based on anticipated future tax consequences attributable to differences between financial statement carrying amounts of assets and liabilities and their respective tax basis.
	We routinely assess the realizability of our deferred tax assets. If we conclude that it is more likely than not that some portion or all of the deferred tax assets will not be realized under accounting standards, the tax asset is reduced by a valuation allowance. At December 31, 2014 and 2013, a valuation allowance was provided for the entire balance of the net deferred tax asset in the amount of $64,480,235 and $13,837,850, respectively. In addition we routinely assess uncertain tax positions, and accrue for tax positions that are not more-likely-than-not to be sustained upon examination by taxing authorities.
Net Income Per Share	Net Income Per Share
	Basic net income per share is computed on the basis of the weighted-average number of common shares outstanding during the periods. Diluted net income per share is computed based upon the weighted-average number of common shares plus the assumed issuance of common shares for all potentially dilutive securities (see Note 11 – “Common Stock”).
Recently Issued Accounting Standards and Developments	Recently Issued Accounting Standards and Developments
	In May 2014, the Financial Accounting Standards Board ("FASB") issued Accounting Standards Update ("ASU") 2014?09, Revenue from Contracts with Customers (Topic 606) ("ASU 2014-09"), which supersedes nearly all existing revenue recognition guidance under existing generally accepted accounting principles. This new standard is based upon the principal that revenue is recognized to depict the transfer of goods or services to customers in an amount that reflects the consideration to which the entity expects to be entitled in exchange for those goods or services. ASU 2014-09 also requires additional disclosure about the nature, amount, timing and uncertainty of revenue and cash flows arising from customer contracts. ASU 2014-09 is effective for annual and interim periods beginning after December 15, 2016. Early adoption is not permitted and entities have the option of using either a retrospective or modified approach to adopt ASU 2014-09. The Company is currently evaluating the new guidance and has not determined the impact this standard may have on its financial statements or decided upon the method of adoption.
	In August 2014, the FASB issued ASU No. 2014-15, Presentation of Financial Statements - Going Concern (Subtopic 205-40): Disclosure of Uncertainties about an Entity's Ability to Continue as a Going Concern ("ASU 2014-15"). ASU 2014-15 provides guidance about management's responsibility to evaluate whether there is substantial doubt about an entity's ability to continue as a going concern and sets rules for how this information should be disclosed in the financial statements. ASU 2014-15 is effective for annual periods ending after December 15, 2016 and interim periods thereafter. The Company plans to adopt ASU 2014-15 prospectively for the annual period ending December 31, 2016. Pursuant to ASU 2014-15, the Company is required to consider whether there are adverse conditions or events that raise substantial doubt about the Company's ability to continue as a going concern within one year after the date that the financial statements are issued and the probability that management's plans will mitigate the adverse conditions or events (if any). Adverse conditions or events would include, but not be limited to, negative financial trends (such as recurring operating losses, working capital deficiencies, or insufficient liquidity), a need to restructure outstanding debt to avoid default, and industry developments (for example commodity price declines and regulatory changes).

Other_Assets_Tables

Other Assets (Tables)	12 Months Ended
	Dec. 31, 2014
Deferred Costs, Capitalized, Prepaid, and Other Assets Disclosure [Abstract]
Schedule of Other Assets		December 31,
		2014		2013
	Site specific trust accounts – P&A escrow	$	5,564,129	$	5,521,913
	Debt issuance cost, net		4,077,060		6,351,806
	Restricted cash – P&A bond		10,628,903		9,738,353
	Other		80,563		53,758
		$	20,350,655	$	21,665,830

Debt_Tables

Debt (Tables)	12 Months Ended
	Dec. 31, 2014
Debt Disclosure [Abstract]
Schedule of Debt		December 31,
		2014		2013
	10% First Lien Notes due 2015	$	54,600,000	$	54,600,000
	12 ½% Second Lien Notes due 2016		125,200,000		152,500,000
	Less unamortized discount		-999,116		-1,603,016
		$	178,800,884	$	178,196,984

Derivative_Instruments_and_Hed1

Derivative Instruments and Hedging Activities (Tables)	12 Months Ended
	Dec. 31, 2014
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Schedule of Hedge Contracts		Beginning		Ending		Fixed		Strike				Total
	Instrument	Date		Date		Price		Price		Premium		Bbls
	Covered Call	1-Apr-14		31-Mar-15		$	-	$	103.3	$	6.8	22,500
												22,500
Schedule of Derivative Liabilities at Fair Value		December 31,
	Description	2014			2013
	Current liabilities
	Commodity derivatives	$	117		$	837,758
		$	117		$	837,758
		December 31,
	Description	2014			2013
	Long-term liabilities
	Commodity derivatives	$	-		$	182,174
		$	-		$	182,174
Schedule of Derivative Instruments Effect on Income (Loss)		For the Year Ended December 31,
	Description	2014			2013
	Unrealized mark-to-market loss	$	-117		$	-1,019,932
	Realized gain (loss) on settlements		1,550,754			-681,637
	Total gain (loss) on commodity derivative instruments	$	1,550,637		$	-1,701,569
Schedule of Derivative Instruments Effect on Other Comprehensive Income (Loss)		For the Year Ended December 31,
	Description	2014			2013
	Unealized mark-to-market gain(loss) in other comprehensive income (loss)	$	-		$	171,086
	Total other comprehensive income (loss)	$	-		$	171,086

Fair_Value_Measurements_Tables

Fair Value Measurements (Tables)	12 Months Ended
	Dec. 31, 2014
Fair Value Disclosures [Abstract]
Fair Value, Liabilities Measured on Recurring Basis	Description	Level 1	Level 2		Level 3	Total
	Liabilities:
	Commodity derivatives	$	$	117	$	$	117
		$	$	117	$	$	117
	Description	Level 1	Level 2		Level 3	Total
	Liabilities:
	Commodity derivatives	$	$	1,019,932	$	$	1,019,932
		$	$	1,019,932	$	$	1,019,932

Oil_and_Gas_Assets_Tables

Oil and Gas Assets (Tables)	12 Months Ended
	Dec. 31, 2014
Oil and Gas Property [Abstract]
Property and Equipment		December 31,
		2014		2013
	Oil and gas properties (proved):
	Gross oil and gas properties (proved)	$	301,399,079	$	286,441,663
	Accumulated depreciation, depletion, amortization and impairment		-225,896,843		-100,381,317
	Net oil and gas properties (proved)		75,502,236		186,060,346
	Other property and equipment		1,031,779		892,694
	Accumulated depreciation and amortization		-819,558		-707,379
	Net other property and equipment		212,221		185,315
	Net property and equipment	$	75,714,457	$	186,245,661

Asset_Retirement_Obligations_T

Asset Retirement Obligations (Tables)	12 Months Ended
	Dec. 31, 2014
Asset Retirement Obligation Disclosure [Abstract]
Schedule of Change in Assets Retirement Obligation	Balance at December 31, 2012	$	17,071,936
	Accretion expense		2,552,381
	Additions		62,808
	Revisions		-6,509,866
	Settlements		-527,801
	Balance at December 31, 2013	$	12,649,458
	Accretion expense		1,793,865
	Additions		24,766
	Revisions		1,929,715
	Settlements		-
	Balance at December 31, 2014	$	16,397,804

Commitments_and_Contingencies_

Commitments and Contingencies (Tables)	12 Months Ended
	Dec. 31, 2014
Commitments and Contingencies Disclosure [Abstract]
Contractual Obligation Fiscal Year Maturity Schedule		Total		2015		2016 – 2017		2018 – 2019		Thereafter
	Debt	$	188,990,000	$	188,990,000	$	-	$	-	$	-
	Operating leases		432,667		168,167		264,500		-		-
	Asset retirement obligations		56,239,500		-		5,695,000		348,000		50,196,500
	Total	$	245,662,167	$	189,158,167	$	5,959,500	$	348,000	$	50,196,500

Common_Stock_Tables

Common Stock (Tables)	12 Months Ended
	Dec. 31, 2014
Disclosure of Compensation Related Costs, Share-based Payments [Abstract]
Schedule of Earnings Per Share Reconciliation			For the Year Ended December, 31
				2014			2013
	Income (loss) attributable to common stock		$	-143,911,025		$	-26,394,459
	Weighted average number of shares outstanding, basic			30,967,533			30,932,541
	Incremental shares from assumed conversion of dilutive stock options and warrants			-			-
	Weighted average number of shares outstanding, diluted:			30,967,533			30,932,541
	Net Income (loss) per share, basic			-4.65			-0.85
	Net Income (loss) per share, diluted			-4.65			-0.85
	Number of antidilutive stock options and warrants excluded from calculation above			1,799,498			1,754,497
Schedule of Share Based Compensation Stock Options Activity		Number of			Weighted			Weighted		Weighted	Aggregate
		Shares			Average			Average		Average	Intrinsic
		Underlying			Exercise			Grant		Remaining	Value (1)
		Options			Price per			Date Fair		Contractual
					Share			Value per		Life (in
								Share		Years)
	Outstanding at December 31, 2012		784,000		$	3.66		$	3.65	6.5	$	474,240
	Granted		830,000			2.6			1.32	5.2		-
	Exercised		-6,500			1.53			1.53	-		-
	Forfeited		-			-			-	-		-
	Outstanding at December 31, 2013		1,607,500		$	3.13		$	2.46	5.4	$	39,000
	Granted		525,000			1.4			0.91	6.4		-
	Exercised		-40,000			1.53			1.53	-		-
	Forfeited		-440,000			3.21			3.12	-		-
	Outstanding at December 31, 2014		1,652,500			2.59			1.81	4.8		-
	Exercisable at December 31, 2014		1,045,000		$	3.03		$	2.18	4.4	$	-
	____________________
	(1) The intrinsic value of an option is the amount by which the market value of our common stock at the indicated date, or at the time of exercise, exceeds the exercise price of the option. On December 31, 2014, the last reported sales price of our common stock on the NYSE MKT was $0.217 per share.
Schedule of Share Based Compensation Outstanding and Exercisable	Options Outstanding and Exercisable
	Exercise			Number of		Weighted			Weighted
	Price			Shares		Average			Average
				Underlying		Exercise			Remaining
				Options		Price per			Contractual
						Share			Life (in
									Years)
	$	0.36		50,000		$	0.02		0.2
		1.3		50,000			0.06		0.3
		1.39		10,000			0.01		0.01
		1.53		20,000			0.03		0.11
		1.71		2,500			0.04		0.01
		1.72		30,000			0.05		0.16
		1.89		52,500			0.09		0.32
		2.18		105,000			0.22		0.55
		2.34		5,000			0.01		0.03
		2.42		20,000			0.05		0.1
		2.75		30,000			0.08		0.18
		3		435,000			1.25		1.54
		3.05		70,000			0.2		0.21
		4.62		30,000			0.13		0.11
		5.11		30,000			0.15		0.11
		6.65		105,000			0.67		0.45
				1,045,000		$	3.03		4.39
Schedule of Warrants Outstanding		Number of			Weighted			Weighted		Weighted	Aggregate
		Shares			Average			Average		Average	Intrinsic
		Underlying			Exercise			Grant		Remaining	Value (1)
		Warrants			Price per			Date Fair		Contractual
					Share			Value per		Life (in
								Share		Years)
	Outstanding at December 31, 2012		572,628		$	5.14		$	3.22	0.8	$	132,900
	Granted		-			-			-	-		-
	Exercised		-35,000			0.4			0.22	-		-
	Forfeited		-390,630			5			2.69	-		-
	Outstanding at December 31, 2013		146,998		$	6.64		$	5.33	0.8	$	-
	Granted		-			-			-	-		-
	Exercised		-			-			-	-		-
	Forfeited		-			-			-	-		-
	Outstanding at December 31, 2014		146,998		$	6.64		$	5.33	0.36	$	-
	Exercisable at December 31, 2014		146,998		$	6.64		$	5.33	0.36	$	-
	_____________________
	(1) The intrinsic value of a warrant is the amount by which the market value of our common stock at the indicated date, or at the time of exercise, exceeds the exercise price of the warrant. On December 31, 2014, the last reported sales price of our common stock on the NYSE MKT was $0.217 per share.
Schedule of Stockholders' Equity Note, Warrants or Rights	Warrants Outstanding and Exercisable
	Exercise			Number of		Weighted			Weighted
	Price			Shares		Average			Average
				Underlying		Exercise			Remaining
				Warrants		Price per			Contractual
						Share			Life (in
									Years)
	$	3		40,000		$	0.82		0.08
		8		106,998			5.82		0.28
				146,998		$	6.64		0.36

Income_Taxes_Tables

Income Taxes (Tables)	12 Months Ended
	Dec. 31, 2014
Income Tax Disclosure [Abstract]
Schedule of Components of Income Tax Expense Benefit			2014			2013
	Current:
	Federal		$	-		$	-
	State			189,855			130,881
				189,855			130,881
	Deferred:
	Federal			-			8,499,575
	State			-			-
				-			8,499,575
	Total tax provision (benefit)		$	189,855		$	8,630,456
Schedule of Effective Income Tax Rate Reconciliation			2014		2013
	Income tax expense at U.S. federal statutory rate		35.00%		35.00%
	Valuation allowance		-35.00%		-77.90%
	State and local income taxes, net of federal income tax benefit		-		-
	Permanent differences		-		-0.40%
	Temporary differences		-0.10%		-5.30%
	Effective tax rate		-0.10%		-48.60%
Schedule of Deferred Tax Assets and Liabilities	Deferred tax asset
	Net operating loss	$	40,218,636		$	25,864,942
	Stock-based compensation		2,712,889			2,527,973
	Debt issuance cost (amortization)		1,245,012			1,245,012
	Depletion on oil and gas properties		19,784,120			-
	Derivatives		416,856			59,880
	Depreciation and amortization		-6,802			-12,970
	Capital loss carryover		94,936			94,936
	Charitable contributions		14,588			14,588
	Total deferred tax assets		64,480,235			29,794,361
	Deferred tax liability
	Depletion on oil and gas properties		-			15,956,511
	Total deferred tax liabilities		-			15,956,511
	Less: valuation allowance		64,480,235			13,837,850
	Deferred tax asset (liability)	$	-		$	-

Supplemental_Oil_and_Gas_Discl1

Supplemental Oil and Gas Disclosures - Unaudited (Tables)	12 Months Ended
	Dec. 31, 2014
Oil and Gas Exploration and Production Industries Disclosures [Abstract]
Capitalized Costs Relating to Oil and Gas Producing Activities		2014		2013
	Proved properties	$	301,399,079	$	286,441,663
	Unproved properties		-		-
			301,399,079		286,441,663
	Accumulated depreciation, depletion, amortization and impairment		-225,896,843		-100,381,317
	Net capitalized costs	$	75,502,236	$	186,060,346
Costs Incurred in Oil and Gas Property Acquisition Exploration and Development Activities		2014		2013
	Acquisitions of properties:
	Proved	$	-	$	1,380,000
	Unproved		-		-
	Exploration and dry hole costs		706,904		900,255
	Development		12,927,757		29,790,284
		$	13,634,661	$	32,070,539
Results of Operations for Oil and Gas Producing Activities		2014		2013
	Oil and gas revenues	$	52,325,716	$	68,696,055
	Lease operating expense		-24,631,620		-21,685,103
	Workover expense		-4,537,031		-2,475,541
	Exploration expense		-706,904		-900,255
	Loss on plugging and abandonment		-		-701,241
	Depreciation, depletion and amortization		-17,853,499		-17,269,349
	Impairment expense		-107,774,206		-2,179,075
	Accretion expense		-1,793,865		-2,552,381
	Gain on revision of asset retirement obligations		75,178		564,719
	Severance taxes		-3,649,814		-7,274,808
	Income before income taxes		-108,546,045		14,223,021
	Income tax benefit (provision)		-189,855		-8,630,456
	Results of operations for oil and gas producing activities (excluding Corporate overhead and financing costs)	$	-108,735,900	$	5,592,565
Schedule of Proved Developed and Undeveloped Oil and Gas Reserve Quantities			Gas (Mcf)	Oil (Bbls)		Boe
	For the year ended December 31, 2013
	Beginning of year		52,918,300	8,406,600		17,226,317
	Acquisition of reserves		8,834,500	1,268,000		2,740,417
	Discoveries and extensions		3,011,500	261,200		763,116
	Improved recovery		-	-		-
	Revisions		-15,569,000	-92,900		-2,687,733
	Production		-1,198,800	-603,600		-803,400
	End of year		47,996,500	9,239,300		17,238,717
	Proved developed reserves
	Beginning of year		9,159,500	2,809,200		4,335,783
	End of year		6,880,800	3,245,700		4,392,500
	For the year ended December 31, 2014
	Beginning of year		47,996,500	9,239,300		17,238,717
	Acquisition of reserves		-	-		-
	Discoveries and extensions		-	-		-
	Improved recovery		-	-		-
	Revisions		-20,467,200	-2,935,300		-6,346,500
	Production		-950,100	-511,700		-670,050
	End of year		26,579,200	5,792,300		10,222,167
	Proved developed reserves
	Beginning of year		6,880,800	3,245,700		4,392,500
	End of year		5,204,700	2,898,500		3,765,950
Standardized Measure of Discounted Future Cash Flows Relating to Proved Reserves
	(dollars in thousands)	2014		2013
	Future cash inflows	$	704,959	$	1,213,823
	Future production costs		-242,110		-297,786
	Future development costs		-167,409		-255,309
	Future net cash flows before income taxes		295,440		660,728
	Future income tax expense		-35,150		-181,935
	Future net cash flows before 10% discount		260,290		478,793
	10% annual discount for estimating timing of cash flows		-71,495		-178,003
	Standardized measure of discounted future net cash flows	$	188,795	$	300,790
Schedule of Changes in Standardized Measure of Discounted Future Net Cash Flows	(dollars in thousands)	2014		2013
	Beginning of year	$	300,790	$	292,685
	Sales of oil and gas produced, net of production costs		-19,507		-37,261
	Net change in prices and production costs		-66,042		33,720
	Extension, discoveries, and improved recovery, less related costs		-		18,639
	Development costs incurred during the year		2,938		8,230
	Net change in estimated future development costs		5,194		13,418
	Revisions of previous quantity estimates		-209,654		-87,642
	Net change from acquisitions of minerals in place		-		37,224
	Net change in income taxes		89,473		4,235
	Accretion of discount		41,075		40,688
	Changes in timing and other		44,528		-23,146
	End of year	$	188,795	$	300,790

Organization_and_Summary_of_Si1

Organization and Summary of Significant Accounting Policies (Details Narrative) (USD $)	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2013
Reorganization Items Disclosures
Reorganization expenses	$0	$2,319
Concentration of Credit Risks
Cash in excess of FDIC insured amounts, approximate	10,700,000	32,300,000
Oil and Gas Property [Abstract]
Depletion expense	17,741,322	17,145,473
Impairment expense	107,774,206	2,179,075
Property Plant and Equipment
Property plant and equipment	The estimated lives of these assets range from three to five years
Income Taxes
Valuation allowance, net deferred tax assets	$64,480,235	$13,837,850
Shell
Major Customers
Sales of oil and gas production, percent	50.00%	57.00%
Chevron
Major Customers
Sales of oil and gas production, percent	37.00%	32.00%

Going_Concern_Details_Narrativ

Going Concern (Details Narrative) (USD $)	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2013
Going Concern
Loss from operations	($119,467,111)	$3,688,281
Working capital deficit	$185,724,291

Chapter_11_Reorganization_Deta

Chapter 11 Reorganization (Details Narrative) (USD $)	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2013
Reorganizations [Abstract]
Reorganization expenses	$0	$2,319

Other_Assets_Details

Other Assets (Details) (USD $)	Dec. 31, 2014	Dec. 31, 2013
Other Assets, Noncurrent
Site specific trust accounts - P&A escrow	$5,564,129	$5,521,913
Debt issuance cost, net	4,077,060	6,351,806
Restricted cash - P&A bond	10,628,903	9,738,353
Other assets	80,563	53,758
Other assets, net	$20,350,655	$21,665,830

Debt_Short_and_Long_Term_Debt_

Debt - Short and Long Term Debt (Details) (USD $)	Dec. 31, 2014	Dec. 31, 2013
Long Term Debt
10% First Lien Notes due 2015	$54,600,000	$54,600,000
12.5% Second Lien Notes due 2016	125,200,000	125,200,000
Less unamortized discount	999,116	1,603,016
Long-term debt	$178,800,884	$178,196,984

Debt_Details_Narrative

Debt (Details Narrative) (USD $)	12 Months Ended
	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011	Dec. 31, 2014	Nov. 30, 2013
Debt Instrument [Line Items]
First Lien Notes	$54,600,000			$54,600,000
Second Lien Notes	125,200,000			125,200,000
First Lien Notes
Debt Instrument [Line Items]
First Lien Notes					54,600,000
Issuance of senior secured notes	25,400,000
Senior secured notes, maturity date	31-Dec-15
Senior secured notes, interest rate	10.00%
Senior secured notes, debt instrument payment terms	Interest is payable on March 31, June 30, September 30 and December 31 of each year, commencing December 31, 2013.
Senior secured notes, redemption terms	The Company has the option to redeem all or a portion of the First Lien Notes at any time at 100% of the principal amount to be redeemed plus accrued and unpaid interest. Upon the occurrence of a change of control, we are required to offer to purchase the First Lien Notes at a price equal to 101% of the aggregate principal amount of First Lien Notes repurchased plus accrued and unpaid interest. Further, upon the occurrence of certain asset sales, we are required to provide notice of the same and are required to offer to purchase a defined portion of the First Lien Notes at a price equal to 100% of the principal amount of First Lien Notes repurchased plus accrued and unpaid interest.
Accrued interest				1,365,000
Second Lien Notes
Debt Instrument [Line Items]
Second Lien Notes					125,200,000
Issuance of senior secured notes		25,000,000	127,500,000
Senior secured notes, maturity date		1-Jul-16	1-Jul-16
Senior secured notes, interest rate			12.50%
Senior secured notes, debt instrument payment terms		Interest is payable on January 1 and July 1 of each year.	Interest is payable on January 1 and July 1 of each year.
Senior secured notes, discount to par value		98.58%	98.22%
Senior secured notes, redemption terms		The Company has the option to redeem all or a portion of the Second Lien Notes at any time on or after January 1, 2014 at the redemption prices specified in the Indenture plus accrued and unpaid interest.
Retirement of secured notes	27,300,000
Accrued interest				$7,825,000

Derivative_Instruments_and_Hed2

Derivative Instruments and Hedging Activities - Hedge Contracts (Details)	12 Months Ended
	Dec. 31, 2014
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Hedge Contract Instrument, total barrels	22,500
Covered Call
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Hedge Contract Instrument, beginning date	1-Apr-14
Hedge Contract Instrument, ending date	31-Mar-15
Hedge Contract Instrument, strike price	103.3
Hedge Contract Instrument, premium	6.8

Derivative_Instruments_and_Hed3

Derivative Instruments and Hedging Activities - Fair Value of the Commodity Derivative Instruments (Details) (USD $)	Dec. 31, 2014	Dec. 31, 2013
Fair value of commodity derivates
Fair value of commodity derivatives, liabilities, current	$117	$837,758
Fair value of commodity derivatives, liabilities, noncurrent	$0	$182,174

Derivative_Instruments_and_Hed4

Derivative Instruments and Hedging Activities - Effect of Derivative Instruments on Operations and OCI (Details) (USD $)	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2013
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Unrealized mark-to-market gain (loss)	($117)	($1,019,932)
Realized gain (loss) on settlements	1,550,754	-681,637
Total (gain) loss on commodity derivative instruments	1,550,637	-1,701,569
Unrealized mark-to-market gain (loss) in other comprehensive income	0	171,086
Total other comprehensive income (loss)	$0	$171,086

Fair_Value_Measurements_Detail

Fair Value Measurements (Details) (USD $)	Dec. 31, 2014	Dec. 31, 2013
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Commodity derivatives, liabilities	$117	$1,019,932
Fair Value, Inputs, Level 1 | Energy Related Derivative
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Commodity derivatives, liabilities	0	0
Fair Value, Inputs, Level 2 | Energy Related Derivative
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Commodity derivatives, liabilities	117	1,019,932
Fair Value, Inputs, Level 3 | Energy Related Derivative
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Commodity derivatives, liabilities	$0	$0

Oil_and_Gas_Assets_Details

Oil and Gas Assets (Details) (USD $)	Dec. 31, 2014	Dec. 31, 2013
Oil and gas properties (proved):
Gross oil and gas properties (proved)	$301,399,079	$286,441,663
Accumulated depreciation, depletion, amortization and impairment	-225,896,843	-100,381,317
Net oil and gas properties (proved)	75,502,236	186,060,346
Other property and equipment	1,031,779	892,694
Accumulated depreciation and amortization	-819,558	-707,379
Net other property and equipment	212,221	185,315
Total property and equipment, net	$75,714,457	$186,245,661

Oil_and_Gas_Assets_Details_Nar

Oil and Gas Assets (Details Narrative) (USD $)	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2013
Oil and Gas Property [Abstract]
Capitalized costs associated with wells in progress	$1,617,635
Impairment expense	$107,774,206	$2,179,075

Asset_Retirement_Obligations_D

Asset Retirement Obligations (Details) (USD $)	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2013
Asset Retirement Obligations
Asset retirement obligations, beginning of period	$12,649,458	$17,071,936
Accretion expense	1,793,865	2,552,381
Additions	24,766	62,808
Revisions	1,929,715	-6,509,866
Settlements	0	-527,801
Asset retirement obligations, end of period	$16,397,804	$12,649,458

Asset_Retirement_Obligations_D1

Asset Retirement Obligations (Details Narrative) (USD $)	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2013
Asset Retirement Obligation [Abstract]
Escrow account	$5,564,129	$5,521,913
Loss on plugging and abandonment	0	701,241
Gain on revision of asset retirement obligations	$75,178	$564,719

Commitments_and_Contingencies_1

Commitments and Contingencies (Details) (USD $)	Dec. 31, 2014
Commitments and Contingencies Disclosure [Abstract]
Debt commitments due 2015	$188,990,000
Debt commitments due 2016 - 2017	0
Debt commitments due 2018 - 2019	0
Debt commitments due thereafter	0
Operating leases due 2015	168,167
Operating leases due 2016 - 2017	264,500
Operating leases due 2018 - 2019	0
Operating leases due thereafter	0
Asset retirement obligations due 2015	0
Asset retirement obligations due 2016 - 2017	5,695,000
Asset retirement obligations due 2018 - 2019	348,000
Asset retirement obligations due thereafter	$50,196,500

Commitments_and_Contingencies_2

Commitments and Contingencies (Details Narrative) (USD $)	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2013
Commitments and Contingencies Disclosure [Abstract]
Rent expense	$262,250	$244,648
Letters of credit	7,750,000
Litigation settlement description	In February 2010, Saratoga filed a complaint in the United States Bankruptcy Court for the Western District of Louisiana against Barry Ray Salsbury, Brian Carl Albrecht, Shell Sibley, Willie Willard Powell and Carolyn Monica Greer, each being former owners of The Harvest Group LLC and/or Harvest Oil & Gas, LLC. The complaint alleged breach of the Purchase and Sale Agreements with the former owners arising from the underpayment or nonpayment of royalties to the State of Louisiana for periods prior to Saratoga's acquisition of the Harvest Companies and related claims for damages. The claims against all parties other than Brian Carl Albrecht were subsequently settled and the claim against Mr. Albrecht was converted to an arbitration proceeding. Harvest Operating, LLC, a company controlled by Mr. Albrecht, brought a separate cause of action against The Harvest Group, LLC, Harvest Oil & Gas, LLC and Saratoga Resources, Inc. (the "Saratoga Parties"), which cause of action was consolidated with the arbitration proceedings noted above. Harvest Operating's cause of action asserted a claim for damages based on the alleged wrongful termination of rights to use a pipeline owned and operated by the Saratoga Parties and the loss in value of a property operated by Harvest Operating based on its inability to transport production from that property via the pipeline in question. The consolidated arbitration proceeding was conducted before a single arbitrator and, in August 2014, the arbitrator issued an Award and Reasons ruling (1) in favor of Saratoga, as relates to the royalty claim, and awarding to Saratoga $355,879, and (2) in favor of Harvest Operating, as relates to the pipeline use claim, and awarding to Harvest Operating $3,757,050. As a result of such award, the Company recorded an arbitration award expense of $3.4 million.
Arbitration award	3,400,000	0
Accrued liability for arbitration award	$3,400,000

Common_Stock_Earnings_per_Shar

Common Stock - Earnings per Share (Details) (USD $)	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2013
Disclosure of Compensation Related Costs, Share-based Payments [Abstract]
Income (loss) attributable to common stock	($143,911,025)	($26,394,459)
Weighted-average number of shares outstanding, basic	30,967,533	30,932,541
Incremental shares from assumed conversion of dilutive stock options and warrants	0	0
Weighted-average number of shares outstanding, diluted	30,967,533	30,932,541
Net income (loss) per share, basic	($4.65)	($0.85)
Net income (loss) per share, diluted	($4.65)	($0.85)
Number of antidilutive stock options and warrants excluded from calculation above	1,799,498	1,754,497

Common_Stock_Stock_Option_Acti

Common Stock - Stock Option Activity (Details) (USD $)	12 Months Ended
	Dec. 31, 2014		Dec. 31, 2013
Share-Based Compensation Arrangement By Share-Based Payment Award Options Outstanding
Number of Shares Underlying Options Outstanding, beginning of period	1,607,500		784,000
Number of Shares Underlying Options Granted	525,000		830,000
Number of Shares Underlying Options, forfeited	-440,000		0
Number of Shares Underlying Options Outstanding, end of period	1,652,500		1,607,500
Number of Shares Underlying Options Exercisable	1,045,000
Share-Based Compensation Arrangement by Share-Based Payment Award Options Outstanding Weighted Average Exercise Price
Weighted Average Exercise Price Outstanding, beginning of period	$3.13		$3.66
Weighted Average Exercise Price Granted	$1.40		$2.60
Weighted Average Exercise Price Exercised	$1.53		$1.53
Weighted Average Exercise Price, forfeited	$3.21		$0
Weighted Average Exercise Price Outstanding, end of period	$2.59		$3.13
Weighted Average Exercise Price Exercisable	$3.03
Share-based Compensation Arrangement by Share-based Payment Award Options Nonvested Weighted Average Grant Date Fair Value
Weighted Average Grant Date Fair Value Per Share Outstanding, beginning of period	$2.46		$3.65
Weighted Average Grant Date Fair Value Per Share, Granted	$0.91		$1.32
Weighted Average Grant Date Fair Value Per Share, Exercised	$1.53		$1.53
Weighted Average Grant Date Fair Value Per Share, forfeited	$3.12		$0
Weighted Average Grant Date Fair Value Per Share Outstanding, end of period	$1.81		$2.46
Weighted Average Grant Date Fair Value Per Share, Exercisable	$2.18
Share-Based Compensation Arrangement by Share-Based Payment Award Options Additional Disclosures
Weighted Average Remaining Contractual Life (In Years) Outstanding, beginning of period	5 years 5 months		6 years 6 months
Weighted Average Remaining Contractual Life (In Years) Granted	6 years 5 months		5 years 2 months
Weighted Average Remaining Contractual Life (In Years) Outstanding, end of period	4 years 10 months		5 years 5 months
Weighted Average Remaining Contractual Life (In Years) Exercisable	4 years 5 months
Aggregate Intrinsic Value Outstanding, beginning of period	$39,000	[1]	$474,240	[1]
Aggregate Intrinsic Value Outstanding, end of period	$0	[1]	$39,000	[1]
[1]	The intrinsic value of an option is the amount by which the market value of our common stock at the indicated date, or at the time of exercise, exceeds the exercise price of the option. On December 31, 2014, the last reported sales price of our common stock on the NYSE MKT was $0.217 per share.

Common_Stock_Stock_Option_Pric

Common Stock - Stock Option Price Range (Details) (USD $)	12 Months Ended
	Dec. 31, 2014
Options $0.36
Share-based Compensation, Shares Authorized under Stock Option Plans, Exercise Price Range [Line Items]
Exercise price	$0.36
Number of shares underlying options	50,000
Weighted average exercise price per share	$0.02
Weighted average remaining contractual life (in years)	2 months
Options $1.30
Share-based Compensation, Shares Authorized under Stock Option Plans, Exercise Price Range [Line Items]
Exercise price	$1.30
Number of shares underlying options	50,000
Weighted average exercise price per share	$0.06
Weighted average remaining contractual life (in years)	4 months
Options $1.39
Share-based Compensation, Shares Authorized under Stock Option Plans, Exercise Price Range [Line Items]
Exercise price	$1.39
Number of shares underlying options	10,000
Weighted average exercise price per share	$0.01
Weighted average remaining contractual life (in years)	0 months
Options $1.53
Share-based Compensation, Shares Authorized under Stock Option Plans, Exercise Price Range [Line Items]
Exercise price	$1.53
Number of shares underlying options	20,000
Weighted average exercise price per share	$0.03
Weighted average remaining contractual life (in years)	1 month
Options $1.71
Share-based Compensation, Shares Authorized under Stock Option Plans, Exercise Price Range [Line Items]
Exercise price	$1.71
Number of shares underlying options	2,500
Weighted average exercise price per share	$0.04
Weighted average remaining contractual life (in years)	0 months
Options $1.72
Share-based Compensation, Shares Authorized under Stock Option Plans, Exercise Price Range [Line Items]
Exercise price	$1.72
Number of shares underlying options	30,000
Weighted average exercise price per share	$0.05
Weighted average remaining contractual life (in years)	2 months
Options $1.89
Share-based Compensation, Shares Authorized under Stock Option Plans, Exercise Price Range [Line Items]
Exercise price	$1.89
Number of shares underlying options	52,500
Weighted average exercise price per share	$0.09
Weighted average remaining contractual life (in years)	4 months
Options $2.18
Share-based Compensation, Shares Authorized under Stock Option Plans, Exercise Price Range [Line Items]
Exercise price	$2.18
Number of shares underlying options	105,000
Weighted average exercise price per share	$0.22
Weighted average remaining contractual life (in years)	7 months
Options $2.34
Share-based Compensation, Shares Authorized under Stock Option Plans, Exercise Price Range [Line Items]
Exercise price	$2.34
Number of shares underlying options	5,000
Weighted average exercise price per share	$0.01
Weighted average remaining contractual life (in years)	0 months
Options $2.42
Share-based Compensation, Shares Authorized under Stock Option Plans, Exercise Price Range [Line Items]
Exercise price	$2.42
Number of shares underlying options	20,000
Weighted average exercise price per share	$0.05
Weighted average remaining contractual life (in years)	1 month
Options $2.75
Share-based Compensation, Shares Authorized under Stock Option Plans, Exercise Price Range [Line Items]
Exercise price	$2.75
Number of shares underlying options	30,000
Weighted average exercise price per share	$0.08
Weighted average remaining contractual life (in years)	2 months
Options $3.00
Share-based Compensation, Shares Authorized under Stock Option Plans, Exercise Price Range [Line Items]
Exercise price	$3
Number of shares underlying options	435,000
Weighted average exercise price per share	$1.25
Weighted average remaining contractual life (in years)	1 year 6 months
Options $3.05
Share-based Compensation, Shares Authorized under Stock Option Plans, Exercise Price Range [Line Items]
Exercise price	$3.05
Number of shares underlying options	70,000
Weighted average exercise price per share	$0.20
Weighted average remaining contractual life (in years)	3 months
Options $4.62
Share-based Compensation, Shares Authorized under Stock Option Plans, Exercise Price Range [Line Items]
Exercise price	$4.62
Number of shares underlying options	30,000
Weighted average exercise price per share	$0.13
Weighted average remaining contractual life (in years)	1 month
Options $5.11
Share-based Compensation, Shares Authorized under Stock Option Plans, Exercise Price Range [Line Items]
Exercise price	$5.11
Number of shares underlying options	30,000
Weighted average exercise price per share	$0.15
Weighted average remaining contractual life (in years)	1 month
Options $6.65
Share-based Compensation, Shares Authorized under Stock Option Plans, Exercise Price Range [Line Items]
Exercise price	$6.65
Number of shares underlying options	105,000
Weighted average exercise price per share	$0.67
Weighted average remaining contractual life (in years)	5 months

Common_Stock_Stock_Warrant_Act

Common Stock - Stock Warrant Activity (Details) (USD $)	12 Months Ended
	Dec. 31, 2014		Dec. 31, 2013
Share-Based Compensation Arrangement By Share-Based Payment Award Equity Instruments Other Than Options Nonvested
Warrants, outstanding, beginning of period	146,998		572,628
Warrants, exercised	0		-35,000
Warrants, forfeited	0		-390,630
Warrants, outstanding, end of period	146,998		146,998
Warrants, exercisable, end of period	146,998
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Weighted Average Exercise Price
Warrants, weighted average exercise price outstanding, beginning of period	$6.64		$5.14
Warrants, weighted average exercise price exercised	$0		$0.40
Warrants, weighted average exercise price forfeited	$0		$5
Warrants, weighted average exercise price outstanding, end of period	$6.64		$6.64
Warrants, weighted average exercise price exercisable, end of period	$6.64
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested, Weighted Average Grant Date Fair Value
Warrants, weighted average grant date fair value per share outstanding, beginning of period	$5.33		$3.22
Warrants, weighted average grant date fair value per share, exercised	$0		$0.22
Warrants, weighted average grant date fair value per share, forfeited	$0		$2.69
Warrants, weighted average grant date fair value per share outstanding, at end of period	$5.33		$5.33
Warrants, weighted average grant date fair value per share exercisable, end of period	$5.33
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Additional Disclosures
Warrants, weighted average remaining contractual life (in years) outstanding, beginning of period	10 months		10 months
Warrants, weighted average remaining contractual life (in years) exercisable, end of period	4 months		10 months
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Aggregate Intrinsic Value
Warrants, aggregate intrinsic value outstanding, beginning of period	$0	[1],[2]	$132,900	[1]
Warrants, aggregate intrinsic value outstanding, end of period	0	[1]	0	[1],[2]
Warrants, aggregate intrinsic value exercisable, end of period	$0	[1]
[1]	The intrinsic value of a warrant is the amount by which the market value of our common stock at the indicated date, or at the time of exercise, exceeds the exercise price of the warrant. On December 31, 2014, the last reported sales price of our common stock on the NYSE MKT was $0.217 per share.
[2]	The intrinsic value of an option is the amount by which the market value of our common stock at the indicated date, or at the time of exercise, exceeds the exercise price of the option. On December 31, 2014, the last reported sales price of our common stock on the NYSE MKT was $0.217 per share.

Common_Stock_Stock_Warrant_Pri

Common Stock - Stock Warrant Price Range (Details) (USD $)	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Number of shares underlying warrants	146,998	146,998	572,628
Weighted average exercise price per share	$5.33	$5.33	$3.22
Weighted average remaining contractual life (in years)	10 months	10 months
Warrants $3.00
Warrant exercise price	$3
Number of shares underlying warrants	40,000
Weighted average exercise price per share	$0.82
Weighted average remaining contractual life (in years)	8 months
Warrants $8.00
Warrant exercise price	$8
Number of shares underlying warrants	106,998
Weighted average exercise price per share	$5.82
Weighted average remaining contractual life (in years)	3 months

Common_Stock_Common_Stock_Opti

Common Stock - Common Stock, Option and Warrant Activity (Details Narrative) (USD $)	12 Months Ended				1 Months Ended
	Dec. 31, 2014		Dec. 31, 2013		Sep. 30, 2014	31-May-14	Apr. 30, 2014	Feb. 28, 2014	Aug. 31, 2013	Jul. 31, 2013	Apr. 30, 2013	Jun. 30, 2013	Jun. 30, 2014	Dec. 31, 2012		Sep. 30, 2011
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Stock option grants authorized	525,000		830,000
Stock options grant date value	$0	[1]	$39,000	[1]										$474,240	[1]
2011 Omnibus Equity Plan reserved shares																3,000,000
Unrecognized stock-based compensation expense	286,407		614,885
Shares of common stock issued upon exercise of stock options	40,000		6,500
Proceeds received from stock options exercised	61,200		9,945
Stock-based compensation expense	528,330		1,001,160
Stock issued upon conversion of warrants			35,000
Stock issued upon conversion of warrants, value			13,850
Non-Executive Employee / Stock Options
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Stock option grants authorized					30,000	60,000	60,000	90,000	90,000	60,000	75,000
Stock options exercisable term					7 years	7 years	7 years	7 years	7 years	7 years	7 years
Stock options exercisable price					$1.47	$1.30	$1.22	$1.32	$1.72	$1.53
Stock options exercise price range, lower range limit											$2.34
Stock options exercise price range, upper range limit											$2.42
Stock options vesting period					Vest 1/3 on each of the first three grant date anniversaries.	Vest 1/3 after six months and 1/3 on each of the first two grant date anniversaries.	Vest 1/3 on each of the first three grant date anniversaries.	Vest 1/3 on each of the first three grant date anniversaries.	Vest 1/3 on each of the first three grant date anniversaries.	Vest 1/3 on each of the first three grant date anniversaries.	Vest 1/3 on each of the first three grant date anniversaries.
Stock options grant date value					29,700	47,400	57,000	96,300	150,300	90,600	178,200
Stock options fair value assumptions, expected volatility rate					90.00%	83.00%	113.00%	121.00%	204.00%	231.00%	240.00%
Stock options fair value assumptions, estimated life					4 years 6 months	4 years 1 month	4 years 6 months	4 years 6 months	4 years 6 months	4 years 6 months	4 years 6 months
Stock options fair value assumptions, dividends					0.00%	0.00%	0.00%	0.00%	0.00%	0.00%	0.00%
Stock options fair value assumptions, discount rate					1.62%	1.26%	1.47%	1.36%	1.18%	1.18%
Non-Executive Employee / Stock Options | Minimum
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Stock options fair value assumptions, discount rate											0.60%
Non-Executive Employee / Stock Options | Maximum
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Stock options fair value assumptions, discount rate											0.62%
Non-Executive Employee / Stock Options #2
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Stock option grants authorized							90,000
Stock options exercisable term							7 years
Stock options exercisable price							$1.18
Stock options vesting period							Vest 1/3 after six months and 1/3 on each of the first two grant date anniversaries.
Stock options grant date value							70,200
Stock options fair value assumptions, expected volatility rate							92.00%
Stock options fair value assumptions, estimated life							4 years 1 month
Stock options fair value assumptions, dividends							0.00%
Stock options fair value assumptions, discount rate							1.25%
Executive Officers
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Stock option grants authorized						90,000						500,000
Stock options exercisable term						7 years						5 years
Stock options exercisable price						$1.30						$3
Stock options vesting period						Vest 1/3 after six months and 1/3 on each of the first two grant date anniversaries.						Vest 1/8 per quarter
Stock options grant date value						71,100						505,000
Stock options fair value assumptions, expected volatility rate						83.00%						83.00%
Stock options fair value assumptions, estimated life						4 years 1 month						3 years 1 month
Stock options fair value assumptions, dividends						0.00%						0.00%
Stock options fair value assumptions, discount rate						1.26%						0.57%
Share price												$2.18
Non-Employee Directors
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Stock option grants authorized												105,000	105,000
Stock options exercisable term												7 years	7 years
Stock options exercisable price												$2.18	$1.89
Stock options vesting period												Vest 1/2 on the date of grant and 1/2 on the first anniversary of the grant date.	Vest 1/2 on the date of grant and 1/2 on the first anniversary of the grant date.
Stock options grant date value												$174,300	$103,950
Stock options fair value assumptions, expected volatility rate												121.00%	72.00%
Stock options fair value assumptions, estimated life												3 years 9 months	3 years 9 months
Stock options fair value assumptions, dividends												0.00%	0.00%
Stock options fair value assumptions, discount rate												0.77%	1.24%
[1]	The intrinsic value of an option is the amount by which the market value of our common stock at the indicated date, or at the time of exercise, exceeds the exercise price of the option. On December 31, 2014, the last reported sales price of our common stock on the NYSE MKT was $0.217 per share.

Income_Taxes_Tax_Provision_Rec

Income Taxes - Tax Provision Reconcilation (Details) (USD $)	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2013
Current:
Federal	$0	$0
State	189,855	130,881
Deferred:
Federal	0	8,499,575
State	0	0
Total tax provision (benefit)	$189,855	$8,630,456

Income_Taxes_Tax_Rate_Reconcil

Income Taxes - Tax Rate Reconciliation (Details)	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2013
Income Tax Disclosure [Abstract]
Income tax expense at U.S. federal statutory rate	35.00%	35.00%
Valuation allowance	-35.00%	-77.90%
State and local income taxes, net of federal income tax benefit	0.00%	0.00%
Permanent differences	0.00%	-0.40%
Temporary differences	-0.10%	-5.30%
Effective tax rate	-0.10%	-48.60%

Income_Taxes_Components_of_the

Income Taxes - Components of the Net Deferred Tax Assets and Liabilities (Details) (USD $)	Dec. 31, 2014	Dec. 31, 2013
Deferred tax asset
Net operating loss	$40,218,636	$25,864,942
Stock-based compensation	2,712,889	2,527,973
Debt issuance cost (amortization)	1,245,012	1,245,012
Depletion on oil and gas properties	19,784,120	0
Derivatives	416,856	59,880
Depreciation and amortization	-6,802	-12,970
Capital loss carryover	94,936	94,936
Charitable contributions	14,588	14,588
Total deferred tax assets	64,480,235	29,794,361
Deferred tax liability
Depletion on oil and gas properties	0	15,956,511
Total deferred tax liabilities	0	15,956,511
Less: valuation allowance	64,480,235	13,837,850
Deferred tax asset (liability)	$0	$0

Income_Taxes_Details_Narrative

Income Taxes (Details Narrative) (USD $)	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2013
Income Tax Disclosure [Abstract]
Net operating loss carryforwards	$114,900,000
Net operating loss carryforwards expiration	31-Dec-34
Deferred tax asset, valuation allowance	$64,480,235	$13,837,850

Supplemental_Oil_and_Gas_Discl2

Supplemental Oil and Gas Disclosures - Capitalized Costs - Unaudited (Details) (USD $)	Dec. 31, 2014	Dec. 31, 2013
Oil and Gas Exploration and Production Industries Disclosures [Abstract]
Proved properties	$301,399,079	$286,441,663
Unproved properties	0	0
Capitalized costs for proved and unproved properties	301,399,079	286,441,663
Accumulated depreciation, depletion, amortization and impairment	-225,896,843	-100,381,317
Net capitalized costs	$75,502,236	$186,060,346

Supplemental_Oil_and_Gas_Discl3

Supplemental Oil and Gas Disclosures - Property Acquisitions, Exploration and Development - Unaudited (Details) (USD $)	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2013
Acquisitions of properties:
Proved	$0	$1,380,000
Unproved	0	0
Exploration and dry hole costs	706,904	900,255
Development	12,927,757	29,790,284
Total costs incurred for oil and gas property acquisitions, exploration and development	$13,634,661	$32,070,539

Supplemental_Oil_and_Gas_Discl4

Supplemental Oil and Gas Disclosures - Consolidated Results of Operations - Unaudited (Details) (USD $)	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2013
Oil and Gas Exploration and Production Industries Disclosures [Abstract]
Oil and gas revenues	$52,325,716	$68,696,055
Lease operating expense	-24,631,620	-21,685,103
Workover expense	-4,537,031	-2,475,541
Exploration expense	-706,904	-900,255
Loss on plugging and abandonment	0	-701,241
Depreciation, depletion and amortization	-17,853,499	-17,269,349
Impairment expense	-107,774,206	-2,179,075
Accretion expense	-1,793,865	-2,552,381
Gain on revision of asset retirement obligations	75,178	564,719
Severance taxes	-3,649,814	-7,274,808
Income before income taxes	-108,546,045	14,223,021
Income tax benefit (provision)	-189,855	-8,630,456
Results of operations for oil and gas producing activities (excluding Corporate overhead and financing costs)	($108,735,900)	$5,592,565

Supplemental_Oil_and_Gas_Discl5

Supplemental Oil and Gas Disclosures - Estimated Total Net Proved Reserves - Unaudited (Details)	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2013
	Mcf	Mcf
Gas (Mcf)
Reserve Quantities [Line Items]
Estimated net proved reserves, beginning of year	47,996,500	52,918,300
Acquisition of reserves	0	8,834,500
Discoveries and extensions	0	3,011,500
Improved recovery	0	0
Revisions	-20,467,200	-15,569,000
Production	-950,100	-1,198,800
Estimated net proved reserves, end of year	26,579,200	47,996,500
Proved developed reserves
Proved developed reserves, beginning of year	6,880,800	9,159,500
Proved developed reserves, end of year	5,204,700	6,880,800
Oil (Bbls)
Reserve Quantities [Line Items]
Estimated net proved reserves, beginning of year	9,239,300	8,406,600
Acquisition of reserves	0	1,268,000
Discoveries and extensions	0	261,200
Improved recovery	0	0
Revisions	-2,935,300	-92,900
Production	-511,700	-603,600
Estimated net proved reserves, end of year	5,792,300	9,239,300
Proved developed reserves
Proved developed reserves, beginning of year	3,245,700	2,809,200
Proved developed reserves, end of year	2,898,500	3,245,700
Boe
Reserve Quantities [Line Items]
Estimated net proved reserves, beginning of year	17,238,717	17,226,317
Acquisition of reserves	0	2,740,417
Discoveries and extensions	0	763,116
Improved recovery	0	0
Revisions	-6,346,500	-2,687,733
Production	-670,050	-803,400
Estimated net proved reserves, end of year	10,222,167	17,238,717
Proved developed reserves
Proved developed reserves, beginning of year	4,392,500	4,335,783
Proved developed reserves, end of year	3,765,950	4,392,500

Supplemental_Oil_and_Gas_Discl6

Supplemental Oil and Gas Disclosures - Standard Measure of Discounted Future Net Cash Flows - Unaudited (Details) (USD $)	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Standardized Measure of Discounted Future Net Cash Flows
Future cash inflows	$704,959	$1,213,823
Future production costs	-242,110	-297,786
Future development costs	-167,409	-255,309
Future net cash flows before income taxes	295,440	660,728
Future income tax expense	-35,150	-181,935
Future net cash flows before 10% discount	260,290	478,793
10% annual discount for estimating timing of cash flows	-71,495	-178,003
Standardized measure of discounted future net cash flows	$188,795	$300,790	$292,685

Supplemental_Oil_and_Gas_Discl7

Supplemental Oil and Gas Disclosures - Changes in Standardized Measure of Discounted Future Cash Flows - Unaudited (Details) (USD $)	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2013
Changes in Standardized Measure of Discounted Future Net Cash Flows:
Beginning of year	$300,790	$292,685
Sales of oil and gas produced, net of production costs	-19,507	-37,261
Net change in prices and production costs	-66,042	33,720
Extension, discoveries, and improved recovery, less related costs	0	18,639
Development costs incurred during the year	2,938	8,230
Net change in estimated future development costs	5,194	13,418
Revisions of previous quantity estimates	-209,654	-87,642
Net change from acquisitions of minerals in place	0	37,224
Net change in income taxes	89,473	4,235
Accretion of discount	41,075	40,688
Changes in timing and other	44,528	-23,146
End of year	$188,795	$300,790

Subsequent_Events_Details_Narr

Subsequent Events (Details Narrative) (USD $)

12 Months Ended

1 Months Ended

3 Months Ended

1 Months Ended

Dec. 31, 2014

Dec. 31, 2013

Sep. 30, 2014

31-May-14

Apr. 30, 2014

Feb. 28, 2014

Aug. 31, 2013

Jul. 31, 2013

Apr. 30, 2013

Mar. 31, 2015

Mar. 16, 2015

Feb. 28, 2015

Subsequent Event [Line Items]

Stock option grants

525,000

830,000

Non-Executive Employee / Stock Options

Subsequent Event [Line Items]

Stock option grants

30,000

60,000

60,000

90,000

90,000

60,000

75,000

Stock options exercisable term

7 years

7 years

7 years

7 years

7 years

7 years

7 years

Stock options vesting period

Vest 1/3 on each of the first three grant date anniversaries.

Vest 1/3 after six months and 1/3 on each of the first two grant date anniversaries.

Vest 1/3 on each of the first three grant date anniversaries.

Vest 1/3 on each of the first three grant date anniversaries.

Vest 1/3 on each of the first three grant date anniversaries.

Vest 1/3 on each of the first three grant date anniversaries.

Vest 1/3 on each of the first three grant date anniversaries.

Subsequent Event | Conway MacKenzie Management Services, LLC

Subsequent Event [Line Items]

Advisory fee, monthly

$50,000

Advisory agreement, terms

In March 2015, pursuant to the terms of the Forbearance Agreements, the Company entered into an engagement letter (the BEngagement LetterB) with Conway MacKenzie Management Services, LLC (BCMSB). Pursuant to the Engagement Letter, the Company appointed principals of CMS to the Interim Chief Financial Officer and Strategic Alternatives Officer positions. Those officers are engaged to assist the Company in connection with its efforts to restructure or repay the First Lien Notes and Second Lien Notes. The Company will pay CMS a fee of $50,000 per month for services of the Interim Chief Financial Officer and pay hourly fees for services of other CMS personnel.

Subsequent Event | Forbearance Agreement

Subsequent Event [Line Items]

Forbearance agreement from secured debt holders

On January 30, 2015, the Company, along with its subsidiaries, Lobo Operating, Inc., Lobo Resources, Inc., Harvest Oil & Gas, LLC and The Harvest Group, LLC entered into a forbearance agreement (the BFirst Lien Forbearance AgreementB) with the holders (the BFirst Lien LendersB) of certain notes (the BFirst Lien NotesB) issued under that certain Indenture dated as of November 22, 2013 (the BFirst Lien IndentureB), by and among the Company and The Bank of New York Mellon Trust Company, N.A., as trustee (the BFirst Lien TrusteeB). Also on January 30, 2015, the Company entered into a forbearance agreement (the BSecond Lien Forbearance AgreementB) with the holders (the BSecond Lien LendersB) of seventy-five percent (75%) or more in principal amount of the notes (the BSecond Lien NotesB) issued under that certain Indenture dated as of July 12, 2011 (as supplemented or amended, the BSecond Lien IndentureB), by and among the Company and The Bank of New York Mellon Trust Company, N.A., as trustee (the BSecond Lien TrusteeB). The First Lien Forbearance Agreement and the Second Lien Forbearance Agreement were entered into following (i) the CompanyBs failure to pay to the First Lien Lenders an interest installment in the amount of $1.3 million scheduled for payment on December 31, 2014, and constituting a default if not paid by January 30, 2015 (the BAnticipated First Lien DefaultB), and (ii) the CompanyBs failure to pay to the Second Lien Lenders an interest installment in the amount of $7.9 million scheduled for payment on January 1, 2015, and constituting a default if not paid by February 2, 2015 (the BAnticipated Second Lien Default,B and, together with the Anticipated First Lien Default, the BSpecified DefaultsB). The Company has received confirmation from the First Lien Lenders that they hold more than 75% of the principal amount of the outstanding Second Lien Notes and have each agreed, during the Forbearance Period (as defined below), not to provide any direction to the Second Lien Trustee or to take any steps to enforce any rights of the Second Lien Trustee or the holders of Second Lien Notes occasioned by the failure of the Company to make the January 1, 2015 interest payment. Pursuant to the First Lien Forbearance Agreement, the First Lien Lenders have agreed to forbear, until the earlier of March 16, 2015 or the occurrence of certain defaults defined in the First Lien Forbearance Agreement (the BForbearance PeriodB), from exercising certain of their default-related rights and remedies against the Company with respect to the Specified Defaults in order to permit the Company an opportunity to effectuate a restructuring/refinancing or implement operational improvements. Under the terms of the First Lien Forbearance Agreement, among other things, the Company agreed to (i) pay, by February 2, 2015, the December 31, 2014 interest payment owing to the First Lien Lenders, with interest at the default rate, in the amount of $1,378,650; (ii) pay expenses incurred by the First Lien Lenders in connection with the Forbearance Agreement, including paying a retainer to counsel for the First Lien Lenders; (iii) retain, by March 2, 2015, a financial advisor acceptable to the First Lien Lenders on terms acceptable to the First Lien Lenders; (iv) deliver to the First Lien Lenders a 6-week operating budget in form and methodology acceptable to the First Lien Lenders and to abide by that budget within permitted variances; (v) deliver to the First Lien Lenders, not later than March 2, 2015, certain financial, operating and other information and, not later than March 15, 2015, a two year business plan and 2015 budget; and (vi) cause its officers, financial advisors, investment bankers and others to furnish information reasonably requested by the First Lien Lenders. Any breach by the Company of any covenant in the First Lien Forbearance Agreement, or the commencement of any bankruptcy, insolvency or creditor relief proceedings by or with respect to the Company, will constitute an event of default under the First Lien Forbearance Agreement. Pursuant to the Second Lien Forbearance Agreement, the Second Lien Lenders have agreed to forbear, during the Forbearance Period, from exercising certain of their default-related rights and remedies against the Company with respect to the Specified Defaults in order to permit the Company an opportunity to effectuate a restructuring/refinancing or implement operational improvements. Second Lien Forbearance Agreement is substantially identical to the First Lien Forbearance Agreement except that the January 1, 2015 interest payment on the First Lien Notes is not required to be made. On March 16, 2015, the Company entered into amendments to the First Lien Forbearance Agreement and the Second Lien Forbearance Agreement, extending the Forbearance Period to April 30, 2015.

Subsequent Event | Non-Executive Employee / Stock Options

Subsequent Event [Line Items]

Stock option grants

75,000

Stock options exercisable term

7 years

Stock options vesting period

Vest over two years