10-Q

United States

Securities and Exchange Commission

Washington, D.C. 20549

Form 10-Q

(Mark One)

þ QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15 (d) OF THE SECURITIES EXCHANGE ACT OF 1934

For the quarterly period ended March 31, 2016

¨ TRANSITION REPORT PURSUANT TO SECTION 13 OR 15 (d) OF THE SECURITIES EXCHANGE ACT OF 1934

For the transition period from to

Commission file number 000-51945

ATLAS AMERICA SERIES 26-2005 L.P.

(Name of small business issuer in its charter)

Delaware	20-2879859
(State or other jurisdiction of incorporation or organization)	(I.R.S. Employer Identification No.)
Park Place Corporate Center One
1000 Commerce Drive, 4th Floor
Pittsburgh, PA	15275
(Address of principal executive offices)	(zip code)

Issuer’s telephone number, including area code: (412)-489-0006

Indicate by check mark whether the registrant (1) has filed all reports required to be filed by Section 13 or 15 (d) of the Securities Exchange Act of 1934 during the preceding 12 months (or for such shorter period that the registrant was required to file such reports), and (2) has been subject to such filing requirements for the past 90 days.    Yes  þ    No  ¨

Indicate by check mark whether the registrant has submitted electronically and posted on its corporate Web site, if any, every Interactive Data File required to be submitted and posted pursuant to Rule 405 of Regulation S-T (§232.405 of this chapter) during the preceding 12 months (or for such shorter period that the registrant was required to submit and post such files).     Yes   þ    No  ¨

Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer, or a smaller reporting company. See the definitions of “large accelerated filer”, “accelerated filer,” “non accelerated filer” and “smaller reporting company” in Rule 12b-2 of the Exchange Act (Check one):

Large accelerated filer	¨	Accelerated filer	¨
Non-accelerated filer	¨	Smaller reporting company	þ

Indicate by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the Exchange Act).    Yes  ¨     No  þ

ATLAS AMERICA SERIES 26-2005 L.P.

(A Delaware Limited Partnership)

INDEX TO QUARTERLY REPORT

ON FORM 10-Q

		PAGE
PART I.	FINANCIAL INFORMATION (Unaudited)
Item 1:
	Condensed Balance Sheets as of March 31, 2016 and December 31, 2015	3
	Condensed Statements of Operations for the Three Months ended March 31, 2016 and 2015	4
	Condensed Statements of Comprehensive Loss for the Three Months ended March 31, 2016 and 2015	5
	Condensed Statement of Changes in Partners’ Deficit for the Three Months ended March 31, 2016	6
	Condensed Statements of Cash Flows for the Three Months ended March 31, 2016 and 2015	7
	Notes to Condensed Financial Statements	8
Item 2:	Management’s Discussion and Analysis of Financial Condition and Results of Operations	13
Item 4:	Controls and Procedures	16
PART II.	OTHER INFORMATION
Item 1:	Legal Proceedings	17
Item 6:	Exhibits	18
SIGNATURES		19
CERTIFICATIONS

2

PART I. FINANCIAL INFORMATION

ITEM I. FINANCIAL STATEMENTS

ATLAS AMERICA SERIES 26-2005 L.P.

CONDENSED BALANCE SHEETS

(Unaudited)

	March 31, 2016			December 31, 2015
ASSETS
Current assets:
Cash	$	-		$	-
Accounts receivable trade–affiliate		36,800			46,900
Current portion of derivative assets		17,800			20,800
Total current assets		54,600			67,700
Gas and oil properties, net		1,199,400			1,199,400
Long-term asset retirement receivable-affiliate		35,900			36,100
Total assets	$	1,289,900		$	1,303,200
LIABILITIES AND PARTNERS’ DEFICIT
Current liabilities:
Accounts payable trade-affiliate	$	172,600		$	138,900
Accrued liabilities		13,900			8,500
Put premiums payable-affiliate		7,100			9,600
Total current liabilities		193,600			157,000
Asset retirement obligations		3,036,500			3,011,400
Commitments and contingencies (Note 6)
Partners’ deficit:
Managing general partner’s deficit		(359,800	)		(331,600	)
Limited partners’ deficit (1,400 units)		(1,581,100	)		(1,534,600	)
Accumulated other comprehensive income		700			1,000
Total partners’ deficit		(1,940,200	)		(1,865,200	)
Total liabilities and partners’ deficit	$	1,289,900		$	1,303,200

See accompanying notes to condensed financial statements.

3

ATLAS AMERICA SERIES 26-2005 L.P.

CONDENSED STATEMENTS OF OPERATIONS

(Unaudited)

	Three Months Ended March 31,
	2016			2015
REVENUES
Natural gas and oil	$	74,000		$	153,600
Gain on mark-to-market derivatives		3,400			2,800
Total revenues		77,400			156,400
COSTS AND EXPENSES
Production		98,200			168,100
Depletion		-			24,400
Accretion of asset retirement obligations		25,300			40,700
General and administrative		28,600			36,100
Total costs and expenses		152,100			269,300
Net loss	$	(74,700	)	$	(112,900	)
Allocation of net loss:
Managing general partner	$	(28,200	)	$	(43,200	)
Limited partners	$	(46,500	)	$	(69,700	)
Net loss per limited partnership unit	$	(33	)	$	(50	)

See accompanying notes to condensed financial statements.

4

ATLAS AMERICA SERIES 26-2005 L.P.

CONDENSED STATEMENTS OF COMPREHENSIVE LOSS

(Unaudited)

	Three Months Ended March 31,
	2016			2015
Net loss	$	(74,700	)	$	(112,900	)
Other comprehensive loss:
Difference in estimated hedge receivable		-			1,500
Reclassification adjustment to net loss of mark-to-market gains on cash flow hedges		(300	)		(2,400	)
Total other comprehensive loss		(300	)		(900	)
Comprehensive loss	$	(75,000	)	$	(113,800	)

See accompanying notes to condensed financial statements.

5

ATLAS AMERICA SERIES 26-2005 L.P.

CONDENSED STATEMENT OF CHANGES IN PARTNERS’ DEFICIT

FOR THE THREE MONTHS ENDED

March 31, 2016

(Unaudited)

	Managing General Partner			Limited Partners			Accumulated Other Comprehensive Income (Loss)			Total
Balance at December 31, 2015	$	(331,600	)	$	(1,534,600	)	$	1,000		$	(1,865,200	)
Participation in revenues, costs and expenses:
Net production expenses		(8,700	)		(15,500	)		-			(24,200	)
Gain on mark-to-market derivatives		-			3,400			-			3,400
Accretion of asset retirement obligations		(9,100	)		(16,200	)		-			(25,300	)
General and administrative		(10,400	)		(18,200	)		-			(28,600	)
Net loss		(28,200	)		(46,500	)		-			(74,700	)
Other comprehensive loss		-			-			(300	)		(300	)
Balance at March 31, 2016	$	(359,800	)	$	(1,581,100	)	$	700		$	(1,940,200	)

See accompanying notes to condensed financial statements.

6

ATLAS AMERICA SERIES 26-2005 L.P.

CONDENSED STATEMENTS OF CASH FLOWS

(Unaudited)

	Three Months Ended March 31,
	2016			2015
Cash flows from operating activities:
Net loss	$	(74,700	)	$	(112,900	)
Adjustments to reconcile net loss to net cash provided by operating activities:
Depletion		-			24,400
Non cash loss (gain) on derivative value		200			(3,700	)
Accretion of asset retirement obligations		25,300			40,700
Asset retirement obligation liabilities settled		(200	)		-
Changes in operating assets and liabilities:
Decrease in accounts receivable trade-affiliate		10,100			62,600
Decrease (increase) in asset retirement receivable-affiliate		200			(12,700	)
Increase in accounts payable trade-affiliate		33,700			-
Increase in accrued liabilities		5,400			2,800
Net cash provided by operating activities		-			1,200
Cash flows from investing activities:
Net cash used in investing activities		-			-
Cash flows from financing activities:
Net cash used in financing activities		-			-
Net change in cash		-			1,200
Cash at beginning of period		-			-
Cash at end of period	$	-		$	1,200

See accompanying notes to condensed financial statements.

7

ATLAS AMERICA SERIES 26-2005 L.P.

NOTES TO CONDENSED FINANCIAL STATEMENTS

March 31, 2016

(Unaudited)

NOTE 1 – DESCRIPTION OF BUSINESS

Atlas America Series 26-2005 L.P. (the “Partnership”) is a Delaware limited partnership, formed on May 26, 2005 with Atlas Resources, LLC serving as its Managing General Partner and Operator (“Atlas Resources” or the “MGP”). Atlas Resources is an indirect subsidiary of Atlas Resource Partners, L.P. (“ARP”) (NYSE: ARP). Unless the context otherwise requires, references to “the Partnership,” “we,” “us” and “our”, refer to Atlas America Series 26-2005 L.P.

Atlas Energy Group, LLC (“Atlas Energy Group”; OTCQX: ATLS) manages ARP’s operations and activities through its ownership of ARP’s general partner interest.

The Partnership has drilled and currently operates wells located in Pennsylvania and Tennessee. The Partnership has no employees and relies on the MGP for management, which in turn, relies on its parent company, Atlas Energy Group, for administrative services.

The Partnership’s operating cash flows are generated from its wells, which produce natural gas and oil. Produced natural gas and oil is then delivered to market through affiliated and/or third-party gas gathering systems. The Partnership intends to produce its wells until they are depleted or become uneconomical to produce, at which time they will be plugged and abandoned or sold. The Partnership does not expect to drill additional wells and expects no additional funds will be required for drilling.

The economic viability of the Partnership’s production is based on a variety of factors including proved developed reserves that it can expect to recover through existing wells with existing equipment and operating methods or in which the cost of additional required extraction equipment is relatively minor compared to the cost of a new well; and through currently installed extraction equipment and related infrastructure which is operational at the time of the reserves estimate (if the extraction is by means not involving drilling, completing or reworking a well). There are numerous uncertainties inherent in estimating quantities of proven reserves and in projecting future net revenues.

The prices at which the Partnership’s natural gas and oil will be sold are uncertain and the Partnership is not guaranteed a specific price for the sale of its production. Changes in natural gas and oil prices have a significant impact on the Partnership’s cash flow and the value of its reserves. Lower natural gas and oil prices may not only decrease the Partnership’s revenues, but also may reduce the amount of natural gas and oil that the Partnership can produce economically.

Liquidity and Capital Resources

The Partnership is generally limited to the amount of funds generated by the cash flow from its operations to fund its obligations and make distributions, if any, to its partners.

The natural gas, oil and natural gas liquids commodity price markets have suffered significant declines throughout 2015 and have continued to decline and remain low in 2016. The extreme ongoing volatility in the energy industry and commodity prices will likely continue to impact the Partnership’s outlook. The Partnership has experienced downward revisions of its natural gas and oil reserves volumes and values due to the significant declines in commodity prices. The MGP continues to implement various cost saving measures to reduce the Partnership’s operating and general and administrative costs, including renegotiating contracts with contractors, suppliers and service providers, reducing the number of staff and contractors and deferring and eliminating discretionary costs. The MGP will continue to be opportunistic and aggressive in managing the Partnership’s cost structure and, in turn, liquidity to meet its operating needs. To the extent commodity prices remain low or decline further, or the Partnership experiences other disruptions in the industry, the Partnership’s ability to fund its operations and make distributions may be further impacted, and could result in the MGP’s decision to liquidate the Partnership’s operations.

8

Historically, there has been no need to borrow funds from the MGP to fund operations as the cash flow from the Partnership’s operations have been adequate to fund its obligations and distributions to its partners. However, the recent significant declines in commodity prices have challenged the Partnership’s ability to fund its operations and may make it uneconomical for the Partnership to produce its wells until they are depleted as the Partnership originally intended. Accordingly, the MGP determined that there is substantial doubt about the Partnership’s ability to continue as a going concern. The MGP intends, as necessary, to continue the Partnership’s operations and to fund the Partnership’s obligations for at least the next twelve months. The MGP has concluded that such undertaking is sufficient to alleviate the doubt as to the Partnership’s ability to continue as a going concern. To the extent commodity prices remain low or decline further, ARP experiences disruptions in the financial markets impacting its respective longer-term access to or cost of capital, or ARP experiences any of the other impacts to its liquidity discussed below, the MGP’s ability to continue the Partnership’s operations and to fund the Partnership’s obligations for at least the next twelve months, as necessary, may be impacted.

ARP’s revolving credit facility is currently in the process of its semi-annual redetermination. Based on projected market conditions, continued declines in commodity prices and recent conversations with its administrative agent, ARP expects that its borrowing base will be redetermined to a level below its outstanding borrowings as of March 31, 2016.  If ARP’s borrowing base is redetermined below its current outstanding borrowings and ARP is unable to repay the deficiency or deposit additional collateral to eliminate such deficiency, or if ARP experiences any other event of default on its debt obligations, or if other debt agreements cross-default, and the lenders accelerate the maturity of any other outstanding debts, the MGP, may not have sufficient liquidity to continue the Partnership’s operations and to fund the Partnership’s obligations, and as a result, there would be substantial doubt regarding the Partnership’s ability to continue as a going concern.

If, however, the MGP were to decide to liquidate our operations, the liquidation valuation of the Partnership’s assets and liabilities would be determined by an independent expert. It is possible that based on such determination, we would not be able to make any liquidation distributions to our limited partners. A liquidation could result in the transfer of the post-liquidation assets and liabilities of the Partnership to the MGP and would occur without any further contributions from or distributions to the limited partners.

The condensed financial statements, which are unaudited, except for the balance sheet at December 31, 2015, which is derived from audited financial statements, have been prepared pursuant to the rules and regulations of the Securities and Exchange Commission and accounting principles generally accepted in the United States of America (“U.S. GAAP”) for interim reporting. Certain information and note disclosures normally included in annual financial statements prepared in accordance with U.S. GAAP have been condensed or omitted pursuant to those rules and regulations, although we believe that the disclosures made are adequate to make the information not misleading.  These interim financial statements should be read in conjunction with the audited financial statements and notes thereto presented in the Partnership’s Annual Report on Form 10-K for the year ended December 31, 2015. The results of operations for the three months ended March 31, 2016 may not necessarily be indicative of the results of operations for the year ended December 31, 2016.

NOTE 2 – SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES

Use of Estimates

The preparation of the Partnership’s financial statements in conformity with U.S. GAAP requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities and the disclosure of contingent assets and liabilities that exist at the date of the Partnership’s financial statements, as well as the reported amounts of revenues and costs and expenses during the reporting periods. The Partnership’s financial statements are based on a number of significant estimates, including the revenue and expense accruals, depletion, impairments, fair value of derivative instruments and the probability of forecasted transactions. Actual results could differ from those estimates.

The natural gas industry principally conducts its business by processing actual transactions many as 60 days after the month of delivery. Consequently, the most recent two months’ financial results were recorded using estimated volumes and contract market prices. Differences between estimated and actual amounts are recorded in the following months’ financial results. Management believes that the operating results presented for the three months ended March 31, 2016 and 2015 represent actual results in all material respects.

9

Gas and Oil Properties

The following is a summary of gas and oil properties at the dates indicated:

	March 31, 2016			December 31, 2015
Proved properties:
Leasehold interests	$	1,102,500		$	1,102,500
Wells and related equipment		44,267,700			44,267,700
Total natural gas and oil properties		45,370,200			45,370,200
Accumulated depletion and impairment		(44,170,800	)		(44,170,800	)
Gas and oil properties, net	$	1,199,400		$	1,199,400

As a result of the recent significant declines in commodity prices and associated recorded impairment charges, remaining net book value of gas and oil properties on our balance sheet at March 31, 2016 and December 31, 2015 was primarily related to the estimated salvage value of such properties.  The estimated salvage values were based on the MGP’s historical experience in determining such values.

Recently Issued Accounting Standards

In August 2014, the FASB updated the accounting guidance related to the evaluation of whether there is substantial doubt about an entity’s ability to continue as a going concern. The updated accounting guidance requires an entity’s management to evaluate whether there are conditions or events that raise substantial doubt about its ability to continue as a going concern within one year from the date the financial statements are issued and provide footnote disclosures, if necessary. The updated guidance is effective as of January 1, 2017 and the Partnership is currently in the process of determining the impact of providing the enhanced disclosures, as applicable, within its financial statements.

In May 2014, the FASB updated the accounting guidance related to revenue recognition. The updated accounting guidance provides a single, contract-based revenue recognition model to help improve financial reporting by providing clearer guidance on when an entity should recognize revenue, and by reducing the number of standards to which an entity has to refer. In July 2015, the FASB voted to defer the effective date by one year to December 15, 2017 for annual reporting periods beginning after that date. The updated accounting guidance provides companies with alternative methods of adoption. The Partnership is currently in the process of determining the impact that the updated accounting guidance will have on its financial statements and its method of adoption.

NOTE 3 – DERIVATIVE INSTRUMENTS

The MGP, on behalf of the Partnership, uses a number of different derivative instruments, principally put contracts, in connection with the partnership’s commodity price risk management activities. The Partnership does not apply hedge accounting to any of its derivative instruments. As a result, gains and losses associated with derivative instruments are recognized in earnings.

The Partnership enters into commodity put contracts to achieve more predictable cash flows by hedging the Partnership’s exposure to changes in commodity prices. At any point in time, such contracts may include regulated NYMEX futures and options contracts and non-regulated over-the-counter futures contracts with qualified counterparties. NYMEX contracts are generally settled with offsetting positions, but may be settled by the physical delivery of the commodity. These contracts have been recorded at their fair values.

The Partnership reflected net derivative assets on its balance sheets of $17,800 and $20,800 at March 31, 2016 and December 31, 2015, respectively.

10

The following table summarizes the gains or losses recognized within the statements of operations for derivative instruments previously designated as cash flow hedges for the periods indicated:

	Three Months Ended
	March 31,
	2016		2015
Gains reclassified from accumulated other comprehensive income into natural gas and oil revenues	$	300	$	2,400
Gains subsequent to hedge accounting recognized in gain on mark-to-market derivatives	$	3,400	$	2,800

At March 31, 2016, the Partnership had the following commodity derivatives:

Natural Gas Put Options

Production Period Ending December 31,	Volumes		AverageFixed Price		Fair Value Asset (2)
	(MMBtu) (1)		(per MMBtu) (1)
2016		9,300		4.15	$	17,800

(1) “MMBtu” represents million British Thermal Units.

(2) Fair value based on forward NYMEX natural gas prices, as applicable.

As the underlying prices and terms in the Partnership’s derivative contracts were consistent with the indices used to sell its natural gas and oil, there were no gains or losses recognized during the three months ended March 31, 2016 and 2015 for hedge ineffectiveness.

NOTE 4 – FAIR VALUE OF FINANCIAL INSTRUMENTS

The Partnership uses a market approach fair value methodology to value the assets and liabilities for its outstanding derivative contracts. The fair value of a financial instrument depends on a number of factors, including the availability of observable market data over the contractual term of the underlying instrument. The Partnership separates the fair value of its financial instruments into three levels (Levels 1, 2 and 3) based on its assessment of the availability of observable market data and the significance of non-observable data used to determine fair value.  As of March 31, 2016 and December 31, 2015, all derivative financial instruments were classified as Level 2.

11

Information for assets measured at fair value at March 31, 2016 and December 31, 2015was as follows:

	Level 1		Level 2		Level 3		Total
As of March 31, 2016
Derivative assets, gross
Commodity puts	$	-	$	17,800	$	-	$	17,800

	Level 1		Level 2		Level 3		Total
As of December 31, 2015
Derivative assets, gross
Commodity puts	$	-	$	20,800	$	-	$	20,800

NOTE 5 – CERTAIN RELATIONSHIPS AND RELATED PARTY TRANSACTIONS

The Partnership has entered into the following significant transactions with the MGP and its affiliates as provided under its Partnership Agreement. Administrative costs, which are included in general and administrative expenses in the Partnership’s statements of operations, are payable at $75 per well per month. Monthly well supervision fees, which are included in production expense in the Partnership’s statements of operations, are payable at $318 per well per month for operating and maintaining the wells. Well supervision fees are proportionately reduced to the extent the Partnership does not acquire 100% of the working interest in a well. Transportation fees are included in production expenses in the Partnership’s statements of operations and are generally payable at 13% of the natural gas sales price. Direct costs, which are included in production and general administrative expenses in the Partnership’s statements of operations, are payable to the MGP and its affiliates as reimbursement for all costs expended on the Partnership’s behalf.

The following table provides information with respect to these costs and the periods incurred:

	Three Months EndedMarch 31,
	2016		2015
Administrative fees	$	14,700	$	22,500
Supervision fees		61,100		94,300
Transportation fees		9,900		19,200
Direct costs		41,100		68,200
Total	$	126,800	$	204,200

The MGP and its affiliates perform all administrative and management functions for the Partnership, including billing revenues and paying expenses. Accounts payable trade-affiliate on the Partnership’s balance sheets includes the net production expenses to the MGP.

NOTE 6 – COMMITMENTS AND CONTINGENCIES

General Commitments

Subject to certain conditions, investor partners may present their interests for purchase by the MGP. The purchase price is calculated by the MGP in accordance with the terms of the partnership agreement. The MGP is not obligated to purchase more than 5% of the total outstanding units in any calendar year. In the event that the MGP is unable to obtain the necessary funds, it may suspend its purchase obligation.

12

Beginning one year after each of the Partnership’s wells has been placed into production, the MGP, as operator, may retain $200 per month per well to cover estimated future plugging and abandonment costs. As of March 31, 2016, the MGP has withheld $35,900 of net production revenue for future plugging and abandonment costs.

Legal Proceedings

The Partnership is a party to various routine legal proceedings arising out of the ordinary course of its business. Management believes that none of these actions, individually or in the aggregate, will have a material adverse effect on the Partnership’s financial condition or results of operations.

Affiliates of the MGP and their subsidiaries are party to various routine legal proceedings arising in the ordinary course of their respective businesses. The MGP’s management believes that none of these actions, individually or in the aggregate, will have a material adverse effect on the MGP’s financial condition or results of operations.

ITEM  2. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS (UNAUDITED)

Forward-Looking Statements

When used in this Form 10-Q, the words “believes”, “anticipates,” “expects” and similar expressions are intended to identify forward-looking statements. Such statements are subject to certain risks and uncertainties, which could cause actual results to differ materially from the results stated or implied in this document. Readers are cautioned not to place undue reliance on these forward-looking statements, which speak only as of the date hereof. We undertake no obligation to publicly release the results of any revisions to forward-looking statements which we may make to reflect events or circumstances after the date of this Form 10-Q or to reflect the occurrence of unanticipated events.

General

Atlas America Series 26-2005 L.P. (“we”, “us”, or the “Partnership”) is a Delaware limited partnership, formed on May 26, 2005 with Atlas Resources, LLC serving as its Managing General Partner and Operator (“Atlas Resources” or the “MGP”). Atlas Resources is an indirect subsidiary of Atlas Resource Partners, L.P. (“ARP”) (NYSE: ARP). Unless the context otherwise requires, references to “the Partnership,” “we,” “us” and “our”, refer to Atlas America Series 26-2005 L.P.

Atlas Energy Group, LLC manages ARP’s operations and activities through its ownership of the ARP’s general partner interest.

We have drilled and currently operate wells located in Pennsylvania and Tennessee. We have no employees and rely on our MGP for management, which in turn, relies on its parent company, Atlas Energy Group, for administrative services.

We intend to continue to produce our wells until they are depleted or become uneconomical to produce, at which time they will be plugged and abandoned or sold. We expect that no other wells will be drilled and no additional funds will be required for drilling.

Overview

The following discussion provides information to assist in understanding our financial condition and results of operations. Our operating cash flows are generated from our wells, which produce primarily natural gas, but also some oil. Our produced natural gas and oil is then delivered to market through affiliated and/or third-party gas gathering systems. Our ongoing operating and maintenance costs have been and are expected to be fulfilled through revenues from the sale of our natural gas and oil production. We pay our MGP, as operator, a monthly well supervision fee, which covers all normal and regularly recurring operating expenses for the production and sale of natural gas and oil such as:

· well tending, routine maintenance and adjustment;

· reading meters, recording production, pumping, maintaining appropriate books and records; and

· preparation of reports for us and government agencies.

The well supervision fees, however, do not include costs and expenses related to the purchase of certain equipment, materials and brine disposal. If these expenses are incurred, we pay cost for third-party services, materials and a competitive charge for services performed directly by our MGP or its affiliates. Also, beginning one year after each of our wells have been placed into production, our MGP, as operator, may retain $200 per month, per well, to cover the estimated future plugging and abandonment costs of the well. As of March 31, 2016, our MGP has withheld $35,900 of net production revenues for this purpose.

13

Markets and Competition

The availability of a ready market for natural gas and oil produced by us, and the price obtained, depends on numerous factors beyond our control, including the extent of domestic production, imports of foreign natural gas and oil, political instability or terrorist acts in gas and oil producing countries and regions, market demand, competition from other energy sources, the effect of federal regulation on the sale of natural gas and oil in interstate commerce, other governmental regulation of the production and transportation of natural gas and oil and the proximity, availability and capacity of pipelines and other required facilities. Our MGP is responsible for selling our production. During 2016 and 2015, we experienced no problems in selling our natural gas and oil. Product availability and price are the principal means of competing in selling natural gas and oil production. While it is impossible to accurately determine our comparative position in the industry, we do not consider our operations to be a significant factor in the industry.

Results of Operations

The following table sets forth information relating to our production revenues, volumes, sales prices, production costs and depletion during the periods indicated:

	Three Months Ended March 31,
	2016			2015
Production revenues (in thousands):
Gas	$	63		$	143
Oil		11			11
Total	$	74		$	154
Production volumes:
Gas (mcf/day) (1)		440			629
Oil (bbl/day) (1)		4			3
Total (mcfe/day) (1)		464			647
Average sales prices (2)
Gas (per mcf) (1)	$	1.58		$	2.53
Oil (per bbl) (1)	$	27.73		$	41.13
Production costs:
As a percent of revenues		133	%		109	%
Per mcfe (1)	$	2.32		$	2.89
Depletion per mcfe	$	-		$	0.43

(1) “Mcf” represents thousand cubic feet, “mcfe” represents thousand cubic feet equivalent, and “bbl” represents barrels. Bbl is converted to mcfe using the ratio of six mcfs to one bbl.

(2) Average sales prices represent accrual basis pricing after adjusting for the effect of previously recognized gains resulting from prior period impairment charges.

Natural Gas Revenues. Our natural gas revenues were $63,300 and $142,900 for the three months ended March 31, 2016 and 2015, respectively, a decrease of $79,600 (56%). The $79,600 decrease in natural gas revenues for the three months ended March 31, 2016 as compared to the prior year similar period was attributable to a $41,900 decrease in production volumes and a $37,700 decrease in our natural gas sales prices after the effect of financial hedges. Our production volumes decreased to 440 mcf per day for the three months ended March 31, 2016 from 629 mcf per day for the three months ended March 31, 2015, a decrease of 189 mcf per day (30%). The decrease in production volumes is mostly due to the normal decline inherent in the life of the wells in addition to wells shut-in due to it being uneconomical to continue production in the current pricing environment.

Oil Revenues. We drilled wells primarily to produce natural gas, rather than oil, but some wells have limited oil production. Our oil revenues were $10,700 for the three months ended March 31, 2016 and 2015. This was attributable to a $5,100 decrease in oil prices, partially offset by a $5,100 increase in production volumes. Our production volumes increased to 4 bbls per day for the three months ended March 31, 2016 from 3 bbls per day for the three months ended March 31, 2015, an increase of 1 bbls per day (33%).

14

Gain on Mark-to-Market Derivatives. On January 1, 2015, we discontinued hedge accounting for our qualified commodity derivatives. As such, subsequent changes in fair value of these derivatives are recognized immediately within gain on mark-to-market derivatives on our statements of operations. The fair values of these commodity derivative instruments as of December 31, 2014, which were recognized in accumulated other comprehensive income within partners’ capital on our balance sheet, will be reclassified to our statements of operations in the future at the time the originally hedged physical transactions settle.

We recognized a gain on mark-to-market derivatives of $3,400 and $2,800 for the three months ended March 31, 2016 and 2015, respectively. These gains were due to mark-to-market gains primarily related to the change in natural gas prices during the periods.

Costs and Expenses. Production expenses were $98,200 and $168,100 for the three months ended March 31, 2016 and 2015, respectively, a decrease of $69,900 (42%). This decrease was mostly attributable to a decrease in monthly well supervision fees, and a decrease in transportation costs.

For the three months ended March 31, 2016, there was no depletion recorded due to the recent significant declines in commodity prices and associated recorded impairment charges. Therefore, the remaining net book value of gas and oil properties on our balance sheet at December 31, 2015 was primarily related to the estimated salvage value of such properties. For the three months ended March 31, 2015, depletion of gas and oil properties as a percentage of gas and oil revenues was 16%.

General and administrative expenses for the three months ended March 31, 2016 and 2015 were $28,600 and $36,100, respectively, a decrease of $7,500 (21%). These expenses include third-party costs for services as well as the monthly administrative fees charged by our MGP and vary from period to period due to the costs charged to us and services provided to us.

Liquidity and Capital Resources

We are generally limited to the amount of funds generated by the cash flows from our operations, which we believe is adequate to fund future operations and distributions to our partners.

The natural gas, oil and natural gas liquids commodity price markets have suffered significant declines throughout 2015 and have continued to decline and remain low in 2016. The extreme ongoing volatility in the energy industry and commodity prices will likely continue to impact our outlook. We have experienced downward revisions of our natural gas and oil reserves volumes and values due to the significant declines in commodity prices. Our MGP continues to implement various cost saving measures to reduce our operating and general and administrative costs, including renegotiating contracts with contractors, suppliers and service providers, reducing the number of staff and contractors and deferring and eliminating discretionary costs. Our MGP will continue to be opportunistic and aggressive in managing our cost structure and, in turn, liquidity to meet our operating needs. To the extent commodity prices remain low or decline further, or we experience other disruptions in the industry, our ability to fund our operations and make distributions may be further impacted, and could result in the MGP’s decision to liquidate our operations.

Historically, there has been no need to borrow funds from the MGP to fund operations as the cash flow from our operations have been adequate to fund our obligations and distributions to our partners. However, the recent significant declines in commodity prices have challenged our ability to fund our operations and may make it uneconomical to produce our wells until they are depleted as we originally intended. Accordingly, the MGP determined that there is substantial doubt about our ability to continue as a going concern. The MGP intends, as necessary, to continue our operations and to fund our obligations for at least the next twelve months. The MGP has concluded that such undertaking is sufficient to alleviate the doubt as to our ability to continue as a going concern. To the extent commodity prices remain low or decline further, ARP experiences disruptions in the financial markets impacting its respective longer-term access to or cost of capital, or ARP experiences any of the other impacts to its liquidity discussed below, the MGP’s ability to continue the Partnership’s operations and to fund the Partnership’s obligations for at least the next twelve months, as necessary, may be impacted.

15

ARP’s revolving credit facility is currently in the process of its semi-annual redetermination. Based on projected market conditions, continued declines in commodity prices and recent conversations with its administrative agent, ARP expects that its borrowing base will be redetermined to a level below its outstanding borrowings as of March 31, 2016.  If ARP’s borrowing base is redetermined below its current outstanding borrowings and ARP is unable to repay the deficiency or deposit additional collateral to eliminate such deficiency, or if ARP experiences any other event of default on its debt obligations, or if other debt agreements cross-default, and the lenders accelerate the maturity of any other outstanding debts, the MGP, may not have sufficient liquidity to continue the Partnership’s operations and to fund the Partnership’s obligations, and as a result, there would be substantial doubt regarding the Partnership’s ability to continue as a going concern.

If, however, the MGP were to decide to liquidate our operations, the liquidation valuation of the Partnership’s assets and liabilities would be determined by an independent expert. It is possible that based on such determination, we would not be able to make any liquidation distributions to our limited partners. A liquidation could result in the transfer of the post-liquidation assets and liabilities of the Partnership to the MGP and would occur without any further contributions from or distributions to the limited partners.

Cash provided by operating activities decreased $1,200 in the three months ended March 31, 2016 to zero as compared to $1,200 for the three months ended March 31, 2015. This decrease was mostly due to a decrease in the change in accounts receivable trade-affiliate of $52,500 and a decrease in asset retirement obligation liabilities settled of $200. The decrease was partially offset by an increase in the change in accounts payable trade-affiliate of $33,700, an increase in the change in accrued liabilities of $2,600, an increase in net earnings before depletion, accretion, impairment, and non-cash loss (gain) on derivative value of $2,300, and an increase in the change in asset retirement receivable-affiliate of $12,900, for the three months ended March 31, 2016 compared to the three months ended March 31, 2015, respectively.

There was no cash used in financing activities for the three months ended March 31, 2016 and 2015.

Our MGP may withhold funds for future plugging and abandonment costs. Through March 31, 2016, our MGP has withheld $35,900 of funds for this purpose. Any additional funds, if required, will be obtained from production revenues or borrowings from our MGP or its affiliates, which are not contractually committed to make loans to us. The amount that we may borrow at any one time may not at any time exceed 5% of our total subscriptions, and we will not borrow from third-parties.

Critical Accounting Policies

For a more complete discussion of the accounting policies and estimates that we have identified as critical in the preparation of our condensed consolidated financial statements, please refer to our Management’s Discussion and Analysis of Financial Condition and Results of Operations in our Annual Report on Form 10-K for the fiscal year ended December 31, 2015.

ITEM  4. CONTROLS AND PROCEDURES

Evaluation of Disclosure Controls and Procedures

We maintain disclosure controls and procedures that are designed to ensure that information required to be disclosed in our Securities Exchange Act of 1934 reports is recorded, processed, summarized and reported within the time periods specified in the SEC’s rules and forms, and that such information is accumulated and communicated to our management, including our general partner’s Chief Executive Officer and Chief Financial Officer, as appropriate, to allow timely decisions regarding required disclosure. In designing and evaluating the disclosure controls and procedures, our management recognized that any controls and procedures, no matter how well designed and operated, can provide only reasonable assurance of achieving the desired control objectives, and our management necessarily was required to apply its judgment in evaluating the cost-benefit relationship of possible controls and procedures.

Under the supervision of our general partner’s Chief Executive Officer and Chief Financial Officer and with the participation of our disclosure committee appointed by such officers, we have carried out an evaluation of the effectiveness of our disclosure controls and procedures as of the end of the period covered by this report.  Based upon that evaluation, our general partner’s Chief Executive Officer and Chief Financial Officer concluded that, as of March 31, 2016, our disclosure controls and procedures were effective at the reasonable assurance level.

Changes in Internal Control over Financial Reporting

There have been no changes in the Partnership’s internal control over financial reporting during our most recent fiscal quarter that have materially affected, or are reasonably likely to materially affect, our internal control over financial reporting.

16

PART II OTHER INFORMATION

ITEM  1. LEGAL PROCEEDINGS

The Partnership is a party to various routine legal proceedings arising out of the ordinary course of its business. Management believes that none of these actions, individually or in the aggregate, will have a material adverse effect on the Partnership’s financial condition or results of operations.

Affiliates of the MGP and their subsidiaries are party to various routine legal proceedings arising in the ordinary course of their respective businesses. The MGP’s management believes that none of these actions, individually or in the aggregate, will have a material adverse effect on the MGP’s financial condition or results of operations.

17

ITEM 6. EXHIBITS

EXHIBIT INDEX

Exhibit No.	Description
4.2	Amended and Restated Certificate and Agreement of Limited Partnership for Atlas America Series 26-2005 L.P. (1)
31.1	Certification Pursuant to Rule 13a-14/15(d)-14
31.2	Certification Pursuant to Rule 13a-14/15(d)-14
32.1	Section 1350 Certification
32.2	Section 1350 Certification
101	Interactive Data File

(1) Filed on April 28, 2006 in the Form S-1 Registration Statement dated April 28, 2006, File No. 000-51945

18

SIGNATURES

Pursuant to the requirements of the Securities of the Exchange Act of 1934, the registrant has duly caused this report to be signed on its behalf by the undersigned, thereunto duly authorized.

	ATLAS AMERICA SERIES 26-2005 L.P.
	By:	Atlas Resources, LLC its
		Managing General Partner
Date: May 23, 2016	By:	/s/ FREDDIE M. KOTEK
		Freddie M. Kotek, Chief Executive Officer and President of the Managing General Partner

Date: May 23, 2016	By:	/s/JEFFREY M. SLOTTERBACK
		Jeffrey M. Slotterback Chief Financial Officer of the Managing General Partner

19

EX-31.1

Exhibit 31.1

CERTIFICATION

I, Freddie M. Kotek, certify that:

1. I have reviewed this quarterly report on Form 10-Q for the quarter ended March 31, 2016 of Atlas America Series 26-2005 L.P.;

2. Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3. Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4. The registrant’s other certifying officer(s) and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have;

(a) designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant is made known to us by others within the entity, particularly during the period in which this report is being prepared;

(b) designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

(c) evaluated the effectiveness of the registrant’s disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

(d) disclosed in this report any change in the registrant’s internal control over financial reporting that occurred during the registrant’s most recent fiscal quarter (the registrant’s fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant’s internal control over financial reporting; and

5. The registrant’s other certifying officer and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant’s auditors and the audit committee of the registrant’s board of directors (or persons performing the equivalent functions):

(a) all significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant’s ability to record, process, summarize and report financial information; and

(b) any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant’s internal control over financial reporting.

By:	/s/ FREDDIE M. KOTEK
Name:	Freddie M. Kotek
Title:	Chief Executive Officer and President of the Managing General Partner
Date:	May 23, 2016

EX-31.2

Exhibit 31.2

CERTIFICATION

I, Jeffrey M. Slotterback, certify that:

1. I have reviewed this quarterly report on Form 10-Q for the quarter ended March 31, 2016 of Atlas America Series 26-2005 L.P.;

2. Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3. Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4. The registrant’s other certifying officer(s) and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have;

(a) designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant is made known to us by others within the entity, particularly during the period in which this report is being prepared;

(b) designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

(c) evaluated the effectiveness of the registrant’s disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

(d) disclosed in this report any change in the registrant’s internal control over financial reporting that occurred during the registrant’s most recent fiscal quarter (the registrant’s fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant’s internal control over financial reporting; and

5. The registrant’s other certifying officer and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant’s auditors and the audit committee of the registrant’s board of directors (or persons performing the equivalent functions):

(a) all significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant’s ability to record, process, summarize and report financial information; and

(b) any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant’s internal control over financial reporting.

By:	/s/JEFFREY M. SLOTTERBACK
Name:	Jeffrey M. Slotterback
Title:	Chief Financial Officer of the  Managing General Partner
Date:	May 23 2016

EX-32.1

Exhibit 32.1

CERTIFICATION PURSUANT TO

18 U.S.C. SECTION 1350,

AS ADOPTED PURSUANT TO

SECTION 906 OF THE SARBANES-OXLEY ACT OF 2002

In connection with the Quarterly Report of Atlas America Series 26-2005 L.P. (the “Partnership”) on Form 10-Q for the period ended March 31, 2016 as filed with the Securities and Exchange Commission on the date hereof (the “Report”), I, Freddie M. Kotek, Chief Executive Officer of the Managing General Partner, certify, pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, that:

(1) the Report fully complies with the requirements of section 13(a) or 15(d) of the Securities Exchange Act of 1934, and

(2) the information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of the Partnership.

By:	/s/ FREDDIE M. KOTEK
Name:	Freddie M. Kotek
Title:	Chief Executive Officer and President of the Managing General Partner
Date:	May 23, 2016

EX-32.2

Exhibit 32.2

CERTIFICATION PURSUANT TO

18 U.S.C. SECTION 1350,

AS ADOPTED PURSUANT TO

SECTION 906 OF THE SARBANES-OXLEY ACT OF 2002

In connection with the Quarterly Report of Atlas America Series 26-2005 L.P. (the “Partnership”) on Form 10-Q for the period ended March 31, 2016 as filed with the Securities and Exchange Commission on the date hereof (the “Report”), I, Jeffrey M. Slotterback, Chief Financial Officer of the Managing General Partner, certify, pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, that:

(1) the Report fully complies with the requirements of section 13(a) or 15(d) of the Securities Exchange Act of 1934, and

(2) the information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of the Partnership.

By:	/s/JEFFREY M. SLOTTERBACK
Name:	Jeffrey M. Slotterback
Title:	Chief Financial Officer of the Managing General Partner
Date:	May 23, 2016

XML

Document and Entity Information	3 Months Ended
	Mar. 31, 2016 shares
Document And Entity Information [Abstract]
Document Type	10-Q
Amendment Flag	false
Document Period End Date	Mar. 31, 2016
Document Fiscal Year Focus	2016
Document Fiscal Period Focus	Q1
Entity Registrant Name	ATLAS AMERICA SERIES 26-2005 L.P.
Entity Central Index Key	0001342514
Current Fiscal Year End Date	--12-31
Entity Filer Category	Smaller Reporting Company
Entity Common Stock, Shares Outstanding	0

XML

CONDENSED BALANCE SHEETS (Unaudited) - USD ($)	Mar. 31, 2016	Dec. 31, 2015
Current assets:
Cash	$ 0	$ 0
Accounts receivable trade–affiliate	36,800	46,900
Current portion of derivative assets	17,800	20,800
Total current assets	54,600	67,700
Gas and oil properties, net	1,199,400	1,199,400
Long-term asset retirement receivable-affiliate	35,900	36,100
Total assets	1,289,900	1,303,200
Current liabilities:
Accounts payable trade-affiliate	172,600	138,900
Accrued liabilities	13,900	8,500
Put premiums payable-affiliate	7,100	9,600
Total current liabilities	193,600	157,000
Asset retirement obligations	$ 3,036,500	$ 3,011,400
Commitments and contingencies (Note 6)
Partners’ deficit:
Managing general partner’s deficit	$ (359,800)	$ (331,600)
Limited partners’ deficit (1,400 units)	(1,581,100)	(1,534,600)
Accumulated other comprehensive income	700	1,000
Total partners’ deficit	(1,940,200)	(1,865,200)
Total liabilities and partners’ deficit	$ 1,289,900	$ 1,303,200

XML

CONDENSED BALANCE SHEETS (Unaudited) (Parenthetical)	Mar. 31, 2016 shares
Statement Of Financial Position [Abstract]
Limited partners' units	1,400

XML

CONDENSED STATEMENTS OF OPERATIONS (Unaudited) - USD ($)	3 Months Ended
	Mar. 31, 2016	Mar. 31, 2015
REVENUES
Natural gas and oil	$ 74,000	$ 153,600
Gain on mark-to-market derivatives	3,400	2,800
Total revenues	77,400	156,400
COSTS AND EXPENSES
Production	98,200	168,100
Depletion	0	24,400
Accretion of asset retirement obligations	25,300	40,700
General and administrative	28,600	36,100
Total costs and expenses	152,100	269,300
Net loss	(74,700)	(112,900)
Allocation of net loss:
Managing general partner	(28,200)	(43,200)
Limited partners	$ (46,500)	$ (69,700)
Net loss per limited partnership unit	$ (33)	$ (50)

XML

CONDENSED STATEMENTS OF COMPREHENSIVE LOSS (Unaudited) - USD ($)	3 Months Ended
	Mar. 31, 2016	Mar. 31, 2015
Statement Of Income And Comprehensive Income [Abstract]
Net loss	$ (74,700)	$ (112,900)
Other comprehensive loss:
Difference in estimated hedge receivable		1,500
Reclassification adjustment to net loss of mark-to-market gains on cash flow hedges	(300)	(2,400)
Total other comprehensive loss	(300)	(900)
Comprehensive loss	$ (75,000)	$ (113,800)

XML

CONDENSED STATEMENT OF CHANGES IN PARTNERS' DEFICIT (Unaudited) - 3 months ended Mar. 31, 2016 - USD ($)	Total	Accumulated Other Comprehensive (Loss) Income	Managing General Partner	Limited Partners
Beginning balance at Dec. 31, 2015	$ (1,865,200)	$ 1,000	$ (331,600)	$ (1,534,600)
Participation in revenues, costs and expenses:
Net production expenses	(24,200)		(8,700)	(15,500)
Gain on mark-to-market derivatives	3,400			3,400
Accretion of asset retirement obligations	(25,300)		(9,100)	(16,200)
General and administrative	(28,600)		(10,400)	(18,200)
Net loss	(74,700)		(28,200)	(46,500)
Other comprehensive loss	(300)	(300)
Ending balance at Mar. 31, 2016	$ (1,940,200)	$ 700	$ (359,800)	$ (1,581,100)

XML

CONDENSED STATEMENTS OF CASH FLOWS (Unaudited) - USD ($)	3 Months Ended
	Mar. 31, 2016	Mar. 31, 2015
Cash flows from operating activities:
Net loss	$ (74,700)	$ (112,900)
Adjustments to reconcile net loss to net cash provided by operating activities:
Depletion	0	24,400
Non cash loss (gain) on derivative value	200	(3,700)
Accretion of asset retirement obligations	25,300	40,700
Asset retirement obligation liabilities settled	(200)	0
Changes in operating assets and liabilities:
Decrease in accounts receivable trade-affiliate	10,100	62,600
Decrease (increase) in asset retirement receivable-affiliate	200	(12,700)
Increase in accounts payable trade-affiliate	33,700	0
Increase in accrued liabilities	5,400	2,800
Net cash provided by operating activities	0	1,200
Cash flows from investing activities:
Net cash used in investing activities	0	0
Cash flows from financing activities:
Net cash used in financing activities	0	0
Net change in cash	0	1,200
Cash at beginning of period	0	0
Cash at end of period	$ 0	$ 1,200

XML

Description of Business

3 Months Ended

Mar. 31, 2016

Organization Consolidation And Presentation Of Financial Statements [Abstract]

DESCRIPTION OF BUSINESS

NOTE 1 – DESCRIPTION OF BUSINESS

Atlas America Series 26-2005 L.P. (the “Partnership”) is a Delaware limited partnership, formed on May 26, 2005 with Atlas Resources, LLC serving as its Managing General Partner and Operator (“Atlas Resources” or the “MGP”). Atlas Resources is an indirect subsidiary of Atlas Resource Partners, L.P. (“ARP”) (NYSE: ARP). Unless the context otherwise requires, references to “the Partnership,” “we,” “us” and “our”, refer to Atlas America Series 26-2005 L.P.

Atlas Energy Group, LLC (“Atlas Energy Group”; OTCQX: ATLS) manages ARP’s operations and activities through its ownership of ARP’s general partner interest.

The Partnership has drilled and currently operates wells located in Pennsylvania and Tennessee. The Partnership has no employees and relies on the MGP for management, which in turn, relies on its parent company, Atlas Energy Group, for administrative services.

The Partnership’s operating cash flows are generated from its wells, which produce natural gas and oil. Produced natural gas and oil is then delivered to market through affiliated and/or third-party gas gathering systems. The Partnership intends to produce its wells until they are depleted or become uneconomical to produce, at which time they will be plugged and abandoned or sold. The Partnership does not expect to drill additional wells and expects no additional funds will be required for drilling.

The economic viability of the Partnership’s production is based on a variety of factors including proved developed reserves that it can expect to recover through existing wells with existing equipment and operating methods or in which the cost of additional required extraction equipment is relatively minor compared to the cost of a new well; and through currently installed extraction equipment and related infrastructure which is operational at the time of the reserves estimate (if the extraction is by means not involving drilling, completing or reworking a well). There are numerous uncertainties inherent in estimating quantities of proven reserves and in projecting future net revenues.

The prices at which the Partnership’s natural gas and oil will be sold are uncertain and the Partnership is not guaranteed a specific price for the sale of its production. Changes in natural gas and oil prices have a significant impact on the Partnership’s cash flow and the value of its reserves. Lower natural gas and oil prices may not only decrease the Partnership’s revenues, but also may reduce the amount of natural gas and oil that the Partnership can produce economically.

Liquidity and Capital Resources

The Partnership is generally limited to the amount of funds generated by the cash flow from its operations to fund its obligations and make distributions, if any, to its partners.

The natural gas, oil and natural gas liquids commodity price markets have suffered significant declines throughout 2015 and have continued to decline and remain low in 2016. The extreme ongoing volatility in the energy industry and commodity prices will likely continue to impact the Partnership’s outlook. The Partnership has experienced downward revisions of its natural gas and oil reserves volumes and values due to the significant declines in commodity prices. The MGP continues to implement various cost saving measures to reduce the Partnership’s operating and general and administrative costs, including renegotiating contracts with contractors, suppliers and service providers, reducing the number of staff and contractors and deferring and eliminating discretionary costs. The MGP will continue to be opportunistic and aggressive in managing the Partnership’s cost structure and, in turn, liquidity to meet its operating needs. To the extent commodity prices remain low or decline further, or the Partnership experiences other disruptions in the industry, the Partnership’s ability to fund its operations and make distributions may be further impacted, and could result in the MGP’s decision to liquidate the Partnership’s operations.

Historically, there has been no need to borrow funds from the MGP to fund operations as the cash flow from the Partnership’s operations have been adequate to fund its obligations and distributions to its partners. However, the recent significant declines in commodity prices have challenged the Partnership’s ability to fund its operations and may make it uneconomical for the Partnership to produce its wells until they are depleted as the Partnership originally intended. Accordingly, the MGP determined that there is substantial doubt about the Partnership’s ability to continue as a going concern. The MGP intends, as necessary, to continue the Partnership’s operations and to fund the Partnership’s obligations for at least the next twelve months. The MGP has concluded that such undertaking is sufficient to alleviate the doubt as to the Partnership’s ability to continue as a going concern. To the extent commodity prices remain low or decline further, ARP experiences disruptions in the financial markets impacting its respective longer-term access to or cost of capital, or ARP experiences any of the other impacts to its liquidity discussed below, the MGP’s ability to continue the Partnership’s operations and to fund the Partnership’s obligations for at least the next twelve months, as necessary, may be impacted.

ARP’s revolving credit facility is currently in the process of its semi-annual redetermination. Based on projected market conditions, continued declines in commodity prices and recent conversations with its administrative agent, ARP expects that its borrowing base will be redetermined to a level below its outstanding borrowings as of March 31, 2016.  If ARP’s borrowing base is redetermined below its current outstanding borrowings and ARP is unable to repay the deficiency or deposit additional collateral to eliminate such deficiency, or if ARP experiences any other event of default on its debt obligations, or if other debt agreements cross-default, and the lenders accelerate the maturity of any other outstanding debts, the MGP, may not have sufficient liquidity to continue the Partnership’s operations and to fund the Partnership’s obligations, and as a result, there would be substantial doubt regarding the Partnership’s ability to continue as a going concern.

If, however, the MGP were to decide to liquidate our operations, the liquidation valuation of the Partnership’s assets and liabilities would be determined by an independent expert. It is possible that based on such determination, we would not be able to make any liquidation distributions to our limited partners. A liquidation could result in the transfer of the post-liquidation assets and liabilities of the Partnership to the MGP and would occur without any further contributions from or distributions to the limited partners.

The condensed financial statements, which are unaudited, except for the balance sheet at December 31, 2015, which is derived from audited financial statements, have been prepared pursuant to the rules and regulations of the Securities and Exchange Commission and accounting principles generally accepted in the United States of America (“U.S. GAAP”) for interim reporting. Certain information and note disclosures normally included in annual financial statements prepared in accordance with U.S. GAAP have been condensed or omitted pursuant to those rules and regulations, although we believe that the disclosures made are adequate to make the information not misleading.  These interim financial statements should be read in conjunction with the audited financial statements and notes thereto presented in the Partnership’s Annual Report on Form 10-K for the year ended December 31, 2015. The results of operations for the three months ended March 31, 2016 may not necessarily be indicative of the results of operations for the year ended December 31, 2016.

XML

Summary of Significant Accounting Policies

3 Months Ended

Mar. 31, 2016

Accounting Policies [Abstract]

SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES

NOTE 2 – SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES

Use of Estimates

The preparation of the Partnership’s financial statements in conformity with U.S. GAAP requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities and the disclosure of contingent assets and liabilities that exist at the date of the Partnership’s financial statements, as well as the reported amounts of revenues and costs and expenses during the reporting periods. The Partnership’s financial statements are based on a number of significant estimates, including the revenue and expense accruals, depletion, impairments, fair value of derivative instruments and the probability of forecasted transactions. Actual results could differ from those estimates.

The natural gas industry principally conducts its business by processing actual transactions many as 60 days after the month of delivery. Consequently, the most recent two months’ financial results were recorded using estimated volumes and contract market prices. Differences between estimated and actual amounts are recorded in the following months’ financial results. Management believes that the operating results presented for the three months ended March 31, 2016 and 2015 represent actual results in all material respects.

Gas and Oil Properties

The following is a summary of gas and oil properties at the dates indicated:

	March 31, 2016			December 31, 2015
Proved properties:
Leasehold interests	$	1,102,500		$	1,102,500
Wells and related equipment		44,267,700			44,267,700
Total natural gas and oil properties		45,370,200			45,370,200
Accumulated depletion and impairment		(44,170,800	)		(44,170,800	)
Gas and oil properties, net	$	1,199,400		$	1,199,400

As a result of the recent significant declines in commodity prices and associated recorded impairment charges, remaining net book value of gas and oil properties on our balance sheet at March 31, 2016 and December 31, 2015 was primarily related to the estimated salvage value of such properties.  The estimated salvage values were based on the MGP’s historical experience in determining such values.

Recently Issued Accounting Standards

In August 2014, the FASB updated the accounting guidance related to the evaluation of whether there is substantial doubt about an entity’s ability to continue as a going concern. The updated accounting guidance requires an entity’s management to evaluate whether there are conditions or events that raise substantial doubt about its ability to continue as a going concern within one year from the date the financial statements are issued and provide footnote disclosures, if necessary. The updated guidance is effective as of January 1, 2017 and the Partnership is currently in the process of determining the impact of providing the enhanced disclosures, as applicable, within its financial statements.

In May 2014, the FASB updated the accounting guidance related to revenue recognition. The updated accounting guidance provides a single, contract-based revenue recognition model to help improve financial reporting by providing clearer guidance on when an entity should recognize revenue, and by reducing the number of standards to which an entity has to refer. In July 2015, the FASB voted to defer the effective date by one year to December 15, 2017 for annual reporting periods beginning after that date. The updated accounting guidance provides companies with alternative methods of adoption. The Partnership is currently in the process of determining the impact that the updated accounting guidance will have on its financial statements and its method of adoption.

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Derivative Instruments

3 Months Ended

Mar. 31, 2016

Derivative Instruments And Hedging Activities Disclosure [Abstract]

DERIVATIVE INSTRUMENTS

NOTE 3 – DERIVATIVE INSTRUMENTS

The MGP, on behalf of the Partnership, uses a number of different derivative instruments, principally put contracts, in connection with the partnership’s commodity price risk management activities. The Partnership does not apply hedge accounting to any of its derivative instruments. As a result, gains and losses associated with derivative instruments are recognized in earnings.

The Partnership enters into commodity put contracts to achieve more predictable cash flows by hedging the Partnership’s exposure to changes in commodity prices. At any point in time, such contracts may include regulated NYMEX futures and options contracts and non-regulated over-the-counter futures contracts with qualified counterparties. NYMEX contracts are generally settled with offsetting positions, but may be settled by the physical delivery of the commodity. These contracts have been recorded at their fair values.

The Partnership reflected net derivative assets on its balance sheets of $17,800 and $20,800 at March 31, 2016 and December 31, 2015, respectively.

The following table summarizes the gains or losses recognized within the statements of operations for derivative instruments previously designated as cash flow hedges for the periods indicated:

	Three Months Ended
	March 31,
	2016		2015
Gains reclassified from accumulated other comprehensive income into natural gas and oil revenues	$	300	$	2,400
Gains subsequent to hedge accounting recognized in gain on mark-to-market derivatives	$	3,400	$	2,800

At March 31, 2016, the Partnership had the following commodity derivatives:

Natural Gas Put Options

Production Period Ending December 31,	Volumes		AverageFixed Price		Fair Value Asset (2)
	(MMBtu) (1)		(per MMBtu) (1)
2016		9,300		4.15	$	17,800

(1) “MMBtu” represents million British Thermal Units.

(2) Fair value based on forward NYMEX natural gas prices, as applicable.

As the underlying prices and terms in the Partnership’s derivative contracts were consistent with the indices used to sell its natural gas and oil, there were no gains or losses recognized during the three months ended March 31, 2016 and 2015 for hedge ineffectiveness.

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Fair Value of Financial Instruments

3 Months Ended

Mar. 31, 2016

Fair Value Disclosures [Abstract]

FAIR VALUE OF FINANCIAL INSTRUMENTS

NOTE 4 – FAIR VALUE OF FINANCIAL INSTRUMENTS

The Partnership uses a market approach fair value methodology to value the assets and liabilities for its outstanding derivative contracts. The fair value of a financial instrument depends on a number of factors, including the availability of observable market data over the contractual term of the underlying instrument. The Partnership separates the fair value of its financial instruments into three levels (Levels 1, 2 and 3) based on its assessment of the availability of observable market data and the significance of non-observable data used to determine fair value.  As of March 31, 2016 and December 31, 2015, all derivative financial instruments were classified as Level 2.

Information for assets measured at fair value at March 31, 2016 and December 31, 2015 was as follows:

	Level 1		Level 2		Level 3		Total
As of March 31, 2016
Derivative assets, gross
Commodity puts	$	-	$	17,800	$	-	$	17,800

	Level 1		Level 2		Level 3		Total
As of December 31, 2015
Derivative assets, gross
Commodity puts	$	-	$	20,800	$	-	$	20,800

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Certain Relationships and Related Party Transactions

3 Months Ended

Mar. 31, 2016

Related Party Transactions [Abstract]

CERTAIN RELATIONSHIPS AND RELATED PARTY TRANSACTIONS

NOTE 5 – CERTAIN RELATIONSHIPS AND RELATED PARTY TRANSACTIONS

The Partnership has entered into the following significant transactions with the MGP and its affiliates as provided under its Partnership Agreement. Administrative costs, which are included in general and administrative expenses in the Partnership’s statements of operations, are payable at $75 per well per month. Monthly well supervision fees, which are included in production expense in the Partnership’s statements of operations, are payable at $318 per well per month for operating and maintaining the wells. Well supervision fees are proportionately reduced to the extent the Partnership does not acquire 100% of the working interest in a well. Transportation fees are included in production expenses in the Partnership’s statements of operations and are generally payable at 13% of the natural gas sales price. Direct costs, which are included in production and general administrative expenses in the Partnership’s statements of operations, are payable to the MGP and its affiliates as reimbursement for all costs expended on the Partnership’s behalf.

The following table provides information with respect to these costs and the periods incurred:

	Three Months EndedMarch 31,
	2016		2015
Administrative fees	$	14,700	$	22,500
Supervision fees		61,100		94,300
Transportation fees		9,900		19,200
Direct costs		41,100		68,200
Total	$	126,800	$	204,200

The MGP and its affiliates perform all administrative and management functions for the Partnership, including billing revenues and paying expenses. Accounts payable trade-affiliate on the Partnership’s balance sheets includes the net production expenses to the MGP.

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Commitments and Contingencies

3 Months Ended

Mar. 31, 2016

Commitments And Contingencies Disclosure [Abstract]

COMMITMENTS AND CONTINGENCIES

NOTE 6 – COMMITMENTS AND CONTINGENCIES

General Commitments

Subject to certain conditions, investor partners may present their interests for purchase by the MGP. The purchase price is calculated by the MGP in accordance with the terms of the partnership agreement. The MGP is not obligated to purchase more than 5% of the total outstanding units in any calendar year. In the event that the MGP is unable to obtain the necessary funds, it may suspend its purchase obligation.

Beginning one year after each of the Partnership’s wells has been placed into production, the MGP, as operator, may retain $200 per month per well to cover estimated future plugging and abandonment costs. As of March 31, 2016, the MGP has withheld $35,900 of net production revenue for future plugging and abandonment costs.

Legal Proceedings

The Partnership is a party to various routine legal proceedings arising out of the ordinary course of its business. Management believes that none of these actions, individually or in the aggregate, will have a material adverse effect on the Partnership’s financial condition or results of operations.

Affiliates of the MGP and their subsidiaries are party to various routine legal proceedings arising in the ordinary course of their respective businesses. The MGP’s management believes that none of these actions, individually or in the aggregate, will have a material adverse effect on the MGP’s financial condition or results of operations.

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Summary of Significant Accounting Policies (Policies)

3 Months Ended

Mar. 31, 2016

Accounting Policies [Abstract]

Liquidity and Capital Resources

Liquidity and Capital Resources

The Partnership is generally limited to the amount of funds generated by the cash flow from its operations to fund its obligations and make distributions, if any, to its partners.

The natural gas, oil and natural gas liquids commodity price markets have suffered significant declines throughout 2015 and have continued to decline and remain low in 2016. The extreme ongoing volatility in the energy industry and commodity prices will likely continue to impact the Partnership’s outlook. The Partnership has experienced downward revisions of its natural gas and oil reserves volumes and values due to the significant declines in commodity prices. The MGP continues to implement various cost saving measures to reduce the Partnership’s operating and general and administrative costs, including renegotiating contracts with contractors, suppliers and service providers, reducing the number of staff and contractors and deferring and eliminating discretionary costs. The MGP will continue to be opportunistic and aggressive in managing the Partnership’s cost structure and, in turn, liquidity to meet its operating needs. To the extent commodity prices remain low or decline further, or the Partnership experiences other disruptions in the industry, the Partnership’s ability to fund its operations and make distributions may be further impacted, and could result in the MGP’s decision to liquidate the Partnership’s operations.

Historically, there has been no need to borrow funds from the MGP to fund operations as the cash flow from the Partnership’s operations have been adequate to fund its obligations and distributions to its partners. However, the recent significant declines in commodity prices have challenged the Partnership’s ability to fund its operations and may make it uneconomical for the Partnership to produce its wells until they are depleted as the Partnership originally intended. Accordingly, the MGP determined that there is substantial doubt about the Partnership’s ability to continue as a going concern. The MGP intends, as necessary, to continue the Partnership’s operations and to fund the Partnership’s obligations for at least the next twelve months. The MGP has concluded that such undertaking is sufficient to alleviate the doubt as to the Partnership’s ability to continue as a going concern. To the extent commodity prices remain low or decline further, ARP experiences disruptions in the financial markets impacting its respective longer-term access to or cost of capital, or ARP experiences any of the other impacts to its liquidity discussed below, the MGP’s ability to continue the Partnership’s operations and to fund the Partnership’s obligations for at least the next twelve months, as necessary, may be impacted.

ARP’s revolving credit facility is currently in the process of its semi-annual redetermination. Based on projected market conditions, continued declines in commodity prices and recent conversations with its administrative agent, ARP expects that its borrowing base will be redetermined to a level below its outstanding borrowings as of March 31, 2016.  If ARP’s borrowing base is redetermined below its current outstanding borrowings and ARP is unable to repay the deficiency or deposit additional collateral to eliminate such deficiency, or if ARP experiences any other event of default on its debt obligations, or if other debt agreements cross-default, and the lenders accelerate the maturity of any other outstanding debts, the MGP, may not have sufficient liquidity to continue the Partnership’s operations and to fund the Partnership’s obligations, and as a result, there would be substantial doubt regarding the Partnership’s ability to continue as a going concern.

If, however, the MGP were to decide to liquidate our operations, the liquidation valuation of the Partnership’s assets and liabilities would be determined by an independent expert. It is possible that based on such determination, we would not be able to make any liquidation distributions to our limited partners. A liquidation could result in the transfer of the post-liquidation assets and liabilities of the Partnership to the MGP and would occur without any further contributions from or distributions to the limited partners.

The condensed financial statements, which are unaudited, except for the balance sheet at December 31, 2015, which is derived from audited financial statements, have been prepared pursuant to the rules and regulations of the Securities and Exchange Commission and accounting principles generally accepted in the United States of America (“U.S. GAAP”) for interim reporting. Certain information and note disclosures normally included in annual financial statements prepared in accordance with U.S. GAAP have been condensed or omitted pursuant to those rules and regulations, although we believe that the disclosures made are adequate to make the information not misleading.  These interim financial statements should be read in conjunction with the audited financial statements and notes thereto presented in the Partnership’s Annual Report on Form 10-K for the year ended December 31, 2015. The results of operations for the three months ended March 31, 2016 may not necessarily be indicative of the results of operations for the year ended December 31, 2016.

Use of Estimates

Use of Estimates

The preparation of the Partnership’s financial statements in conformity with U.S. GAAP requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities and the disclosure of contingent assets and liabilities that exist at the date of the Partnership’s financial statements, as well as the reported amounts of revenues and costs and expenses during the reporting periods. The Partnership’s financial statements are based on a number of significant estimates, including the revenue and expense accruals, depletion, impairments, fair value of derivative instruments and the probability of forecasted transactions. Actual results could differ from those estimates.

The natural gas industry principally conducts its business by processing actual transactions many as 60 days after the month of delivery. Consequently, the most recent two months’ financial results were recorded using estimated volumes and contract market prices. Differences between estimated and actual amounts are recorded in the following months’ financial results. Management believes that the operating results presented for the three months ended March 31, 2016 and 2015 represent actual results in all material respects.

Gas and Oil Properties

Gas and Oil Properties

The following is a summary of gas and oil properties at the dates indicated:

	March 31, 2016			December 31, 2015
Proved properties:
Leasehold interests	$	1,102,500		$	1,102,500
Wells and related equipment		44,267,700			44,267,700
Total natural gas and oil properties		45,370,200			45,370,200
Accumulated depletion and impairment		(44,170,800	)		(44,170,800	)
Gas and oil properties, net	$	1,199,400		$	1,199,400

As a result of the recent significant declines in commodity prices and associated recorded impairment charges, remaining net book value of gas and oil properties on our balance sheet at March 31, 2016 and December 31, 2015 was primarily related to the estimated salvage value of such properties.  The estimated salvage values were based on the MGP’s historical experience in determining such values.

Recently Issued Accounting Standards

Recently Issued Accounting Standards

In August 2014, the FASB updated the accounting guidance related to the evaluation of whether there is substantial doubt about an entity’s ability to continue as a going concern. The updated accounting guidance requires an entity’s management to evaluate whether there are conditions or events that raise substantial doubt about its ability to continue as a going concern within one year from the date the financial statements are issued and provide footnote disclosures, if necessary. The updated guidance is effective as of January 1, 2017 and the Partnership is currently in the process of determining the impact of providing the enhanced disclosures, as applicable, within its financial statements.

In May 2014, the FASB updated the accounting guidance related to revenue recognition. The updated accounting guidance provides a single, contract-based revenue recognition model to help improve financial reporting by providing clearer guidance on when an entity should recognize revenue, and by reducing the number of standards to which an entity has to refer. In July 2015, the FASB voted to defer the effective date by one year to December 15, 2017 for annual reporting periods beginning after that date. The updated accounting guidance provides companies with alternative methods of adoption. The Partnership is currently in the process of determining the impact that the updated accounting guidance will have on its financial statements and its method of adoption.

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Summary of Significant Accounting Policies (Tables)

3 Months Ended

Mar. 31, 2016

Accounting Policies [Abstract]

Summary of Gas and Oil Properties

The following is a summary of gas and oil properties at the dates indicated:

	March 31, 2016			December 31, 2015
Proved properties:
Leasehold interests	$	1,102,500		$	1,102,500
Wells and related equipment		44,267,700			44,267,700
Total natural gas and oil properties		45,370,200			45,370,200
Accumulated depletion and impairment		(44,170,800	)		(44,170,800	)
Gas and oil properties, net	$	1,199,400		$	1,199,400

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Derivative Instruments (Tables)

3 Months Ended

Mar. 31, 2016

Derivative Instruments And Hedging Activities Disclosure [Abstract]

Summary of Gains or Losses Recognized Within Statements of Operations for Derivative Instruments Previously Designated as Cash Flow Hedges

The following table summarizes the gains or losses recognized within the statements of operations for derivative instruments previously designated as cash flow hedges for the periods indicated:

	Three Months Ended
	March 31,
	2016		2015
Gains reclassified from accumulated other comprehensive income into natural gas and oil revenues	$	300	$	2,400
Gains subsequent to hedge accounting recognized in gain on mark-to-market derivatives	$	3,400	$	2,800

Commodity Derivatives

At March 31, 2016, the Partnership had the following commodity derivatives:

Natural Gas Put Options

Production Period Ending December 31,	Volumes		AverageFixed Price		Fair Value Asset (2)
	(MMBtu) (1)		(per MMBtu) (1)
2016		9,300		4.15	$	17,800

(1) “MMBtu” represents million British Thermal Units.

(2) Fair value based on forward NYMEX natural gas prices, as applicable.

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Fair Value of Financial Instruments (Tables)

3 Months Ended

Mar. 31, 2016

Fair Value Disclosures [Abstract]

Assets Measured at Fair Value on a Recurring Basis

Information for assets measured at fair value at March 31, 2016 and December 31, 2015 was as follows:

	Level 1		Level 2		Level 3		Total
As of March 31, 2016
Derivative assets, gross
Commodity puts	$	-	$	17,800	$	-	$	17,800

	Level 1		Level 2		Level 3		Total
As of December 31, 2015
Derivative assets, gross
Commodity puts	$	-	$	20,800	$	-	$	20,800

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Certain Relationships and Related Party Transactions (Tables)

3 Months Ended

Mar. 31, 2016

Related Party Transactions [Abstract]

Certain Relationships and Related Party Transactions

The following table provides information with respect to these costs and the periods incurred:

	Three Months EndedMarch 31,
	2016		2015
Administrative fees	$	14,700	$	22,500
Supervision fees		61,100		94,300
Transportation fees		9,900		19,200
Direct costs		41,100		68,200
Total	$	126,800	$	204,200

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Description of Business (Details)	3 Months Ended
	Mar. 31, 2016
Organization Consolidation And Presentation Of Financial Statements [Abstract]
Atlas America Series 26-2005 L.P. Formation Date	May 26, 2005

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Summary of Significant Accounting Policies (Summary of Gas and Oil Properties) (Details) - USD ($)	Mar. 31, 2016	Dec. 31, 2015
Property Plant And Equipment [Line Items]
Total natural gas and oil properties	$ 45,370,200	$ 45,370,200
Accumulated depletion and impairment	(44,170,800)	(44,170,800)
Gas and oil properties, net	1,199,400	1,199,400
Leasehold interests
Property Plant And Equipment [Line Items]
Total natural gas and oil properties	1,102,500	1,102,500
Wells and related equipment
Property Plant And Equipment [Line Items]
Total natural gas and oil properties	$ 44,267,700	$ 44,267,700

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Derivative Instruments (Narrative) (Details) - USD ($)	3 Months Ended
	Mar. 31, 2016	Mar. 31, 2015	Dec. 31, 2015
Derivative Instruments And Hedging Activities Disclosure [Abstract]
Net derivative assets	$ 17,800		$ 20,800
Gains (Losses) on Fair Value Hedge Ineffectiveness, Net	$ 0	$ 0

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Derivative Instruments (Summary of Gains or Losses Recognized Within Statements of Operations for Derivative Instruments Previously Designated as Cash Flow Hedges) (Details) - USD ($)	3 Months Ended
	Mar. 31, 2016	Mar. 31, 2015
Derivative Instruments And Hedging Activities Disclosure [Abstract]
Gains reclassified from accumulated other comprehensive income into natural gas and oil revenues	$ 300	$ 2,400
Gains subsequent to hedge accounting recognized in gain on mark-to-market derivatives	$ 3,400	$ 2,800

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Derivative Instruments (Commodity Derivatives) (Details)		3 Months Ended
		Mar. 31, 2016 USD ($) MMBTU $ / MMBTU	Dec. 31, 2015 USD ($)
Derivative [Line Items]
Fair Value Asset		$ 17,800	$ 20,800
Designated as Hedging Instrument | Natural Gas Put Options Production Period Ending December 31, 2016
Derivative [Line Items]
Volumes (MMBtu) | MMBTU	[1]	9,300
Average Fixed Price (per MMBtu) | $ / MMBTU	[1]	4.15
Fair Value Asset	[2]	$ 17,800

[1] “MMBtu” represents million British Thermal Units.

[2] Fair value based on forward NYMEX natural gas prices, as applicable.

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Fair Value of Financial Instruments (Assets Measured at Fair Value on a Recurring Basis) (Details) - USD ($)	Mar. 31, 2016	Dec. 31, 2015
Fair Value Assets And Liabilities Measured On Recurring And Nonrecurring Basis [Line Items]
Fair Value Asset	$ 17,800	$ 20,800
Commodity Puts
Fair Value Assets And Liabilities Measured On Recurring And Nonrecurring Basis [Line Items]
Fair Value Asset	17,800	20,800
Fair Value, Inputs, Level 2 | Commodity Puts
Fair Value Assets And Liabilities Measured On Recurring And Nonrecurring Basis [Line Items]
Fair Value Asset	$ 17,800	$ 20,800

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Certain Relationships and Related Party Transactions (Narrative) (Details) - MGP and Affiliates	3 Months Ended
	Mar. 31, 2016 $ / mo
Administrative costs
Related Party Transaction [Line Items]
Monthly Administrative Costs Per Well	75
Supervision fees
Related Party Transaction [Line Items]
Monthly Supervision Fees Per Well	318
Transportation fees
Related Party Transaction [Line Items]
Transportation Fees Rate As Percentage Of Natural Gas Sales Price	13.00%

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Certain Relationships and Related Party Transactions (Certain Relationships and Related Party Transactions) (Details) - MGP and Affiliates - USD ($)	3 Months Ended
	Mar. 31, 2016	Mar. 31, 2015
Related Party Transaction [Line Items]
Related Party Transaction, Expenses from Transactions with Related Party	$ 126,800	$ 204,200
Administrative fees
Related Party Transaction [Line Items]
Related Party Transaction, Expenses from Transactions with Related Party	14,700	22,500
Supervision fees
Related Party Transaction [Line Items]
Related Party Transaction, Expenses from Transactions with Related Party	61,100	94,300
Transportation fees
Related Party Transaction [Line Items]
Related Party Transaction, Expenses from Transactions with Related Party	9,900	19,200
Direct costs
Related Party Transaction [Line Items]
Related Party Transaction, Expenses from Transactions with Related Party	$ 41,100	$ 68,200

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Commitments and Contingencies (Narrative) (Details)	3 Months Ended
	Mar. 31, 2016 USD ($) $ / mo
Commitments And Contingencies Disclosure [Abstract]
Investor Partners Ownership Interest Presented For Purchase By The MGP, Maximum Percentage	5.00%
Operator Fee Per Well To Cover Estimated Future Plugging And Abandonment Costs, Monthly | $ / mo	200
Net production revenue for future plugging and abandonment costs | $	$ 35,900