Atlas America Series 25-2004 10-Q 23 May 16 2016 Q1 Quarterly report Financial data

Document and Entity Information

Document and Entity Information	3 Months Ended
	Mar. 31, 2016shares
Document And Entity Information [Abstract]
Document Type	10-Q
Amendment Flag	false
Document Period End Date	Mar. 31, 2016
Document Fiscal Year Focus	2,016
Document Fiscal Period Focus	Q1
Entity Registrant Name	ATLAS AMERICA SERIES 25-2004 (A) L.P.
Entity Central Index Key	1,283,810
Current Fiscal Year End Date	--12-31
Entity Filer Category	Smaller Reporting Company
Entity Common Stock, Shares Outstanding	0

CONDENSED BALANCE SHEETS (Unaud

CONDENSED BALANCE SHEETS (Unaudited) - USD ($)	Mar. 31, 2016	Dec. 31, 2015
Current assets:
Cash	$ 0	$ 0
Accounts receivable trade–affiliate	40,800	36,100
Current portion of derivative assets	15,200	18,300
Total current assets	56,000	54,400
Gas and oil properties, net	1,047,900	1,047,900
Long-term asset retirement receivable-affiliate	348,300	266,100
Total assets	1,452,200	1,368,400
Current liabilities:
Accounts payable trade-affiliate	592,900	451,500
Accrued liabilities	15,100	9,700
Put premiums payable-affiliate	6,000	8,500
Total current liabilities	614,000	469,700
Asset retirement obligations	$ 3,334,000	$ 3,307,400
Commitments and contingencies (Note 6)
Partners’ deficit:
Managing general partner’s deficit	$ (654,900)	$ (623,500)
Limited partners’ deficit (1,106.76 units)	(1,841,600)	(1,786,100)
Accumulated other comprehensive income	700	900
Total partners’ deficit	(2,495,800)	(2,408,700)
Total liabilities and partners’ deficit	$ 1,452,200	$ 1,368,400

CONDENSED BALANCE SHEETS (Unau3

CONDENSED BALANCE SHEETS (Unaudited) (Parenthetical)	Mar. 31, 2016shares
Statement Of Financial Position [Abstract]
Limited partners' units	1,106.76

CONDENSED STATEMENTS OF OPERATI

CONDENSED STATEMENTS OF OPERATIONS (Unaudited) - USD ($)	3 Months Ended
	Mar. 31, 2016	Mar. 31, 2015
REVENUES
Natural gas, oil and liquids	$ 70,000	$ 121,800
Gain on mark-to-market derivatives	2,800	2,600
Total revenues	72,800	124,400
COSTS AND EXPENSES
Production	102,600	138,800
Depletion	0	18,200
Accretion of asset retirement obligations	26,600	44,700
General and administrative	30,500	35,200
Total costs and expenses	159,700	236,900
Net loss	(86,900)	(112,500)
Allocation of net loss:
Managing general partner	(31,400)	(42,600)
Limited partners	$ (55,500)	$ (69,900)
Net loss per limited partnership unit	$ (50)	$ (63)

CONDENSED STATEMENTS OF COMPREH

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	$ (86,900)	$ (112,500)
Other comprehensive loss:
Difference in estimated hedge receivable	0	1,300
Reclassification adjustment to net loss of mark-to-market gains on cash flow hedges	(200)	(2,200)
Total other comprehensive loss	(200)	(900)
Comprehensive loss	$ (87,100)	$ (113,400)

CONDENSED STATEMENT OF CHANGES

CONDENSED STATEMENT OF CHANGES IN PARTNERS' DEFICIT (Unaudited) - 3 months ended Mar. 31, 2016 - USD ($)	Total	Managing General Partner	Limited Partners	Accumulated Other Comprehensive Income (Loss)
Beginning balance at Dec. 31, 2015	$ (2,408,700)	$ (623,500)	$ (1,786,100)	$ 900
Participation in revenues, costs and expenses:
Net production expenses	(32,600)	(11,400)	(21,200)
Gain on mark-to-market derivatives	2,800		2,800
Accretion of asset retirement obligations	(26,600)	(9,300)	(17,300)
General and administrative	(30,500)	(10,700)	(19,800)
Net loss	(86,900)	(31,400)	(55,500)
Other comprehensive loss	(200)			(200)
Ending balance at Mar. 31, 2016	$ (2,495,800)	$ (654,900)	$ (1,841,600)	$ 700

CONDENSED STATEMENTS OF CASH FL

CONDENSED STATEMENTS OF CASH FLOWS (Unaudited) - USD ($)	3 Months Ended
	Mar. 31, 2016	Mar. 31, 2015
Cash flows from operating activities:
Net loss	$ (86,900)	$ (112,500)
Adjustments to reconcile net loss to net cash used in operating activities:
Depletion	0	18,200
Non cash loss (gain) on derivative value	400	(3,400)
Accretion of asset retirement obligations	26,600	44,700
Changes in operating assets and liabilities:
(Increase) decrease in accounts receivable trade-affiliate	(4,700)	49,600
Increase in asset retirement receivable-affiliate	(82,200)	(1,100)
Increase in accounts payable trade-affiliate	141,400	0
Increase in accrued liabilities	5,400	2,600
Net cash used in operating activities	0	(1,900)
Cash flows from investing activities:
Net cash used in investing activities	0	0
Cash flows from financing activities:
Distributions to partners	0	(1,900)
Net cash used in financing activities	0	(1,900)
Net change in cash	0	(3,800)
Cash at beginning of period	0	3,800
Cash at end of period	$ 0	$ 0

Description of Business

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 25-2004 (A) L.P. (the “Partnership”) is a Delaware limited partnership, formed on January 21, 2004 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 25-2004 (A) 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, oil and NGL. Produced natural gas, oil and NGL 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, oil and NGL will be sold are uncertain and the Partnership is not guaranteed a specific price for the sale of its production. Changes in natural gas, oil and NGL prices have a significant impact on the Partnership’s cash flow and the value of its reserves. Lower natural gas, oil and NGL prices may not only decrease the Partnership’s revenues, but also may reduce the amount of natural gas, oil and NGL 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.

Summary of Significant Accounti

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, December 31, 2016 2015 Proved properties: Leasehold interests $ 716,500 $ 716,500 Wells and related equipment 35,903,400 35,903,400 Total natural gas and oil properties 36,619,900 36,619,900 Accumulated depletion and impairment (35,572,000 ) (35,572,000 ) Gas and oil properties, net $ 1,047,900 $ 1,047,900 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.

Derivative Instruments

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 $15,200 and $18,300 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, oil and liquids revenues $ 200 $ 2,200 Gains subsequent to hedge accounting recognized in gain on mark-to-market derivatives $ 2,800 $ 2,600 At March 31, 2016, the Partnership had the following commodity derivatives: Natural Gas Put Options Production Volumes Average Fixed Price Fair Value (2) (MMBtu) (1) (per MMBtu) (1) 2016 7,900 $ 4.15 $ 15,200 (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.

Fair Value of Financial Instrum

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 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 $ - $ 15,200 $ - $ 15,200 Level 1 Level 2 Level 3 Total As of December 31, 2015 Derivative assets, gross Commodity puts $ - $ 18,300 $ - $ 18,300

Certain Relationships and Relat

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 $313 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 Ended 2016 2015 Administrative fees $ 16,600 $ 21,200 Supervision fees 68,100 87,500 Transportation fees 6,800 13,800 Direct costs 41,600 51,500 Total $ 133,100 $ 174,000 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 due to the MGP.

Commitments and Contingencies

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 $348,300 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.

Summary of Significant Accoun14

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, December 31, 2016 2015 Proved properties: Leasehold interests $ 716,500 $ 716,500 Wells and related equipment 35,903,400 35,903,400 Total natural gas and oil properties 36,619,900 36,619,900 Accumulated depletion and impairment (35,572,000 ) (35,572,000 ) Gas and oil properties, net $ 1,047,900 $ 1,047,900 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.

Summary of Significant Accoun15

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, December 31, 2016 2015 Proved properties: Leasehold interests $ 716,500 $ 716,500 Wells and related equipment 35,903,400 35,903,400 Total natural gas and oil properties 36,619,900 36,619,900 Accumulated depletion and impairment (35,572,000 ) (35,572,000 ) Gas and oil properties, net $ 1,047,900 $ 1,047,900

Derivative Instruments (Tables)

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, oil and liquids revenues $ 200 $ 2,200 Gains subsequent to hedge accounting recognized in gain on mark-to-market derivatives $ 2,800 $ 2,600
Commodity Derivatives	At March 31, 2016, the Partnership had the following commodity derivatives: Natural Gas Put Options Production Volumes Average Fixed Price Fair Value (2) (MMBtu) (1) (per MMBtu) (1) 2016 7,900 $ 4.15 $ 15,200 (1) “MMBtu” represents million British Thermal Units. (2) Fair value based on forward NYMEX natural gas prices, as applicable.

Fair Value of Financial Instr17

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 $ - $ 15,200 $ - $ 15,200 Level 1 Level 2 Level 3 Total As of December 31, 2015 Derivative assets, gross Commodity puts $ - $ 18,300 $ - $ 18,300

Certain Relationships and Rel18

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 Ended 2016 2015 Administrative fees $ 16,600 $ 21,200 Supervision fees 68,100 87,500 Transportation fees 6,800 13,800 Direct costs 41,600 51,500 Total $ 133,100 $ 174,000

Description of Business (Detail

Description of Business (Details)	3 Months Ended
	Mar. 31, 2016
Organization Consolidation And Presentation Of Financial Statements [Abstract]
Atlas America Series 25-2004 (A) L.P. Formation Date	Jan. 21, 2004

Summary of Significant Accoun20

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	$ 36,619,900	$ 36,619,900
Accumulated depletion and impairment	(35,572,000)	(35,572,000)
Gas and oil properties, net	1,047,900	1,047,900
Leasehold interests
Property Plant And Equipment [Line Items]
Total natural gas and oil properties	716,500	716,500
Wells and related equipment
Property Plant And Equipment [Line Items]
Total natural gas and oil properties	$ 35,903,400	$ 35,903,400

Derivative Instruments (Narrati

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	$ 15,200		$ 18,300
Gains (Losses) on Fair Value Hedge Ineffectiveness, Net	$ 0	$ 0

Derivative Instruments (Summary

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, oil and liquids revenues	$ 200	$ 2,200
Gains subsequent to hedge accounting recognized in gain on mark-to-market derivatives	$ 2,800	$ 2,600

Derivative Instruments (Commodi

Derivative Instruments (Commodity Derivatives) (Details)		3 Months Ended
		Mar. 31, 2016USD ($)MMBTU$ / MMBTU	Dec. 31, 2015USD ($)
Derivative [Line Items]
Fair Value Asset		$ 15,200	$ 18,300
Designated as Hedging Instrument | Natural Gas Put Options Production Period Ending December 31, 2016
Derivative [Line Items]
Volumes (MMBtu) | MMBTU	[1]	7,900
Average Fixed Price (per MMBtu) | $ / MMBTU	[1]	4.15
Fair Value Asset	[2]	$ 15,200
[1]	“MMBtu” represents million British Thermal Units
[2]	Fair value based on forward NYMEX natural gas prices, as applicable

Fair Value of Financial Instr24

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	$ 15,200	$ 18,300
Commodity Puts
Fair Value Assets And Liabilities Measured On Recurring And Nonrecurring Basis [Line Items]
Fair Value Asset	15,200	18,300
Fair Value, Inputs, Level 2 | Commodity Puts
Fair Value Assets And Liabilities Measured On Recurring And Nonrecurring Basis [Line Items]
Fair Value Asset	$ 15,200	$ 18,300

Certain Relationships and Rel25

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	313
Transportation fees
Related Party Transaction [Line Items]
Transportation Fees Rate As Percentage Of Natural Gas Sales Price	13.00%

Certain Relationships and Rel26

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	$ 133,100	$ 174,000
Administrative fees
Related Party Transaction [Line Items]
Related Party Transaction, Expenses from Transactions with Related Party	16,600	21,200
Supervision fees
Related Party Transaction [Line Items]
Related Party Transaction, Expenses from Transactions with Related Party	68,100	87,500
Transportation fees
Related Party Transaction [Line Items]
Related Party Transaction, Expenses from Transactions with Related Party	6,800	13,800
Direct costs
Related Party Transaction [Line Items]
Related Party Transaction, Expenses from Transactions with Related Party	$ 41,600	$ 51,500

Commitments and Contingencies (

Commitments and Contingencies (Narrative) (Details)	3 Months Ended
	Mar. 31, 2016USD ($)$ / 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 | $	$ 348,300