Atlas Resources Series 28-2010 10-Q 14 Aug 17 2017 Q2 Quarterly report Financial data

Document and Entity Information

Document and Entity Information	6 Months Ended
	Jun. 30, 2017shares
Document And Entity Information [Abstract]
Document Type	10-Q
Amendment Flag	false
Document Period End Date	Jun. 30, 2017
Document Fiscal Year Focus	2,017
Document Fiscal Period Focus	Q2
Entity Registrant Name	ATLAS RESOURCES SERIES 28-2010 L.P.
Entity Central Index Key	1,487,561
Current Fiscal Year End Date	--12-31
Entity Filer Category	Smaller Reporting Company
Entity Common Stock, Shares Outstanding	0

CONDENSED BALANCE SHEETS

CONDENSED BALANCE SHEETS - USD ($)	Jun. 30, 2017	Dec. 31, 2016
Current assets:
Cash	$ 12,100	$ 171,800
Accounts receivable trade-affiliate	1,725,900	1,223,800
Sales proceeds receivable-affiliate	17,800
Total current assets	1,755,800	1,395,600
Gas and oil properties, net	23,495,100	24,494,800
Long-term asset retirement receivable-affiliate	195,800	110,000
Total assets	25,446,700	26,000,400
Current liabilities:
Accrued liabilities	156,900	206,300
Total current liabilities	156,900	206,300
Asset retirement obligations	3,523,400	3,956,700
Commitments and contingencies (Note 4)
Partners’ capital:
Managing general partner’s interest	3,846,600	3,691,000
Limited partners’ interest (7,500 units)	17,919,800	18,146,400
Total partners’ capital	21,766,400	21,837,400
Total liabilities and partners’ capital	$ 25,446,700	$ 26,000,400

CONDENSED BALANCE SHEETS (Paren

CONDENSED BALANCE SHEETS (Parenthetical) - shares	Jun. 30, 2017	Dec. 31, 2016
Statement Of Financial Position [Abstract]
Limited partners' units	7,500	7,500

CONDENSED STATEMENTS OF OPERATI

CONDENSED STATEMENTS OF OPERATIONS - USD ($)	3 Months Ended		6 Months Ended
	Jun. 30, 2017	Jun. 30, 2016	Jun. 30, 2017	Jun. 30, 2016
REVENUES
Natural gas	$ 1,942,100	$ 1,157,300	$ 3,962,100	$ 2,308,500
Loss on mark-to-market derivatives		(134,200)		(11,800)
Total revenues	1,942,100	1,023,100	3,962,100	2,296,700
COSTS AND EXPENSES
Production	996,600	781,600	1,835,800	1,749,600
Depletion	436,700	409,700	867,000	826,000
Accretion of asset retirement obligations	44,500	42,400	89,000	84,800
General and administrative	33,400	33,200	66,400	66,800
Total costs and expenses	1,511,200	1,266,900	2,858,200	2,727,200
Operating income (loss)	430,900	(243,800)	1,103,900	(430,500)
Gain on sale of oil and gas properties	514,500		514,500
Net income (loss)	945,400	(243,800)	1,618,400	(430,500)
Allocation of net income (loss):
Managing general partner	419,500	50,800	751,500	26,000
Limited partners	$ 525,900	$ (294,600)	$ 866,900	$ (456,500)
Net income (loss) per limited partnership unit	$ 71	$ (39)	$ 116	$ (61)

CONDENSED STATEMENTS OF COMPREH

CONDENSED STATEMENTS OF COMPREHENSIVE INCOME (LOSS) - USD ($)	3 Months Ended		6 Months Ended
	Jun. 30, 2017	Jun. 30, 2016	Jun. 30, 2017	Jun. 30, 2016
Statement Of Income And Comprehensive Income [Abstract]
Net income (loss)	$ 945,400	$ (243,800)	$ 1,618,400	$ (430,500)
Other comprehensive loss:
Reclassification adjustment to net income (loss) of mark-to-market gains on cash flow hedges		(1,100)		(2,000)
Total other comprehensive loss		(1,100)		(2,000)
Comprehensive income (loss)	$ 945,400	$ (244,900)	$ 1,618,400	$ (432,500)

CONDENSED STATEMENT OF CHANGES

CONDENSED STATEMENT OF CHANGES IN PARTNERS' CAPITAL - 6 months ended Jun. 30, 2017 - USD ($)	Total	Managing General Partner	Limited Partners
Beginning balance at Dec. 31, 2016	$ 21,837,400	$ 3,691,000	$ 18,146,400
Participation in revenues, costs and expenses:
Net production revenues	2,126,300	799,300	1,327,000
Gain on sale of oil and gas properties	514,500	178,000	336,500
Depletion	(867,000)	(167,400)	(699,600)
Accretion of asset retirement obligations	(89,000)	(33,400)	(55,600)
General and administrative	(66,400)	(25,000)	(41,400)
Net income (loss)	1,618,400	751,500	866,900
Distributions to partners	(1,689,400)	(595,900)	(1,093,500)
Ending balance at Jun. 30, 2017	$ 21,766,400	$ 3,846,600	$ 17,919,800

CONDENSED STATEMENTS OF CASH FL

CONDENSED STATEMENTS OF CASH FLOWS - USD ($)	6 Months Ended
	Jun. 30, 2017	Jun. 30, 2016
Cash flows from operating activities:
Net income (loss)	$ 1,618,400	$ (430,500)
Adjustments to reconcile net income (loss) to net cash provided by operating activities:
Depletion	867,000	826,000
Non-cash loss on derivative value		430,400
Accretion of asset retirement obligations	89,000	84,800
Gain on sale of gas and oil properties – Niobrara	(514,500)
Changes in operating assets and liabilities:
(Increase) decrease in accounts receivable trade-affiliate	(502,100)	417,000
Increase in asset retirement receivable-affiliate	(85,800)	(34,800)
Increase in accounts payable trade-affiliate		130,700
Increase (decrease) in accrued liabilities	15,800	(20,400)
Asset retirement obligations settled	(4,300)
Net cash provided by operating activities	1,483,500	1,403,200
Cash flows from investing activities:
Proceeds from the sale of tangible equipment	46,200	16,300
Net cash provided by investing activities	46,200	16,300
Cash flows from financing activities:
Distributions to partners	(1,689,400)	(1,094,100)
Net cash used in financing activities	(1,689,400)	(1,094,100)
Net change in cash	(159,700)	325,400
Cash beginning of period	171,800	181,200
Cash at end of period	12,100	$ 506,600
Sales proceeds receivable	17,800
Niobrara Shale in Colorado
Adjustments to reconcile net income (loss) to net cash provided by operating activities:
Gain on sale of gas and oil properties – Niobrara	(514,500)
Cash flows from financing activities:
Write-off accrued property taxes associated with sale of Colorado properties	$ (65,200)

Description of Business

Description of Business	6 Months Ended
	Jun. 30, 2017
Organization Consolidation And Presentation Of Financial Statements [Abstract]
DESCRIPTION OF BUSINESS	NOTE 1 - DESCRIPTION OF BUSINESS Atlas Resources Series 28-2010 L.P. (the “Partnership”) is a Delaware limited partnership, formed on April 1, 2010 with Atlas Resources, LLC serving as its Managing General Partner (“Atlas Resources” or the “MGP”). Atlas Resources is an indirect subsidiary of Titan Energy, LLC (“Titan”). Titan is an independent developer and producer of natural gas, crude oil, and natural gas liquids, with operations in basins across the United States. Titan also sponsors and manages tax-advantaged investment partnerships, in which it co-invests to finance a portion of its natural gas and oil production activities. Titan is the successor to the business and operations of Atlas Resource Partners, L.P. (“ARP”), a Delaware limited partnership organized in 2012. Unless the context otherwise requires, references below to “the Partnership,” “we,” “us,” “our” and “our company”, refer to Atlas Resources Series 28-2010 L.P. Atlas Energy Group, LLC (“Atlas Energy Group”; OTCQX: ATLS) is a publicly traded company and manages Titan and the MGP through a 2% preferred member interest in Titan. The Partnership has drilled and currently operates wells located in Pennsylvania, Indiana and Colorado. We have no employees and rely on our MGP for management, which in turn, relies on Atlas Energy Group for administrative services. The Partnership’s operating cash flows are generated from its wells, which produce natural gas. Produced natural gas 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 will be sold are uncertain and the Partnership is not guaranteed a specific price for the sale of its production. Changes in natural gas prices have a significant impact on the Partnership’s cash flow and the value of its reserves. Lower natural gas prices may not only decrease the Partnership’s revenues, but also may reduce the amount of natural gas that the Partnership can produce economically. Liquidity, Capital Resources and Ability to Continue as a Going Concern 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. Historically, there has been no need to borrow funds from the MGP to fund operations as the cash flow from the Partnership’s operations had been adequate to fund its obligations and distributions to its partners. Prices for oil and natural gas began to decline significantly during the fourth quarter of 2014 and continue to remain low in 2017. These lower commodity prices have negatively impacted the Partnership’s revenues, earnings and cash flows. Sustained low commodity prices will have a material and adverse effect on the Partnership’s liquidity position and may make it uneconomical for the Partnership to produce its wells until they are depleted as the Partnership originally intended. In addition, the Partnership has experienced significant downward revisions of its natural gas and oil reserves volumes and values due to the 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 strategic 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 liquidation of the Partnership’s operations. The uncertainties of Titan’s and the MGP’s liquidity and capital resources (as further described below) raise substantial doubt about Titan’s and the MGP’s ability to continue as a going concern, which also raises substantial doubt about the Partnership’s ability to continue as a going concern. If Titan is unsuccessful in taking actions to resolve its liquidity issues (as further described below), the MGP’s ability to continue the Partnership’s operations may be further impacted and may make it uneconomical for the Partnership to produce its wells until they are depleted as originally intended. If the Partnership is not able to continue as a going concern, the Partnership will liquidate. If the Partnership’s operations are liquidated, a valuation of the Partnership’s assets and liabilities would be determined by an independent expert in accordance with the partnership agreement. It is possible that based on such determination, the Partnership would not be able to make any liquidation distributions to its limited partners. A liquidation could occur without any further contributions from or distributions to the limited partners. The financial statements have been prepared on a going concern basis of accounting, which contemplates continuity of operations, realization of assets, and satisfaction of liabilities and commitments in the normal course of business. The financial statements do not include any adjustments that might result from the outcome of the going concern uncertainty. If the Partnership cannot continue as a going concern, adjustments to the carrying values and classification of the Partnership’s assets and liabilities and the reported amounts of income and expenses could be required and could be material. MGP’s Liquidity, Capital Resources, and Ability to Continue as a Going Concern The MGP’s primary sources of liquidity are cash generated from operations, capital raised through its drilling partnership program, and borrowings under Titan’s credit facilities. The MGP’s primary cash requirements are operating expenses, payments to Titan for debt service including interest, and capital expenditures. The MGP has historically funded its operations, acquisitions and cash distributions primarily through cash generated from operations, amounts available under Titan’s credit facilities and equity and debt offerings. The MGP’s future cash flows are subject to a number of variables, including oil and natural gas prices. Prices for oil and natural gas began to decline significantly during the fourth quarter of 2014 and continue to remain low in 2017. These lower commodity prices have negatively impacted the MGP’s revenues, earnings and cash flows. Sustained low commodity prices could have a material and adverse effect on the MGP’s liquidity position. In addition, challenges with the MGP’s ability to raise capital through its drilling partnership program, either as a result of downturn in commodity prices or other difficulties affecting the fundraising channel, have negatively impacted Titan’s and the MGP’s ability to remain in compliance with the covenants under its credit facilities. Titan was not in compliance with certain of the financial covenants under its credit facilities as of December 31, 2016, as well as the requirement to deliver audited financial statements without a going concern qualification. Titan and the MGP do not currently have sufficient liquidity to repay all of Titan’s outstanding indebtedness, and as a result, there is substantial doubt regarding Titan’s and the MGP’s ability to continue as a going concern. On April 19, 2017, Titan entered into a third amendment to its first lien credit facility in an attempt to ameliorate some of its liquidity concerns. The amendment provides for, among other things, waivers of non-compliance, increases in certain financial covenant ratios and scheduled decreases in Titan’s borrowing base. In addition, Titan expects that it will sell a significant amount of non-core assets in the near future to comply with the requirements of its first lien credit facility amendment and to attempt to enhance its liquidity. The lenders’ waivers are subject to revocation in certain circumstances, including the exercise of remedies by junior lenders (including pursuant to Titan’s second lien credit facility), the failure to extend the 180-day standstill period under the intercreditor agreement at least 15 business days prior to its expiration, and the occurrence of additional events of default under the first lien credit facility. On April 21, 2017, the lenders under the Titan’s second lien credit facility delivered a notice of events of default and reservation of rights, pursuant to which they noticed events of default related to financial covenants and the failure to deliver financial statements without a “going concern” qualification. The delivery of such notice began the 180-day standstill period under the intercreditor agreement, during which the lenders under the second lien credit facility are prevented from pursuing remedies against the collateral securing Titan’s obligations under the second lien credit facility. The lenders have not accelerated the payment of amounts outstanding under the second lien credit facility. On May 4, 2017, Titan entered into a definitive purchase and sale agreement (the “Purchase Agreement”) to sell its conventional Appalachia and Marcellus assets to Diversified Gas & Oil, PLC (“Diversified”), for $84.2 million. The transaction includes the sale of approximately 8,400 oil and gas wells across Pennsylvania, Ohio, Tennessee, New York and West Virginia, along with the associated infrastructure (the “Appalachian Assets”). On June 30, 2017, Titan completed a majority of the Appalachian Assets sale for net cash proceeds of $65.6 million, which included customary preliminary purchase price adjustments, all of which was used to repay a portion of the outstanding indebtedness under its first lien credit facility. Effective on June 30, 2017, the MGP delegated operational activities to an affiliate of Diversified for the Partnership’s natural gas wells in Pennsylvania. Titan expects to complete the remainder of the Appalachia Assets sale for additional cash proceeds of approximately $11.4 million by September 2017, which will be used to repay a portion of outstanding borrowings under its first lien credit facility. On June 12, 2017, Titan entered into a definitive agreement to sell its 25% interest in Rangely Field to an affiliate of Merit Energy Company, LLC for $105 million. On August 7, 2017, Titan completed the sale of Rangely Field for net cash proceeds of $103.5 million, which included customary preliminary purchase price adjustments, all of which was used to repay a portion of the outstanding indebtedness under its first lien credit facility and significantly improved Titan’s first lien credit facility metrics by fulfilling its borrowing base step down to $330 million, which is scheduled to occur on August 31, 2017. Titan continually monitors the capital markets and the MGP’s capital structure and may make changes to its capital structure from time to time, with the goal of maintaining financial flexibility, preserving or improving liquidity, strengthening its balance sheet, meeting its debt service obligations and/or achieving cost efficiency. For example, Titan could pursue options such as refinancing, restructuring or reorganizing its indebtedness or capital structure or seek to raise additional capital through debt or equity financing to address its liquidity concerns and high debt levels. Titan is evaluating various options, but there is no certainty that Titan will be able to implement any such options, and cannot provide any assurances that any refinancing or changes in its debt or equity capital structure would be possible or that additional equity or debt financing could be obtained on acceptable terms, if at all, and such options may result in a wide range of outcomes for Titan’s stakeholders. In addition, Titan expects that it will continue to sell a significant amount of non-core assets in the near future to comply with the requirements of its first lien credit facility amendment and to attempt to enhance its liquidity. However, there is no guarantee that the proceeds Titan receives for any asset sale will satisfy the repayment requirements under its first lien credit facility. Titan’s Appalachia Divestiture Among other things, the Purchase Agreement includes the sale of Titan’s indirect interests in the assets and liabilities associated with the Partnership’s natural gas and oil wells in Pennsylvania to be transferred to DGOC Series 28, L.P., a newly formed entity and currently a subsidiary of the Partnership (“DGOC”), for which Atlas Resources serves as its managing general partner. We refer to this transfer as the “separation.” Following the satisfaction of a number of additional conditions, including, among others, the U.S. Securities and Exchange Commission (“SEC”) declaring the DGOC’s registration statement on Form 10 effective, the separation will be accomplished through a transaction in which all of the natural gas and oil development and production assets of the Partnership located in Pennsylvania will be transferred to DGOC. After the separation, the Partnership will distribute to its unit holders, on a pro rata basis, common units representing one hundred percent of the limited partner interest in DGOC. In connection with the completion of the separation and distribution, the MGP will transfer its limited partner and general partner interests in DGOC (the “DGOC equity interests”) to an entity expected to be named DGOC Partnership Holdings II, LLC (“DGOC Holdings”) formed as a wholly owned subsidiary of Titan to serve as DGOC’s new managing general partner (the “DGOC MGP”). Following the completion of the separation and distribution and the transfer of the DGOC equity interests to the DGOC MGP, the equity interests of the DGOC MGP will be transferred to Diversified and Diversified will own the managing general partner of the DGOC. In accordance with accounting standards related to the presentation of long-lived assets to be disposed of other than by sale, the Partnership continues to classify its Appalachia Assets as held and used in its condensed financial statements and will continue to do so until such assets are disposed of.

Summary of Significant Accounti

Summary of Significant Accounting Policies	6 Months Ended
	Jun. 30, 2017
Accounting Policies [Abstract]
SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES	NOTE 2 - SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES Use of Estimates The preparation of the Partnership’s condensed 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 condensed financial statements, as well as the reported amounts of revenues and costs and expenses during the reporting periods. The Partnership’s condensed 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. The natural gas industry principally conducts its business by processing actual transactions as 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. Actual results could differ from those estimates. Derivative Instruments The Partnership’s MGP entered into certain financial contracts to manage the Partnership’s exposure to movement in commodity prices. On January 1, 2015, the Partnership discontinued hedge accounting through de-designation for all of its existing commodity derivatives which were qualified as hedges. As such, subsequent changes in fair value after December 31, 2014 of these derivatives were recognized immediately within gain (loss) on mark-to-market derivatives in the Partnership’s statements of operations, while the fair values of the instruments recorded in accumulated other comprehensive income as of December 31, 2014 were reclassified to the statements of operations in the periods in which the respective derivative contracts settled. During the three and six months ended June 30, 2017, the Partnership did not have any derivative activity as all derivative contracts have matured. During the three and six months ended June 30, 2016, the Partnership recorded $1,100 and $2,000, respectively, as a gain reclassified from accumulated other comprehensive income into natural gas revenues and $134,200 and $11,800, respectively, as a loss subsequent to hedge accounting recognized in loss on mark-to-market derivatives. Gas and The following is a summary of gas and oil properties at the dates indicated: June 30, 2017 December 31, Proved properties: Leasehold interests $ 2,797,400 $ 5,301,300 Wells and related equipment 144,673,500 159,420,100 Total natural gas and oil properties 147,470,900 164,721,400 Accumulated depletion and impairment (123,975,800 ) (140,226,600 ) Gas and oil properties, net $ 23,495,100 $ 24,494,800 Upon the sale or retirement of a complete or partial unit of a proved property, the cost is eliminated from the property accounts, and the resultant gain or loss is reclassified to accumulated depletion. During the six months ended June 30, 2017, one well was plugged and abandoned and the related cost of $1,818,000 was reclassified to accumulated depletion. Upon the sale of an entire interest where the property had been assessed for impairment, a gain or loss is recognized in the statements of operations. On June 23, 2017, the Partnership sold its oil and gas properties with a net book value of $86,500 in the Niobrara Shale geological formation located in Colorado for $17,800. Cash proceeds from the sale will be distributed to the partnership unit holders in accordance with the terms of the partnership agreement. As a result of the sale, $15,432,500 of oil and gas properties, $15,346,000 of accumulated depletion and impairment, $65,200 of accrued property taxes and $518,000 of asset retirement obligations were removed from the partnership accounts resulting in a net gain of $514,500. Recently Issued Accounting Standards 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. We intend to adopt the new standard using the modified retrospective method, which is expected to have an immaterial impact to our financial statements. The accounting guidance will require that our revenue recognition policy disclosures include further detail regarding our performance obligations as to the nature, amount, timing, and estimates of revenue and cash flows generated from our contracts with customers.

Certain Relationships and Relat

Certain Relationships and Related Party Transactions	6 Months Ended
	Jun. 30, 2017
Related Party Transactions [Abstract]
CERTAIN RELATIONSHIPS AND RELATED PARTY TRANSACTIONS	NOTE 3 - 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 condensed 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 condensed statements of operations, are payable at $975 per well per month for Marcellus wells, $1,500 per well per month for New Albany wells, and for Colorado wells a fee of $400 is charged per well per month for operating and maintaining the wells. The following table provides information with respect to these costs and the periods incurred. Three Months Ended Six Months Ended 2017 2016 2017 2016 Administrative fees $ 16,200 $ 16,400 $ 32,200 $ 33,200 Supervision fees 172,400 172,400 337,600 354,700 Transportation fees 187,300 137,100 389,300 260,500 Direct costs 654,100 488,900 1,143,100 1,168,000 Total $ 1,030,000 $ 814,800 $ 1,902,200 $ 1,816,400 The MGP and its affiliates perform all administrative and management functions for the Partnership, including billing revenues and paying expenses. Accounts receivable trade-affiliate on the Partnership’s condensed balance sheets includes the net production revenues due from the MGP. Subordination by Managing General Partner Under the terms of the Partnership Agreement, the MGP may be required to subordinate up to 50% of its share of net production revenues of the Partnership to the benefit of the limited partners for an amount equal to at least 12% of their net subscriptions in the first 12-month subordination period, 10% of their net subscriptions in each of the next three 12-month subordination periods, and 8% of their net subscriptions in the fifth 12-month subordination period determined on a cumulative basis, in each of the first five years of Partnership operations, commencing with the first distribution to the limited partners (March 2011) and 60 months from that date. The subordination period expired September 2016.

Commitments and Contingencies

Commitments and Contingencies	6 Months Ended
	Jun. 30, 2017
Commitments And Contingencies Disclosure [Abstract]
COMMITMENTS AND CONTINGENCIES	NOTE 4 - COMMITMENTS AND CONTINGENCIES General Commitments Subject to certain conditions, investor partners may present their interests beginning in 2015 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 June 30, 2017, the MGP has withheld $195,800 of net production revenue for future plugging and abandonment costs. Effective on June 30, 2017, the MGP delegated operational activities to an affiliate of Diversified for the Partnership’s natural ga s Legal Proceedings The Partnership and affiliates of the MGP and their subsidiaries are party to various routine legal proceedings arising out of the ordinary course of its business. The MGP’s management believes that none of these actions, individually or in the aggregate, will have a material adverse effect on the Partnership’s or the MGP’s financial condition or results of operations.

Summary of Significant Accoun12

Summary of Significant Accounting Policies (Policies)	6 Months Ended
	Jun. 30, 2017
Summary Of Significant Accounting Policies [Line Items]
Liquidity, Capital Resources and Ability to Continue as a Going Concern	Liquidity, Capital Resources and Ability to Continue as a Going Concern 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. Historically, there has been no need to borrow funds from the MGP to fund operations as the cash flow from the Partnership’s operations had been adequate to fund its obligations and distributions to its partners. Prices for oil and natural gas began to decline significantly during the fourth quarter of 2014 and continue to remain low in 2017. These lower commodity prices have negatively impacted the Partnership’s revenues, earnings and cash flows. Sustained low commodity prices will have a material and adverse effect on the Partnership’s liquidity position and may make it uneconomical for the Partnership to produce its wells until they are depleted as the Partnership originally intended. In addition, the Partnership has experienced significant downward revisions of its natural gas and oil reserves volumes and values due to the 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 strategic 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 liquidation of the Partnership’s operations. The uncertainties of Titan’s and the MGP’s liquidity and capital resources (as further described below) raise substantial doubt about Titan’s and the MGP’s ability to continue as a going concern, which also raises substantial doubt about the Partnership’s ability to continue as a going concern. If Titan is unsuccessful in taking actions to resolve its liquidity issues (as further described below), the MGP’s ability to continue the Partnership’s operations may be further impacted and may make it uneconomical for the Partnership to produce its wells until they are depleted as originally intended. If the Partnership is not able to continue as a going concern, the Partnership will liquidate. If the Partnership’s operations are liquidated, a valuation of the Partnership’s assets and liabilities would be determined by an independent expert in accordance with the partnership agreement. It is possible that based on such determination, the Partnership would not be able to make any liquidation distributions to its limited partners. A liquidation could occur without any further contributions from or distributions to the limited partners. The financial statements have been prepared on a going concern basis of accounting, which contemplates continuity of operations, realization of assets, and satisfaction of liabilities and commitments in the normal course of business. The financial statements do not include any adjustments that might result from the outcome of the going concern uncertainty. If the Partnership cannot continue as a going concern, adjustments to the carrying values and classification of the Partnership’s assets and liabilities and the reported amounts of income and expenses could be required and could be material.
Titan's Appalachia Divestiture	Titan’s Appalachia Divestiture Among other things, the Purchase Agreement includes the sale of Titan’s indirect interests in the assets and liabilities associated with the Partnership’s natural gas and oil wells in Pennsylvania to be transferred to DGOC Series 28, L.P., a newly formed entity and currently a subsidiary of the Partnership (“DGOC”), for which Atlas Resources serves as its managing general partner. We refer to this transfer as the “separation.” Following the satisfaction of a number of additional conditions, including, among others, the U.S. Securities and Exchange Commission (“SEC”) declaring the DGOC’s registration statement on Form 10 effective, the separation will be accomplished through a transaction in which all of the natural gas and oil development and production assets of the Partnership located in Pennsylvania will be transferred to DGOC. After the separation, the Partnership will distribute to its unit holders, on a pro rata basis, common units representing one hundred percent of the limited partner interest in DGOC. In connection with the completion of the separation and distribution, the MGP will transfer its limited partner and general partner interests in DGOC (the “DGOC equity interests”) to an entity expected to be named DGOC Partnership Holdings II, LLC (“DGOC Holdings”) formed as a wholly owned subsidiary of Titan to serve as DGOC’s new managing general partner (the “DGOC MGP”). Following the completion of the separation and distribution and the transfer of the DGOC equity interests to the DGOC MGP, the equity interests of the DGOC MGP will be transferred to Diversified and Diversified will own the managing general partner of the DGOC. In accordance with accounting standards related to the presentation of long-lived assets to be disposed of other than by sale, the Partnership continues to classify its Appalachia Assets as held and used in its condensed financial statements and will continue to do so until such assets are disposed of.
Use of Estimates	Use of Estimates The preparation of the Partnership’s condensed 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 condensed financial statements, as well as the reported amounts of revenues and costs and expenses during the reporting periods. The Partnership’s condensed 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. The natural gas industry principally conducts its business by processing actual transactions as 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. Actual results could differ from those estimates.
Derivative Instruments	Derivative Instruments The Partnership’s MGP entered into certain financial contracts to manage the Partnership’s exposure to movement in commodity prices. On January 1, 2015, the Partnership discontinued hedge accounting through de-designation for all of its existing commodity derivatives which were qualified as hedges. As such, subsequent changes in fair value after December 31, 2014 of these derivatives were recognized immediately within gain (loss) on mark-to-market derivatives in the Partnership’s statements of operations, while the fair values of the instruments recorded in accumulated other comprehensive income as of December 31, 2014 were reclassified to the statements of operations in the periods in which the respective derivative contracts settled. During the three and six months ended June 30, 2017, the Partnership did not have any derivative activity as all derivative contracts have matured. During the three and six months ended June 30, 2016, the Partnership recorded $1,100 and $2,000, respectively, as a gain reclassified from accumulated other comprehensive income into natural gas revenues and $134,200 and $11,800, respectively, as a loss subsequent to hedge accounting recognized in loss on mark-to-market derivatives.
Gas and Oil Properties	Gas and The following is a summary of gas and oil properties at the dates indicated: June 30, 2017 December 31, Proved properties: Leasehold interests $ 2,797,400 $ 5,301,300 Wells and related equipment 144,673,500 159,420,100 Total natural gas and oil properties 147,470,900 164,721,400 Accumulated depletion and impairment (123,975,800 ) (140,226,600 ) Gas and oil properties, net $ 23,495,100 $ 24,494,800 Upon the sale or retirement of a complete or partial unit of a proved property, the cost is eliminated from the property accounts, and the resultant gain or loss is reclassified to accumulated depletion. During the six months ended June 30, 2017, one well was plugged and abandoned and the related cost of $1,818,000 was reclassified to accumulated depletion. Upon the sale of an entire interest where the property had been assessed for impairment, a gain or loss is recognized in the statements of operations. On June 23, 2017, the Partnership sold its oil and gas properties with a net book value of $86,500 in the Niobrara Shale geological formation located in Colorado for $17,800. Cash proceeds from the sale will be distributed to the partnership unit holders in accordance with the terms of the partnership agreement. As a result of the sale, $15,432,500 of oil and gas properties, $15,346,000 of accumulated depletion and impairment, $65,200 of accrued property taxes and $518,000 of asset retirement obligations were removed from the partnership accounts resulting in a net gain of $514,500.
Recently Issued Accounting Standards	Recently Issued Accounting Standards 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. We intend to adopt the new standard using the modified retrospective method, which is expected to have an immaterial impact to our financial statements. The accounting guidance will require that our revenue recognition policy disclosures include further detail regarding our performance obligations as to the nature, amount, timing, and estimates of revenue and cash flows generated from our contracts with customers.
MGP
Summary Of Significant Accounting Policies [Line Items]
Liquidity, Capital Resources and Ability to Continue as a Going Concern	MGP’s Liquidity, Capital Resources, and Ability to Continue as a Going Concern The MGP’s primary sources of liquidity are cash generated from operations, capital raised through its drilling partnership program, and borrowings under Titan’s credit facilities. The MGP’s primary cash requirements are operating expenses, payments to Titan for debt service including interest, and capital expenditures. The MGP has historically funded its operations, acquisitions and cash distributions primarily through cash generated from operations, amounts available under Titan’s credit facilities and equity and debt offerings. The MGP’s future cash flows are subject to a number of variables, including oil and natural gas prices. Prices for oil and natural gas began to decline significantly during the fourth quarter of 2014 and continue to remain low in 2017. These lower commodity prices have negatively impacted the MGP’s revenues, earnings and cash flows. Sustained low commodity prices could have a material and adverse effect on the MGP’s liquidity position. In addition, challenges with the MGP’s ability to raise capital through its drilling partnership program, either as a result of downturn in commodity prices or other difficulties affecting the fundraising channel, have negatively impacted Titan’s and the MGP’s ability to remain in compliance with the covenants under its credit facilities. Titan was not in compliance with certain of the financial covenants under its credit facilities as of December 31, 2016, as well as the requirement to deliver audited financial statements without a going concern qualification. Titan and the MGP do not currently have sufficient liquidity to repay all of Titan’s outstanding indebtedness, and as a result, there is substantial doubt regarding Titan’s and the MGP’s ability to continue as a going concern. On April 19, 2017, Titan entered into a third amendment to its first lien credit facility in an attempt to ameliorate some of its liquidity concerns. The amendment provides for, among other things, waivers of non-compliance, increases in certain financial covenant ratios and scheduled decreases in Titan’s borrowing base. In addition, Titan expects that it will sell a significant amount of non-core assets in the near future to comply with the requirements of its first lien credit facility amendment and to attempt to enhance its liquidity. The lenders’ waivers are subject to revocation in certain circumstances, including the exercise of remedies by junior lenders (including pursuant to Titan’s second lien credit facility), the failure to extend the 180-day standstill period under the intercreditor agreement at least 15 business days prior to its expiration, and the occurrence of additional events of default under the first lien credit facility. On April 21, 2017, the lenders under the Titan’s second lien credit facility delivered a notice of events of default and reservation of rights, pursuant to which they noticed events of default related to financial covenants and the failure to deliver financial statements without a “going concern” qualification. The delivery of such notice began the 180-day standstill period under the intercreditor agreement, during which the lenders under the second lien credit facility are prevented from pursuing remedies against the collateral securing Titan’s obligations under the second lien credit facility. The lenders have not accelerated the payment of amounts outstanding under the second lien credit facility. On May 4, 2017, Titan entered into a definitive purchase and sale agreement (the “Purchase Agreement”) to sell its conventional Appalachia and Marcellus assets to Diversified Gas & Oil, PLC (“Diversified”), for $84.2 million. The transaction includes the sale of approximately 8,400 oil and gas wells across Pennsylvania, Ohio, Tennessee, New York and West Virginia, along with the associated infrastructure (the “Appalachian Assets”). On June 30, 2017, Titan completed a majority of the Appalachian Assets sale for net cash proceeds of $65.6 million, which included customary preliminary purchase price adjustments, all of which was used to repay a portion of the outstanding indebtedness under its first lien credit facility. Effective on June 30, 2017, the MGP delegated operational activities to an affiliate of Diversified for the Partnership’s natural gas wells in Pennsylvania. Titan expects to complete the remainder of the Appalachia Assets sale for additional cash proceeds of approximately $11.4 million by September 2017, which will be used to repay a portion of outstanding borrowings under its first lien credit facility. On June 12, 2017, Titan entered into a definitive agreement to sell its 25% interest in Rangely Field to an affiliate of Merit Energy Company, LLC for $105 million. On August 7, 2017, Titan completed the sale of Rangely Field for net cash proceeds of $103.5 million, which included customary preliminary purchase price adjustments, all of which was used to repay a portion of the outstanding indebtedness under its first lien credit facility and significantly improved Titan’s first lien credit facility metrics by fulfilling its borrowing base step down to $330 million, which is scheduled to occur on August 31, 2017. Titan continually monitors the capital markets and the MGP’s capital structure and may make changes to its capital structure from time to time, with the goal of maintaining financial flexibility, preserving or improving liquidity, strengthening its balance sheet, meeting its debt service obligations and/or achieving cost efficiency. For example, Titan could pursue options such as refinancing, restructuring or reorganizing its indebtedness or capital structure or seek to raise additional capital through debt or equity financing to address its liquidity concerns and high debt levels. Titan is evaluating various options, but there is no certainty that Titan will be able to implement any such options, and cannot provide any assurances that any refinancing or changes in its debt or equity capital structure would be possible or that additional equity or debt financing could be obtained on acceptable terms, if at all, and such options may result in a wide range of outcomes for Titan’s stakeholders. In addition, Titan expects that it will continue to sell a significant amount of non-core assets in the near future to comply with the requirements of its first lien credit facility amendment and to attempt to enhance its liquidity. However, there is no guarantee that the proceeds Titan receives for any asset sale will satisfy the repayment requirements under its first lien credit facility.

Summary of Significant Accoun13

Summary of Significant Accounting Policies (Tables)	6 Months Ended
	Jun. 30, 2017
Accounting Policies [Abstract]
Summary of Gas and Oil Properties	The following is a summary of gas and oil properties at the dates indicated: June 30, 2017 December 31, Proved properties: Leasehold interests $ 2,797,400 $ 5,301,300 Wells and related equipment 144,673,500 159,420,100 Total natural gas and oil properties 147,470,900 164,721,400 Accumulated depletion and impairment (123,975,800 ) (140,226,600 ) Gas and oil properties, net $ 23,495,100 $ 24,494,800

Certain Relationships and Rel14

Certain Relationships and Related Party Transactions (Tables)	6 Months Ended
	Jun. 30, 2017
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 Six Months Ended 2017 2016 2017 2016 Administrative fees $ 16,200 $ 16,400 $ 32,200 $ 33,200 Supervision fees 172,400 172,400 337,600 354,700 Transportation fees 187,300 137,100 389,300 260,500 Direct costs 654,100 488,900 1,143,100 1,168,000 Total $ 1,030,000 $ 814,800 $ 1,902,200 $ 1,816,400

Description of Business (Detail

Description of Business (Details)	Aug. 07, 2017USD ($)	Jun. 30, 2017USD ($)	Jun. 12, 2017USD ($)	May 04, 2017USD ($)Well	Sep. 30, 2017USD ($)	Jun. 30, 2017USD ($)	Jun. 30, 2016USD ($)
Description Of Business [Line Items]
Atlas Resources Series 28-2010 L.P.						Apr. 1, 2010
Sale of assets						$ 46,200	$ 16,300
DGOC
Description Of Business [Line Items]
Percentage of limited partner interest representing common units						100.00%
Titan Energy, LLC | Affiliate of Merit Energy Company, LLC
Description Of Business [Line Items]
Percentage of sale of interest in assets			25.00%
Definitive agreement amount on sale of assets to affiliate			$ 105,000,000
Titan Energy, LLC | Appalachia and Marcellus
Description Of Business [Line Items]
Definitive agreement amount on sale of assets				$ 84,200,000
Number of oil and gas wells sold | Well				8,400
Titan Energy, LLC | Appalachia
Description Of Business [Line Items]
Sale of assets		$ 65,600,000
Titan Energy, LLC | Rangely Field | Affiliate of Merit Energy Company, LLC | Subsequent Event
Description Of Business [Line Items]
Sale of assets to affiliate	$ 103,500,000
Titan Energy, LLC | Rangely Field | Affiliate of Merit Energy Company, LLC | First Lien Credit Facility
Description Of Business [Line Items]
Step down in borrowing base			$ 330,000,000
Titan Energy, LLC | Scenario, Forecast | Appalachia
Description Of Business [Line Items]
Sale of assets					$ 11,400,000
Atlas Energy Group, LLC | Titan Energy, LLC | Preferred Member Interest
Description Of Business [Line Items]
Percentage of preferred interest		2.00%				2.00%

Summary of Significant Accoun16

Summary of Significant Accounting Policies (Narrative) (Details)	Jun. 23, 2017USD ($)	Jun. 30, 2017USD ($)	Jun. 30, 2016USD ($)	Jun. 30, 2017USD ($)Well	Jun. 30, 2016USD ($)	Dec. 31, 2016USD ($)
Summary Of Significant Accounting Policies [Line Items]
Gain reclassified from accumulated other comprehensive income into natural gas revenues			$ 1,100		$ 2,000
Loss subsequent to hedge accounting recognized in loss on mark-to-market derivatives			$ (134,200)		$ (11,800)
Number of wells plugged and abandoned | Well				1
Reclassification from oil and gas properties to accumulated depletion due to asset retirements				$ 1,818,000
Net book value of of oil and gas properties sold		$ 23,495,100		23,495,100		$ 24,494,800
Proceeds receivable from sale of oil and gas property				17,800
Gain on disposition of oil and gas properties		$ 514,500		514,500
Niobrara Shale in Colorado
Summary Of Significant Accounting Policies [Line Items]
Net book value of of oil and gas properties sold	$ 86,500
Proceeds receivable from sale of oil and gas property	17,800
Accrued property taxes removed with sale of oil and gas properties				65,200
Gain on disposition of oil and gas properties	514,500			$ 514,500
Niobrara Shale in Colorado | Oil and Gas Properties
Summary Of Significant Accounting Policies [Line Items]
Oil and gas properties sold	15,432,500
Accumulated depletion and impairment removed with sale of oil and gas properties	15,346,000
Accrued property taxes removed with sale of oil and gas properties	65,200
Asset retirement obligation removed with sale of oil and gas properties	$ 518,000

Summary of Significant Accoun17

Summary of Significant Accounting Policies (Summary of Gas and Oil Properties) (Details) - USD ($)	Jun. 30, 2017	Dec. 31, 2016
Property Plant And Equipment [Line Items]
Total natural gas and oil properties	$ 147,470,900	$ 164,721,400
Accumulated depletion and impairment	(123,975,800)	(140,226,600)
Gas and oil properties, net	23,495,100	24,494,800
Leasehold interests
Property Plant And Equipment [Line Items]
Total natural gas and oil properties	2,797,400	5,301,300
Wells and related equipment
Property Plant And Equipment [Line Items]
Total natural gas and oil properties	$ 144,673,500	$ 159,420,100

Certain Relationships and Rel18

Certain Relationships and Related Party Transactions (Narrative) (Details)	6 Months Ended
	Jun. 30, 2017$ / mo
Related Party Transaction [Line Items]
Managing General Partner Maximum Subordination Percentage Of Share Of Net Production Revenues	50.00%
MGP | First 12 Month Subordination Period
Related Party Transaction [Line Items]
Subordination Target Return Rate For Limited Partner Subscriptions	12.00%
MGP | Next Three 12 Month Subordination Periods
Related Party Transaction [Line Items]
Subordination Target Return Rate For Limited Partner Subscriptions	10.00%
MGP | Fifth 12 Month Subordination Period
Related Party Transaction [Line Items]
Subordination Target Return Rate For Limited Partner Subscriptions	8.00%
MGP and Affiliates | General and administrative expenses
Related Party Transaction [Line Items]
Monthly Administrative Costs Per Well	75
MGP and Affiliates | Production
Related Party Transaction [Line Items]
Transportation Fee Rate As Percentage Of Natural Gas Sales Price	16.00%
MGP and Affiliates | Production | Marcellus wells
Related Party Transaction [Line Items]
Monthly Supervision Fees Per Well	975
MGP and Affiliates | Production | New Albany Wells
Related Party Transaction [Line Items]
Monthly Supervision Fees Per Well	1,500
MGP and Affiliates | Production | Colorado Wells
Related Party Transaction [Line Items]
Monthly Supervision Fees Per Well	400

Certain Relationships and Rel19

Certain Relationships and Related Party Transactions (Certain Relationships and Related Party Transactions) (Details) - MGP and Affiliates - USD ($)	3 Months Ended		6 Months Ended
	Jun. 30, 2017	Jun. 30, 2016	Jun. 30, 2017	Jun. 30, 2016
Related Party Transaction [Line Items]
Related Party Transaction, Expenses from Transactions with Related Party	$ 1,030,000	$ 814,800	$ 1,902,200	$ 1,816,400
Administrative fees
Related Party Transaction [Line Items]
Related Party Transaction, Expenses from Transactions with Related Party	16,200	16,400	32,200	33,200
Supervision fees
Related Party Transaction [Line Items]
Related Party Transaction, Expenses from Transactions with Related Party	172,400	172,400	337,600	354,700
Transportation fees
Related Party Transaction [Line Items]
Related Party Transaction, Expenses from Transactions with Related Party	187,300	137,100	389,300	260,500
Direct costs
Related Party Transaction [Line Items]
Related Party Transaction, Expenses from Transactions with Related Party	$ 654,100	$ 488,900	$ 1,143,100	$ 1,168,000

Commitments and Contingencies (

Commitments and Contingencies (Narrative) (Details)	6 Months Ended
	Jun. 30, 2017USD ($)$ / 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 | $	$ 195,800