10-Q

United States
Securities and Exchange Commission
Washington, D.C. 20549

Form 10-Q

(Mark One)

x	QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15 (d) OF THE SECURITIES EXCHANGE ACT OF 1934
	For the quarterly period ended June 30, 2016
¨	TRANSITION REPORT PURSUANT TO SECTION 13 OR 15 (d) OF THE SECURITIES EXCHANGE ACT OF 1934
	For the transition period from ___________ to ___________

MDS ENERGY PUBLIC 2013-A LP

(Name of small business issuer in its charter)

Delaware (State or other jurisdiction of incorporation or organization)	90-0852601 (I.R.S. Employer Identification No.)
409 Butler Road Suite A
Kittanning, PA (Address of principal executive offices)	16201 (zip code)
Issuer’s telephone number, including area code: (855) 807-0807

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

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

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

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

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

As of June 30, 2016 this Partnership had 1,508.53 units of limited partnership interest outstanding.

MDS ENERGY PUBLIC 2013 – A LP
(A Delaware Limited Partnership)
INDEX TO QUARTERLY REPORT
ON FORM 10-Q

		PAGE
	PART I. FINANCIAL INFORMATION
Item 1:	Financial Statements (Unaudited)
	Condensed Balance Sheets	1
	Condensed Statements of Operations	2
	Condensed Statements of Partners’ Equity (Deficit)	3
	Condensed Statements of Cash Flow	4
	Notes to Unaudited Condensed Financial Statements	5
Item 2:	Management’s Discussion and Analysis of Financial Condition and Results of Operations (Unaudited)	9
Item 4:	Controls and Procedures	12
	PART II. OTHER INFORMATION
Item 1:	Legal Proceedings	12
Item 2:	Unregistered Sales of Equity Securities and Use of Proceeds	12
Item 3:	Defaults Upon Senior Securities	12
Item 4.	Mine Safety Disclosures	12
Item 5:	Other Information	12
Item 6:	Exhibits	13
SIGNATURES		14
CERTIFICATIONS

IMPLICATIONS OF BEING AN EMERGING GROWTH COMPANY.

The Jumpstart Our Business Startups Act (the “JOBS Act”) became law in April 2012. The Partnership is an “emerging growth Company” as defined in the JOBS Act, and it is eligible for certain exemptions from, or reduced disclosure obligations relating to, various reporting requirements that usually apply to public companies.

These exemptions include, among others, not being required to comply with the auditor attestation requirements of Section 404 of the Sarbanes-Oxley Act, any requirements adopted by the Public Company Accounting Oversight Board (the “PCAOB”) which require mandatory audit firm rotation or a supplement to the auditor’s report in which the auditor must provide additional information about the audit and the issuer’s financial statements, nor with new audit rules adopted by the PCAOB after April 5, 2012, unless the SEC determines otherwise. The Partnership has not yet decided whether to use any or all of the exemptions.

Additionally, under Section 107 of the JOBS Act, an “emerging growth company” is eligible for the extended transition period provided in Section 7(a)(2)(B) of the Securities Act of 1933 (the “Act”) to comply with new or revised accounting standards. This means an “emerging growth company” can delay adopting certain accounting standards until those standards otherwise become applicable to private companies. However, the Partnership is electing to “opt out” of that extended transition period, and therefore will comply with new or revised accounting standards on the dates the standards are required for non-emerging growth companies. Section 107 of the JOBS Act provides that the Partnership’s decision to opt out of the extended transition period for compliance with new or revised accounting standards is irrevocable.

The Partnership could continue to be an “emerging growth company” until the earliest of:

(i) the last day of the first fiscal year in which it has total annual gross revenue of $1 billion or more;

(ii) the last day of the fiscal year following the fifth anniversary of the date of the first sale of its units pursuant to its prospectus and Registration Statement with the SEC;

(iii) the date that it becomes a “large accelerated filer” as defined in Rule 12b-2 under the Securities Exchange Act of 1934 (the “Exchange Act”), which would occur if the market value of its units held by non-affiliates exceeds $700 million, measured as of the last business day of its most recently completed second fiscal quarter; or

(iv) the date on which it has, during the preceding three year period, issued more than $1 billion in non-convertible debt.

The Partnership anticipates that it will continue to be an emerging growth company until the termination of the five year period described in (ii), above.

Part I. FINANCIAL INFORMATION

Item 1. Financial Statements:

MDS ENERGY PUBLIC 2013-A LP
Condensed Balance Sheets

	June 30, 2016 (Unaudited)			December 31, 2015 Derived from Audited Statements
Assets
Current Assets
Cash and Cash Equivalents	$	37,074		$	23,707
Accounts Receivable Related Party		79,545			78,760
Accounts Receivable Managing General Partner		31,143			19,510
Total Current Assets		147,762			121,977
Natural Gas Properties, net		320,367			396,715
Total Assets	$	468,129		$	518,692
Liabilities and Partners’ Deficit
Accrued Expenses	$	76,082		$	82,235
Due to Managing General Partner		28,000			28,000
Accrued Expenses -  Related Party		92,066			28,800
Total Current Liabilities		196,148			139,035
Long-term Asset Retirement Obligations		654,303			651,870
Partners’ Deficit		(382,322	)		(272,213	)
Total Liabilities and Partners’ Deficit	$	468,129		$	518,692

The accompanying notes are an integral part of these unaudited financial statements.

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MDS ENERGY PUBLIC 2013-A LP
Condensed Statements of Operations
(Unaudited)

	For the Six Months Ended June 30						For the Three Months Ended June 30
	2016			2015			2016			2015
Natural Gas Revenue, net	$	233,511		$	396,089		$	118,264		$	189,400
Expenses
Gathering Expense		82,024			87,614			40,725			49,672
Well Maintenance		75,655			83,669			36,441			36,376
Depreciation, Depletion and Amortization Expense		78,781			345,641			29,051			178,355
Impact Fee		32,356			77,414			6,315			26,041
Professional Fees		55,753			50,000			29,056			25,000
Total Expenses		324,569			644,338			141,588			315,444
Net Loss	$	(91,058	)	$	(248,249	)	$	(23,324	)	$	(126,044	)

The accompanying notes are an integral part of these unaudited financial statements.

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MDS ENERGY PUBLIC 2013-A LP
Condensed Statements of Partners’ Equity (Deficit)
(Unaudited)

	Investor Partners			Managing General Partner			Total
Balance at December 31, 2014	$	7,529,923		$	(1,094,385	)	$	6,435,538
(Distributions) Subordination		(199,876	)		5,012	*		(194,864	)
Net Loss		(208,231	)		(40,018	)		(248,249	)
Balance at June 30, 2015	$	7,121,816		$	(1,129,391	)	$	5,992,425
*due to subordination

	Investor Partners			Managing General Partner			Total
Balance at December 31, 2015	$	1,848,004		$	(2,120,217	)	$	(272,213	)
(Distributions) Subordination		(30,684	)		11,633	*		(19,051	)
Net Loss		(76,447	)		(14,611	)		(91,058	)
Balance at June 30, 2016	$	1,740,873		$	(2,123,195	)	$	(382,322	)
*due to subordination

The accompanying notes are an integral part of these unaudited financial statements.

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MDS ENERGY PUBLIC 2013-A LP
Condensed Statements of Cash Flows
(Unaudited)

	For the Six Months Ended June 30
	2016			2015
Cash flows from Operating activities
Net Loss	$	(91,058	)	$	(248,249	)
Adjustments to reconcile net loss to cash provided by operating activities
Depreciation, Depletion and Amortization		78,781			345,641
Total adjustments to net loss to reconcile to net cash provided by operating activities		(12,277	)		97,392
Changes in assets and liabilities
Accounts Receivable and Due from Managing General Partner		(785	)		101,007
Accrued Expenses		57,113			6,147
Net cash provided by operating activities		44,051			204,546
Cash flows from financing activities
Distributions		(30,684	)		(199,876	)
Net change in cash and cash equivalents		13,367			4,670
Cash and cash equivalents at beginning of period		23,707			18,264
Cash and cash equivalents at end of period	$	37,074		$	22,934
Supplemental Schedule of Non-Cash Financing Activities:
During the six months ended June 30, 2016 and 2015 the MGP subordinated  it’s distributions of $11,633 and $5,012 respectively.

The accompanying notes are an integral part of these unaudited financial statements.

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MDS ENERGY PUBLIC 2013-A LP

NOTES TO UNAUDITED CONDENSED FINANCIAL STATEMENTS

June 30, 2016

NOTE 1 - ORGANIZATION AND NATURE OF OPERATIONS

On May 3, 2012 (date of inception), MDS Energy Public 2013-A LP (Partnership), a Delaware limited partnership, was formed for the purpose of drilling developmental natural gas wells. The Partnership has a maximum 50-year term, although the Partnership intends to terminate when all of the wells invested in by the Partnership become uneconomical to continue to operate, which may be approximately 15 years or longer. The Partnership was formed by MDS Energy Development, LLC (MDS), a related party, as the Managing General Partner (MGP) and M/D Gas, Inc. (M/D), a related party. In accordance with the terms of the limited partnership agreement, the MGP is authorized to manage all activities of the Partnership and initiates and completes substantially all transactions.

In our opinion, the accompanying condensed financial statements contain all adjustments necessary for a fair presentation of the Partnership’s financial statements for interim periods in accordance with accounting principles generally accepted in the United States of America (U.S. GAAP) and with the instructions to Form 10-Q and Article 10 of Regulation S-X of the SEC. Accordingly, pursuant to such rules and regulations, certain notes and other financial information included in audited financial statements have been condensed or omitted. The information presented in this Quarterly Report on Form 10-Q should be read in conjunction with the Partnership’s audited financial statements and notes thereto included in its 2015 Form 10-K. The results of operations for the interim periods are not necessarily indicative of the results of operations to be expected for the full year.

NOTE 2 - SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES

Proved Property Impairment - The Partnership assesses its producing natural gas properties for possible impairment, upon a triggering event, by comparing net capitalized costs to estimated undiscounted future net cash flows on a well by well basis using estimated production based upon prices at which the Partnership reasonably estimates the commodities to be sold.  The estimates of future prices may differ from current market prices of natural gas.  Certain events, including but not limited to, downward revisions in estimates to the Partnership’s reserve quantities, expectations of falling commodity prices or rising operating costs, could result in a triggering event and, therefore, a possible impairment of the Partnership’s proved natural gas properties.  If net capitalized costs exceed undiscounted future net cash flows, the measurement of impairment is based on estimated fair value utilizing a future discounted cash flows analysis, which is predominantly unobservable data or inputs, and is measured by the amount by which the net capitalized costs exceed their fair value.  Estimated undiscounted future net cash flows are determined using prices from the forward price curve at the measurement date.  Estimated discounted future net cash flows are determined utilizing a risk adjusted discount rate that is based on rates utilized by market participants that are commensurate with the risks inherent in the development of the underlying natural gas reserves.  Due to the decrease in natural gas prices, as further discussed in Note 4, the Partnership reviewed its proved natural gas properties for impairment at June 30, 2016 and did not recognize an impairment charge for the second quarter 2016.  The Partnership has an accumulated impairment charge of proved natural gas properties of approximately $11,810,700 as of June 30, 2016 and December 31, 2015.

Asset Retirement Obligations - The Partnership applies the provisions of “Accounting for Asset Retirement Obligations” and “Accounting for Conditional Asset Retirement Obligations” and accounts for asset retirement obligations by recording the fair value of its plugging and abandonment obligations when incurred, which is at the time the well is completely drilled. Upon initial recognition of an asset retirement obligation, the Partnership increases the carrying amount of the long-lived asset by the same amount as the liability. Over time, the asset retirement obligations are accreted, over the estimated life of the related asset, for the change in their present value. The initial capitalized costs are depleted over the useful lives of the related assets, through charges to depreciation, depletion and amortization. If the fair value of the estimated asset retirement obligation changes, an adjustment is recorded to both the asset retirement obligation and the asset retirement cost. Revisions in estimated liabilities can result from revisions of estimated inflation rates, escalating retirement costs and changes in the estimated timing of settling asset retirement obligations.

Recent Accounting Pronouncements - In May 2014, the FASB and the International Accounting Standards Board issued their converged standard on revenue recognition that provides a single, comprehensive model that entities will apply to determine the measurement of revenue and timing of when it is recognized. The underlying principle is that an entity will recognize revenue to depict the transfer of goods or services to customers at an amount that the entity expects to be entitled to in exchange for those goods or services. The standard outlines a five-step approach to apply the underlying principle: (a) identify the contract with the customer, (b) identify the separate performance obligations in the contract, (c) determine the transaction price, (d) allocate the transaction price to separate performance obligations and (e) recognize revenue when (or as) each performance obligation is satisfied. The revenue standard is effective for annual reporting periods beginning after December 15, 2017, including interim periods within that reporting period, and can be adopted under the full retrospective method or simplified transition method. Early adoption is not permitted. The Partnership plans to adopt the revenue standard beginning January 1, 2018 and is currently evaluating the impact that these changes will have on our condensed financial statements.

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In August 2014, the FASB issued Accounting Standards Update (ASU) No. 2014-15, Disclosures of Uncertainties About an Entity’s Ability to Continue as a Going Concern, new guidance related to the disclosures around going concern. The new standard provides guidance around management’s responsibility to evaluate whether there is substantial doubt about an entity’s ability to continue as a going concern and to provide related footnote disclosures. The new standard is effective for fiscal years, and interim periods within those fiscal years, beginning after December 15, 2017. Early adoption is permitted.

NOTE 3 - CONCENTRATION OF RISK

Accounts Receivable - This Partnership’s accounts receivable are from purchasers of natural gas production. The Partnership sells substantially all of its gas production to a customer who purchases from other Partnerships managed by the Partnership’s MGP. Inherent to the Partnership’s industry is the concentration of natural gas sales to a limited number of customers. This industry concentration has the potential to impact the Partnership’s overall exposure to credit risk in that its customers may be similarly affected by the changes in economic and financial condition, commodity prices and other conditions.

As of June 30, 2016 and December 31, 2015, the Partnership did not record an allowance for doubtful accounts. In making the estimate for receivables that are uncollectible, the MGP considers, among other things, subsequent collections, historical write-offs and overall creditworthiness of the Partnership’s customers. It is reasonably possible the estimate for uncollectable receivables will change periodically. Historically neither MDS nor any of the other Partnerships managed by the Partnership’s MGP, have experienced uncollectable accounts receivable. The Partnership did not incur any losses on accounts receivable for the six months ended June 30, 2016 or 2015.

NOTE 4 - PARTICIPATION IN COSTS AND REVENUES

For the quarter ended June 30, 2016, approximately $129,000 of gross revenue from the sale of natural gas had been received or estimated for approximately 99,000 MCF at an average price of $1.30 per MCF. Royalties for this period were approximately $13,000. In addition approximately $88,700 of gross revenue from the sale of natural gas had been recorded as revenue as a result of the Partnership estimating revenue not yet received, which is 65,000 MCF at an average price of $1.37. These amounts are recorded as accounts receivable net of royalties approximating $79,500. The total estimate of expenses to be deducted from those amounts is approximately $63,300, which are typically transportation, well maintenance and lease operating expense.

For the quarter ended June 30, 2015, approximately $69,400 of gross revenue from the sale of natural gas had been received or estimated for approximately 46,700 MCF at an average price of $1.49 per MCF. In addition approximately $128,000 of gross revenue from the sale of natural gas had been recorded as revenue as a result of the Partnership estimating revenue not yet received, which is 93,400 MCF at an average price of $1.37. These amounts are recorded as accounts receivable net of royalties approximating $14,000. The total estimate of expenses to be deducted from those amounts is approximately $73,000, which are typically transportation, well maintenance and lease operating expenses.

NOTE 5 - PARTNERS’ CAPITAL

The Partnership Agreement provides that MDS shall review the accounts of the Partnership at least monthly to determine whether cash distributions are appropriate and the amount to be distributed, if any.

The Partnership Agreement provides for the enhancement of investor cash distributions if the Partnership does not meet a performance standard defined in the agreement during the first 8 years of operations beginning the earlier of the first full year of operation after all wells begin production or 12 months after the final closing of the Partnership. In general, if the cumulative distributions to the investors is less than 10% of their subscriptions for years 1 through 5 and 7.5% of their subscriptions for years 6 through 8, MDS will subordinate up to 60% of its share, as MGP, of Partnership gross production revenues. As a result of the trend of lower revenue per MCF that the industry is currently experiencing, the MGP has subordinated 60% of it revenue interest beginning in August 2014 and continuing through June 2016. During the six months ended June 30, 2016 and for the year ended December 31, 2015, MGP subordinated $11,633 and $51,002, respectively, which was distributed to investors. The MGP’s share of expenses exceeds its share of revenue, due to the subordination, thus, the MGP is not currently receiving distributions and owes the Partnership approximately $31,000 and $19,500 which is included with Accounts Receivable from Managing General Partner at June 30, 2016 and December 31, 2015 respectively.

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NOTE 6 - TRANSFERS AND PRESENTATIONS

There is no established public trading market for the Partnership’s units and the Partnership does not anticipate that a market for the Partnership’s units will develop. The Partnership’s units may be transferred only in accordance with the provisions of the Partnership Agreement which require:

● the MGP may require an opinion of counsel that registration under applicable federal and state law is not required;

● the transfer not result in materially adverse tax consequences to the Partnership; and

● the transfer must not contravene any terms of the Partnership Agreement.

An assignee of a unit may become a substituted partner only upon meeting the following conditions:

● the assignor gives the assignee the right;

● the assignee pays to the Partnership all costs and expenses incurred in connection with the substitution; and

● the assignee executes and delivers the instruments, which the MGP requires to effect the substitution and to confirm his or her agreement to be bound by the terms of the Partnership Agreement.

A substitute partner is entitled to all of the rights of full ownership of the assigned units, including the right to vote.

Investor Partners may request that the MGP repurchase their units at any time beginning with the fifth anniversary after December 31, 2013 provided that certain conditions are met. The repurchase price is set at the greater of the partner’s share of (i) predominantly 70% of the Partnership’s present worth of future net revenues from the proved reserves as determined under the last reserve report and is reduced by an amount equal to all of the Partnership’s debts or (ii) an amount equal to three times the total amount of distributions paid by the Partnership to the participant during the previous twelve months. The MGP is also permitted to adjust the purchase price under certain conditions for changes occurring after the date of the presentment request. Repurchase requests are fulfilled by the MGP on a first-come, first-served basis and may not exceed 5% of the total units outstanding. The MGP may suspend the presentment feature at any time if it determines that it does not have sufficient cash flow or it is unable to borrow funds on terms it deems reasonable. As of June 30, 2016 the MGP has not repurchased any limited partnership units.

NOTE 7 - NATURAL GAS PROPERTIES

The Partnership is engaged solely in natural gas activities, all of which are located in Armstrong County, Pennsylvania. Costs capitalized for these activities are as follows:

	June 30, 2016		December 31, 2015
Leasehold Costs	$	124,987	$	124,987
Asset Retirement Obligation Asset		642,503		642,503
Development Costs		2,210,505		2,210,505
Natural Gas Properties, successful efforts method		2,977,995		2,977,995
Less: Accumulated Depreciation, Depletion and Amortization		2,657,628		2,581,280
Natural Gas Properties,  net	$	320,367	$	396,715

As of June 30, 2016, all fourteen wells are completed and are revenue producing.

NOTE 8 - ASSET RETIREMENT OBLIGATIONS

Changes in carrying amount of asset retirement obligations associated with natural gas properties are as follows:

	June 30, 2016
December 31, 2015, beginning balance	$	651,870
Accretion expense		2,433
June 30, 2016	$	654,303

During the three months ended June 30, 2015, the Partnership recorded an Asset Retirement Obligation of $131,698 and incurred an Accretion expense of $2,068 for the same period.

The above accretion expense is included in depreciation, depletion and amortization in the Partnership’s statement of operations. As of June 30, 2016 the Partnership’s estimate of the costs to plug it’s wells was $60,000, which has increased from it’s initial assessment at June 30, 2015 of $21,000 due to better data available in regards to plugging of vertical Marcellus wells. The Partnership’s asset retirement obligation is measured using a discount rate of 5.57% and estimated useful lives of 4.8 to 20 years.

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NOTE 9 - RELATED-PARTY ACTIVITIES

MDS, through entities under common ownership, performs well services for the Partnership and is paid at competitive rates for these services. In addition, gathering, transportation and gas marketing is provided by Snyder Brothers, Inc. (“Snyder Brothers”), a wholly-owned subsidiary of Snyder Associated Companies, Inc. Snyder Associated Companies, Inc. is controlled by the father and uncle’s of Michael D. Snyder who is Chief Executive Officer and President of the MGP and the sole shareholder of MDS Associated Companies, Inc., the parent company of the MGP. Mr. Snyder is a minority shareholder of Snyder Associated Companies, Inc. The MGP also receives a fully accountable reimbursement for actual administrative costs. As of June 30, 2016 and 2015 the Partnership paid MDS approximately, $28,800 respectively in each period for well maintenance fees related to the revenue producing wells and this amount is included in the due to managing general partner account on the balance sheet. The Partnership also has an accrued liability of approximately $76,000 and $82,000 due to the MGP as of June 30, 2016 and December 31, 2015, respectively.

NOTE 10 - FAIR VALUE MEASUREMENT

This Partnership's fair value measurements were estimated pursuant to a fair value hierarchy that requires this Partnership to maximize the use of observable inputs and minimize the use of unobservable inputs when measuring fair value. The valuation hierarchy is based upon the transparency of inputs to the valuation of an asset or liability as of the measurement date, giving the highest priority to quoted prices in active markets (Level 1) and the lowest priority to unobservable data (Level 3). In some cases, the inputs used to measure fair value might fall in different levels of the fair value hierarchy. In these cases, the lowest level input that is significant to a fair value measurement in its entirety determines the applicable level in the fair value hierarchy. Assessing the significance of a particular input to the fair value measurement in its entirety requires judgment, considering factors specific to the asset or liability, and may affect the valuation of the assets and liabilities and their placement within the fair value hierarchy levels. The carrying value of the financial instruments included in current assets and current liabilities approximate fair value due to the short-term maturities of these instruments.

The MGP utilizes fair value, on a non-recurring basis, to perform impairment testing on this Partnership's natural gas properties by comparing net capitalized costs, or carrying value, to estimated undiscounted future net cash flows. If net capitalized costs exceed undiscounted future net cash flows, the measurement of impairment is based on estimated fair value and is measured by the amount by which the net capitalized costs exceed their fair value, which is generally determined using the discounted cash flows.

The fair values were determined using the income approach and were based on the expected present values of the future cash flows from proved reserves. Significant level 3 assumptions associated with the calculation of discounted cash flows used in the impairment analysis included estimates of production costs, development expenditures, anticipated production of reserves, appropriate risk – adjusted discount rates and other relevant data.

NOTE 11 - COMMITMENTS AND CONTINGENCIES

Environmental

Due to the nature of the natural gas industry, the Partnership is exposed to environmental risks through the services provided to it by affiliated companies.

The affiliated companies have various policies and procedures to avoid environmental contamination and mitigate the risks from environmental contamination. The affiliated companies conduct periodic reviews to identify changes in their environmental risk profile. Liabilities are accrued when environmental assessments and/or clean-ups are probable and the costs can be reasonably estimated. The MGP is not aware of any environmental claims existing as of June 30, 2016. However, there can be no assurance that current regulatory requirements will not change or unknown past noncompliance with environmental laws will not be discovered on the Partnership’s properties.

Legal

Neither the Partnership nor the MGP are party to any pending legal proceeding that the MGP believes would have a materially adverse effect on the Partnership’s business, financial condition, results of operations or liquidity.

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

The following discussion and analysis should be read together with the Partnership’s unaudited condensed balance sheets and related notes thereto set forth in this Quarterly Report on Form 10-Q. Please also refer to the Partnership’s prospectus dated May 2, 2013 for further details regarding the matters discussed below.

Forward-Looking Statements

When used in this Form 10-Q, the words “believes,” “anticipates,” “expects” and similar expressions are intended to identify forward-looking statements. These risks and uncertainties could cause actual results to differ materially from the results stated or implied in this document. These statements involve a number of risks, uncertainties and other factors that could cause actual results to differ materially from those reflected in any forward-looking statements, as a result of a variety of risks and uncertainties, including those described under “Cautionary Statements Regarding Forward Looking Statements” and “Risk Factors” of the prospectus dated May 2, 2013.

Readers are cautioned not to place undue reliance on these forward-looking statements, which speak only as of the date hereof. The Partnership undertakes no obligation to publicly release the results of any revisions to forward-looking statements which the Partnership may make to reflect events or circumstances after the date of this Form 10-Q or to reflect the occurrence of unanticipated events.

Overview

Business of the Partnership, the Managing General Partner and Certain Relationships

The Partnership drilled development wells which means a well drilled within the proved area of a natural gas reservoir to the depth of a stratigraphic horizon known to be productive. Only vertical natural gas wells in the Marcellus Shale area in western Pennsylvania were drilled. The Partnership Agreement governs the rights and obligations of the partners. The investment return will depend solely on the operations and success or lack of success of the Partnership.

The Partnership has been formed as a limited partnership under the Delaware Revised Uniform Limited Partnership Act. 1,508.53 units have been sold for an aggregate price of $15,001,000.

The MGP of the Partnership is MDS, a Pennsylvania limited liability company which also serves as MGP of ten private drilling partnerships, in the aggregate.

The gas marketing is handled by Snyder Brothers. The MGP receives fees and profits in connection with the Partnership’s business.

Governance

The Partnership has no executive officers and currently does not have any directors. Because the Partnership itself does not employ any persons, the MGP has determined that the Partnership will rely on a Code of Business Conduct and Ethics adopted by the MGP that applies to the executive officers, employees and other persons performing services for the MGP.

The MGP, on behalf of the investor members, is currently evaluating the deregistering of the Partnership in an effort to reduce direct costs to the Partnership.

Conflicts of Interest

Conflicts of interest are inherent in natural gas and oil partnerships involving non-industry investors because the transactions are entered into without arms’ length negotiation. The interests of the investors and those of the MGP and its affiliates may be inconsistent in some respects, and the MGP’s actions may not be the most advantageous to investors.

The Partnership does not directly employ any of the persons responsible for its management or operation. Rather, the personnel of the MGP manage and operate the Partnership’s business, and they will also spend a substantial amount of time managing the business and affairs of the MGP’s other affiliates, which creates a conflict regarding the allocation of their time between the Partnership’s business and affairs and the MGP’s other business interests. In this regard, the Partnership’s policies and procedures for reviewing, approving or ratifying related party transactions with the MGP are set forth in the partnership agreement. Due to the family relationship between Mr. Snyder and the principals and certain executive officers of Snyder Brothers, transactions between Snyder Brothers and its affiliates and the Partnership are subject to similar restrictions and conditions as transactions between the Partnership and affiliates of the MGP.

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Natural Gas Sales

The Partnership currently uses the “net-back” method of accounting for arrangements related to its commodity sales. This Partnership sells commodities at the wellhead and collects a price and recognizes revenues based on the wellhead sales price as transportation costs downstream of the wellhead are incurred by the purchaser and reflected in the wellhead price.

As of June 30, 2016, all of the aggregate capital from our offering of the units has been expended; fourteen wells have been completed and are producing revenue. As of June 30, 2016, approximately $167,000 of gross revenue from the sale of natural gas had been received for approximately 138,000 MCF of production with an average realized price of $1.21 per MCF. In addition approximately $88,700 of gross revenue from the sale of natural gas had been recorded as revenue as a result of the Partnership estimating revenue from production for which the proceeds of the sale of the natural gas had not yet been received and those amounts are recorded as accounts receivable. The average realizable price per MCF for this estimated revenue is $1.36 per MCF for estimated production of 65,000 MCF of production.

Natural gas pricing is predominately driven by the supply and demand in the physical and financial markets. Natural gas is sold under various purchase contracts with monthly pricing provisions based on NYMEX pricing, adjusted for differentials. Natural gas prices vary by locality, depending upon the distance to markets, availability of pipeline capacity and supply and demand relationships in that region. The Marcellus shale region, where this production is derived from, has a negative price differential making the prices we are realizing lesser than NYMEX.

For the six month period ended June 30, 2016 compared to the same period for 2015 natural gas production decreased approximately 19% as a result of the Partnership wells depleting inline with normal depletion curves during the six month period ended June 30, 2016. Additionally, there was a decrease in the average price per MCF for the six month period ended June 30, 2016. The average price per MCF for the six months ended June 30, 2016 was approximately $1.26 compared to $1.79 per MCF for the six months ended June 30, 2015.

For the three month period ended June 30, 2016 compared to the same period for 2015 natural gas production decreased approximately 30%, due to the normal decline associated with these wells. Additionally, there was a slight decrease in the average price per MCF for the three month period ended June 30, 2016. The average price per MCF for the three months ended June 30, 2016 was approximately $1.31 compared to $1.41 per MCF for the same period in 2015.

During the three months ended June 30, 2016, the Partnership recognized approximately $129,000 of gross revenue from the sale of approximately 99,000 MCF’s as compared to approximately $198,000 of gross revenue from the production of 140,000 MCF’s of production in the three month period ended June 30, 2015. The three month gross revenues from June 30, 2016 compared to the same period in 2015 decreased approximately 35% while the average price per MCF decreased 7%.

Natural Gas Production Costs

Generally, natural gas production costs vary with changes in total natural gas production volumes. In addition, general field services and all other costs vary and can fluctuate based on services required, but are expected to increase as wells age and require more extensive repair and maintenance. These costs include water hauling and disposal, equipment repairs and maintenance, snow removal, environmental compliance and remediation and service rig workovers. Production costs for the three months ended June 30, 2016 were approximately $78,200, compared to the same period in 2015 natural gas production costs decreased approximately $7,800. A factor in the decrease of natural gas production cost was associated with some of the wells being classified as stripper wells and thus the impact fees that were being paid on said wells has stopped being assessed during 2016.

Natural gas production costs for the six months ended June 30, 2016 compared to the same period in 2015 decreased approximately $51,000. A factor in this decrease is similar as to what is discussed above and in a direct result of these wells being classified as stripper wells and not being required to submit impact fee payments.

Depreciation, Depletion and Amortization

Depreciation, depletion and amortization (DD&A) expense was approximately $79,000 for the six months ended June 30, 2016 from production of 202,800 MCFs, compared to the same period in 2015 which has an expense of $344,000 from production of 272,600 MCFs. The DD&A expense rate per MCF is estimated to be $0.39 for 2016 as compared to $1.26 for 2015. The decrease is due to the impairment charge recognized during the third and fourth quarters of 2015.

DD&A expense related to natural gas properties is directly related to proven reserves and production volumes. DD&A expense decreased approximately $149,000 for the three months ended June 30, 2016 compared to the three months ended June 30, 2015 due to a decrease in production volumes, and the decreased DD&A rate.

10

Direct costs - general and administrative

Direct costs slightly increased for the three month period ended June 30, 2016 compared to the same period in 2015. Direct cost for the three month period ended June 30, 2016 was approximately $29,000. Direct costs are professional fees and other miscellaneous administrative expenses of the Partnership.

Direct costs for the six month period ended June 30, 2016 compared to the same period in 2015 increased $6,000 due to an increase in professional fees and other miscellaneous administrative expenses of the Partnership.

Financial Condition, Liquidity and Capital Resources

The Partnership’s primary source of liquidity has been cash flows from operating activities. Fluctuations in this Partnership’s operating cash flows are substantially driven by changes in commodity prices and sales volumes. This source of cash has been primarily used to fund this Partnership’s operating costs, direct cost-general and administrative, capital program and distributions to the investors and the MGP.

The Partnership’s future operations are expected to be conducted with available funds and revenues generated from natural gas production activities. Natural gas production from existing properties is generally expected to continue a gradual decline in the rate of production over the remaining life of the wells. Any additional funds, if required, will be obtained from production revenues, advances or waiving/suspending of fees from the MGP.

Working Deficit

At June 30, 2016, the Partnership had working deficit of $(48,400), compared to working deficit of $(17,000) at December 31, 2015. The decrease of $31,400 between June 30, 2016 and December 31, 2015 was primarily due to an increase of professional fees, impact fees and well maintenance expenses for the three months ended June 30, 2016. At the current time, the MGP has permitted the Partnership to not reimburse the MGP for certain expenses until market conditions become more favorable that amounted approximately $120,000 and $57,000 at June 30, 2016 and December 31, 2015 respectively. Should the MGP require payment before that time the Partnership may be unable to do so. In addition, the MGP has informed the Partnership that it may be able to borrow funds from the MGP on a limited basis to sustain its operating activities.

The MGP has subordinated distributions thus creating and accounts receivable balance on the balance sheet, this accounts receivable balance will be relieved once the subordination period ends pursuant to the Private Placement Memorandum or an increase is pricing is recognized.

Cash Flows

Operating Activities

The Partnership's cash flows from operating activities in the second quarter of 2016 were primarily impacted by commodity prices, operating costs, professional fees and reduced production.

Net cash flows from operating activities were $44,050 for the six months ended June 30, 2016 compared to $199,534 for the comparable period in 2015. The decrease in cash from operating activities was primarily due to a decrease in natural gas pricing and production.

Financing Activities

The Partnership distributed $30,684 for the six months ended June 30, 2016 for the comparable period in 2015 the Partnership distributed $199,876. During the six months ended June 30, 2016 and 2015, the MGP subordinated $11,633 and $5,012, respectively, which was distributed to investors.

Critical Accounting Policies

The discussion and analysis of the Partnership’s financial condition is based upon the Partnership’s condensed balance sheets, which have been prepared in accordance with U.S. GAAP. The Partnership will base its estimates on historical experience and on various other assumptions that it believes are reasonable under the circumstances, and the results of which form the basis for making judgments about the carrying values of assets and liabilities that are not readily apparent from other sources. The Partnership will evaluate its estimates on an on-going basis.

Actual results may differ from these estimates under different assumptions or conditions. A discussion of significant accounting policies the Partnership has adopted and followed in the preparation of its financial statements is included within “Notes to Financial Statements” in Part I, Item 1, “Financial Statements” in this quarterly report and in its Form 10-K dated March 14, 2016.

11

ITEM 4.          CONTROLS AND PROCEDURES

Evaluation of Disclosure Controls and Procedures

The MGP on behalf of the Partnership, with the participation of the MGP’s management, including the Chief Executive Officer and President and the Chief Financial Officer, evaluated the effectiveness of the Partnership’s disclosure controls and procedures as of June 30, 2016. The term “disclosure controls and procedures,” as defined in Rules 13a-15(e) and 15d-15(e) under the Securities Exchange Act of 1934, as amended (the “Exchange Act”), means controls and other procedures of a company that are designed to ensure that information required to be disclosed by a company in the reports that it files or submits under the Exchange Act is recorded, processed, summarized and reported, within the time periods specified in the SEC’s rules and forms. Disclosure controls and procedures include, without limitation, controls and procedures designed to ensure that information required to be disclosed by a company in the reports that it files or submits under the Exchange Act is accumulated and communicated to the Partnership’s management, including its principal executive and principal financial officers, as appropriate to allow timely decisions regarding required disclosure. Management recognizes that any controls and procedures, no matter how well designed and operated, can provide only reasonable assurance of achieving their objectives and management necessarily applies its judgment in evaluating the cost benefit relationship of possible controls and procedures.

Under the supervision of the MGP’s Chief Executive Officer and President, and Chief Financial Officer, the MGP has carried out an evaluation of the effectiveness of its disclosure controls and procedures as of the end of the period covered by this report. Based upon that evaluation, the MGP’s management, including the Chief Executive Officer and President and the Chief Financial Officer concluded that, at June 30, 2016, the Partnership’s disclosure controls and procedures were effective.

Changes in Internal Control over Financial Reporting

There have been no changes in the Partnership’s internal control over financial reporting for the Partnership during the three months ended June 30, 2016 that have materially affected, or are reasonably likely to materially affect, the Partnership’s internal control over financial reporting.

As an emerging growth company, the Partnership is exempt from the requirement to obtain an attestation report from the Partnership’s independent registered public accounting firm on the assessment of the Partnership’s internal controls pursuant to the Sarbanes-Oxley Act of 2002 until 2018, or such time that the Partnership no longer qualifies as an emerging growth company in accordance with the Jumpstart Our Business Startups Act of 2012.

PART II OTHER INFORMATION

ITEM 1.          LEGAL PROCEEDINGS

The MGP is not aware of any legal proceedings filed against the Partnership.

Affiliates of the MGP are party to various routine legal proceedings arising in the ordinary course of their collective business. 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 or Partnership’s financial condition or results of operations.

ITEM 2.          UNREGISTERED SALES OF EQUITY SECURITIES AND USE OF PROCEEDS

Not applicable.

ITEM 3.          DEFAULTS UPON SENIOR SECURITIES

Not applicable.

ITEM 4.          MINE SAFETY DISCLOSURES.

Not applicable.

ITEM 5.          OTHER INFORMATION

None.

12

ITEM 6.          EXHIBITS

EXHIBIT INDEX

		Incorporated by Reference
Exhibit No.	Description	Form	SEC File Number	Exhibit	Filing Date	Filed Herewith
4.2	Certificate of Limited Partnership for MDS Energy Public 2013-A LP	10-Q	333-181993-02	4.2	6/10/2013
31.1	Rule 13(a)-14(a) Certification of Principal Executive Officer.					Filed herewith
31.2	Rule 13(a)-14(a) Certification of Principal Financial Officer and Principal Accounting Officer.					Filed herewith
32	Section 1350 Certification of Principal Executive Officer and Principal Financial Officer and Principal Accounting Officer.					Filed herewith
101.INS	XBRL Instance document					Filed herewith
101.SCH	XBRL Taxonomy Extension Schema Document					Filed herewith
101.CAL	XBRL Taxonomy Extension Calculation Linkbase Document					Filed herewith
101.DEF	XBRL Taxonomy Extension Definition Linkbase Document					Filed herewith
101.LAB	XBRL Taxonomy Extension Label Linkbase Document					Filed herewith
101.PRE	XBRL Taxonomy Extension Presentation Linkbase Document					Filed herewith

Incorporate all by reference into the document rather than attached.

13

SIGNATURES

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

	MDS ENERGY PUBLIC 2013-A LP
	By:	MDS Energy Development, LLC, its Managing General Partner
Date: August 12, 2016	By:	/s/ Michael D. Snyder
		Michael D. Snyder, Chief Executive Officer and President

In accordance with the Exchange Act, this report has been signed by the following persons on behalf of the registrant and in the capacities and on the dates indicated.

Date: August 12, 2016	By:	/s/ Mark H. Axel
		Mark H. Axel, Chief Financial Officer and Treasurer

14

EX-31.1

Exhibit 31.1

CERTIFICATION

I, Michael D. Snyder, certify that:

1. I have reviewed this Quarterly Report on Form 10-Q of the MDS Energy Public 2013-A LP;

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

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

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

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

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

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

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

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

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

Date: August 12, 2016

MDS ENERGY PUBLIC 2013-A LP

By: MDS Energy Development, LLC, its Managing General Partner

/s/ Michael D. Snyder

Michael D. Snyder, Chief Executive Officer and President

(Principal Executive Officer)

EX-31.2

Exhibit 31.2

CERTIFICATION

I, Mark H. Axel, certify that:

1. I have reviewed this Quarterly Report on Form 10-Q of the MDS Energy Public 2013-A LP;

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

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

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

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

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

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

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

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

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

Date: August 12, 2016

MDS ENERGY PUBLIC 2013-A LP

By: MDS Energy Development, LLC, its Managing General Partner

/s/ Mark H. Axel

Mark H. Axel, Chief Financial Officer and Treasurer

(Principal Financial Officer and Principal Accounting Officer)

EX-32

Exhibit 32

CERTIFICATION

In connection with the Quarterly Report of MDS Energy Public 2013-A LP on Form 10-Q for the period ended June 30, 2016, as filed with the Securities and Exchange Commission on the date hereof (the “Report”), the undersigned certify pursuant to § 906 of the Sarbanes-Oxley Act of 2002, that:

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

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

	MDS ENERGY PUBLIC 2013-A LP
	By: MDS Energy Development, LLC, its Managing General Partner
August 12, 2016	/s/ Michael D. Snyder
	Michael D. Snyder, Chief Executive Officer and President
	(Principal Executive Officer)
August 12, 2016	/s/ Mark H. Axel
	Mark H. Axel, Chief Financial Officer and Treasurer
	(Principal Financial Officer and Principal Accounting Officer)

A signed original of this written statement required by Section 906, or other document authenticating, acknowledging, or otherwise adopting the signature that appears in typed form within the electronic version of this written statement required by Section 906, has been provided to MDS Energy Public 2013-A LP and will be retained by MDS Energy Public 2013-A LP and furnished to the Securities and Exchange Commission or its staff upon request.

XML

Document and Entity Information	6 Months Ended
	Jun. 30, 2016 shares
Entity Registrant Name	MDS ENERGY PUBLIC 2013-A LP
Entity Central Index Key	0001551390
Trading Symbol	mdse
Current Fiscal Year End Date	--12-31
Entity Filer Category	Smaller Reporting Company
Document Type	10-Q
Document Period End Date	Jun. 30, 2016
Amendment Flag	false
Document Fiscal Year Focus	2016
Document Fiscal Period Focus	Q2
Limited partnership interest
Entity Partnership Units Outstanding	1,508.53
General partnership interest
Entity Partnership Units Outstanding

XML

Condensed Balance Sheets - USD ($)	Jun. 30, 2016	Dec. 31, 2015
Current Assets
Cash and Cash Equivalents	$ 37,074	$ 23,707
Accounts Receivable Related Party	79,545	78,760
Accounts Receivable Managing General Partner	31,143	19,510
Total Current Assets	147,762	121,977
Natural Gas Properties, net	320,367	396,715
Total Assets	468,129	518,692
Liabilities and Partners' Deficit
Accrued Expenses	76,082	82,235
Due to Managing General Partner	28,000	28,000
Accrued Expenses - Related Party	92,066	28,800
Total Current Liabilities	196,148	139,035
Long-term Asset Retirement Obligations	654,303	651,870
Partners' Deficit	(382,322)	(272,213)
Total Liabilities and Partners' Deficit	$ 468,129	$ 518,692

XML

Condensed Statements of Operations (Unaudited) - USD ($)	3 Months Ended		6 Months Ended
	Jun. 30, 2016	Jun. 30, 2015	Jun. 30, 2016	Jun. 30, 2015
Income Statement [Abstract]
Natural Gas Revenue, net	$ 118,264	$ 189,400	$ 233,511	$ 396,089
Expenses
Gathering Expense	40,725	49,672	82,024	87,614
Well Maintenance	36,441	36,376	75,655	83,669
Depreciation, Depletion and Amortization Expense	29,051	178,355	78,781	345,641
Impact Fee	6,315	26,041	32,356	77,414
Professional Fees	29,056	25,000	55,753	50,000
Total Expenses	141,588	315,444	324,569	644,338
Net Loss	$ (23,324)	$ (126,044)	$ (91,058)	$ (248,249)

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Condensed Statements of Partners' Equity (Deficit) (Unaudited) - USD ($)	Investor Partners	Managing General Partner		Total
Balance at Dec. 31, 2014	$ 7,529,923	$ (1,094,385)		$ 6,435,538
Increase (Decrease) in Partners' Capital [Roll Forward]
(Distributions) Subordination	(199,876)	5,012	[1]	(194,864)
Net Loss	(208,231)	(40,018)		(248,249)
Balance at Jun. 30, 2015	7,121,816	(1,129,391)		5,992,425
Balance at Dec. 31, 2015	1,848,004	(2,120,217)		(272,213)
Increase (Decrease) in Partners' Capital [Roll Forward]
(Distributions) Subordination	(30,684)	11,633	[1]	(19,051)
Net Loss	(76,447)	(14,611)		(91,058)
Balance at Jun. 30, 2016	$ 1,740,873	$ (2,123,195)		$ (382,322)

[1] due to subordination

XML

Condensed Statements of Cash Flows (Unaudited) - USD ($)	6 Months Ended
	Jun. 30, 2016	Jun. 30, 2015
Cash flows from Operating activities
Net Loss	$ (91,058)	$ (248,249)
Adjustments to reconcile net loss to cash provided by operating activities
Depreciation, Depletion and Amortization	78,781	345,641
Total adjustments to net loss to reconcile to net cash provided by operating activities	(12,277)	97,392
Changes in assets and liabilities
Accounts Receivable and Due from Managing General Partner	(785)	101,007
Accrued Expenses	57,113	6,147
Net cash provided by operating activities	44,051	204,546
Cash flows from financing activities
Distributions	(30,684)	(199,876)
Net change in cash and cash equivalents	13,367	4,670
Cash and cash equivalents at beginning of period	23,707	18,264
Cash and cash equivalents at end of period	37,074	22,934
Supplemental Schedule of Non-Cash Financing Activities:
During the six months ended June 30, 2016 and 2015 the MGP subordinated it's distributions of $11,633 and $5,012 respectively.	$ 11,633	$ 5,012

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ORGANIZATION AND NATURE OF OPERATIONS

6 Months Ended

Jun. 30, 2016

Organization and Nature Of Operations [Abstract]

ORGANIZATION AND NATURE OF OPERATIONS

NOTE 1 - ORGANIZATION AND NATURE OF OPERATIONS

On May 3, 2012 (date of inception), MDS Energy Public 2013-A LP (Partnership), a Delaware limited partnership, was formed for the purpose of drilling developmental natural gas wells. The Partnership has a maximum 50-year term, although the Partnership intends to terminate when all of the wells invested in by the Partnership become uneconomical to continue to operate, which may be approximately 15 years or longer. The Partnership was formed by MDS Energy Development, LLC (MDS), a related party, as the Managing General Partner (MGP) and M/D Gas, Inc. (M/D), a related party. In accordance with the terms of the limited partnership agreement, the MGP is authorized to manage all activities of the Partnership and initiates and completes substantially all transactions.

In our opinion, the accompanying condensed financial statements contain all adjustments necessary for a fair presentation of the Partnership’s financial statements for interim periods in accordance with accounting principles generally accepted in the United States of America (U.S. GAAP) and with the instructions to Form 10-Q and Article 10 of Regulation S-X of the SEC. Accordingly, pursuant to such rules and regulations, certain notes and other financial information included in audited financial statements have been condensed or omitted. The information presented in this Quarterly Report on Form 10-Q should be read in conjunction with the Partnership’s audited financial statements and notes thereto included in its 2015 Form 10-K. The results of operations for the interim periods are not necessarily indicative of the results of operations to be expected for the full year.

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SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES

6 Months Ended

Jun. 30, 2016

Accounting Policies [Abstract]

SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES

NOTE 2 - SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES

Proved Property Impairment - The Partnership assesses its producing natural gas properties for possible impairment, upon a triggering event, by comparing net capitalized costs to estimated undiscounted future net cash flows on a well by well basis using estimated production based upon prices at which the Partnership reasonably estimates the commodities to be sold.  The estimates of future prices may differ from current market prices of natural gas.  Certain events, including but not limited to, downward revisions in estimates to the Partnership’s reserve quantities, expectations of falling commodity prices or rising operating costs, could result in a triggering event and, therefore, a possible impairment of the Partnership’s proved natural gas properties.  If net capitalized costs exceed undiscounted future net cash flows, the measurement of impairment is based on estimated fair value utilizing a future discounted cash flows analysis, which is predominantly unobservable data or inputs, and is measured by the amount by which the net capitalized costs exceed their fair value.  Estimated undiscounted future net cash flows are determined using prices from the forward price curve at the measurement date.  Estimated discounted future net cash flows are determined utilizing a risk adjusted discount rate that is based on rates utilized by market participants that are commensurate with the risks inherent in the development of the underlying natural gas reserves.  Due to the decrease in natural gas prices, as further discussed in Note 4, the Partnership reviewed its proved natural gas properties for impairment at June 30, 2016 and did not recognize an impairment charge for the second quarter 2016.  The Partnership has an accumulated impairment charge of proved natural gas properties of approximately $11,810,700 as of June 30, 2016 and December 31, 2015.

Asset Retirement Obligations - The Partnership applies the provisions of “Accounting for Asset Retirement Obligations” and “Accounting for Conditional Asset Retirement Obligations” and accounts for asset retirement obligations by recording the fair value of its plugging and abandonment obligations when incurred, which is at the time the well is completely drilled. Upon initial recognition of an asset retirement obligation, the Partnership increases the carrying amount of the long-lived asset by the same amount as the liability. Over time, the asset retirement obligations are accreted, over the estimated life of the related asset, for the change in their present value. The initial capitalized costs are depleted over the useful lives of the related assets, through charges to depreciation, depletion and amortization. If the fair value of the estimated asset retirement obligation changes, an adjustment is recorded to both the asset retirement obligation and the asset retirement cost. Revisions in estimated liabilities can result from revisions of estimated inflation rates, escalating retirement costs and changes in the estimated timing of settling asset retirement obligations.

Recent Accounting Pronouncements - In May 2014, the FASB and the International Accounting Standards Board issued their converged standard on revenue recognition that provides a single, comprehensive model that entities will apply to determine the measurement of revenue and timing of when it is recognized. The underlying principle is that an entity will recognize revenue to depict the transfer of goods or services to customers at an amount that the entity expects to be entitled to in exchange for those goods or services. The standard outlines a five-step approach to apply the underlying principle: (a) identify the contract with the customer, (b) identify the separate performance obligations in the contract, (c) determine the transaction price, (d) allocate the transaction price to separate performance obligations and (e) recognize revenue when (or as) each performance obligation is satisfied. The revenue standard is effective for annual reporting periods beginning after December 15, 2017, including interim periods within that reporting period, and can be adopted under the full retrospective method or simplified transition method. Early adoption is not permitted. The Partnership plans to adopt the revenue standard beginning January 1, 2018 and is currently evaluating the impact that these changes will have on our condensed financial statements.

In August 2014, the FASB issued Accounting Standards Update (ASU) No. 2014-15, Disclosures of Uncertainties About an Entity’s Ability to Continue as a Going Concern, new guidance related to the disclosures around going concern. The new standard provides guidance around management’s responsibility to evaluate whether there is substantial doubt about an entity’s ability to continue as a going concern and to provide related footnote disclosures. The new standard is effective for fiscal years, and interim periods within those fiscal years, beginning after December 15, 2017. Early adoption is permitted.

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CONCENTRATION OF RISK

6 Months Ended

Jun. 30, 2016

Risks and Uncertainties [Abstract]

CONCENTRATION OF RISK

NOTE 3 - CONCENTRATION OF RISK

Accounts Receivable - This Partnership’s accounts receivable are from purchasers of natural gas production. The Partnership sells substantially all of its gas production to a customer who purchases from other Partnerships managed by the Partnership’s MGP. Inherent to the Partnership’s industry is the concentration of natural gas sales to a limited number of customers. This industry concentration has the potential to impact the Partnership’s overall exposure to credit risk in that its customers may be similarly affected by the changes in economic and financial condition, commodity prices and other conditions.

As of June 30, 2016 and December 31, 2015, the Partnership did not record an allowance for doubtful accounts. In making the estimate for receivables that are uncollectible, the MGP considers, among other things, subsequent collections, historical write-offs and overall creditworthiness of the Partnership’s customers. It is reasonably possible the estimate for uncollectable receivables will change periodically. Historically neither MDS nor any of the other Partnerships managed by the Partnership’s MGP, have experienced uncollectable accounts receivable. The Partnership did not incur any losses on accounts receivable for the six months ended June 30, 2016 or 2015.

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PARTICIPATION IN COSTS AND REVENUES

6 Months Ended

Jun. 30, 2016

Partners Participation In Costs and Revenues [Abstract]

PARTICIPATION IN COSTS AND REVENUES

NOTE 4 - PARTICIPATION IN COSTS AND REVENUES

For the quarter ended June 30, 2016, approximately $129,000 of gross revenue from the sale of natural gas had been received or estimated for approximately 99,000 MCF at an average price of $1.30 per MCF. Royalties for this period were approximately $13,000. In addition approximately $88,700 of gross revenue from the sale of natural gas had been recorded as revenue as a result of the Partnership estimating revenue not yet received, which is 65,000 MCF at an average price of $1.37. These amounts are recorded as accounts receivable net of royalties approximating $79,500. The total estimate of expenses to be deducted from those amounts is approximately $63,300, which are typically transportation, well maintenance and lease operating expense.

For the quarter ended June 30, 2015, approximately $69,400 of gross revenue from the sale of natural gas had been received or estimated for approximately 46,700 MCF at an average price of $1.49 per MCF. In addition approximately $128,000 of gross revenue from the sale of natural gas had been recorded as revenue as a result of the Partnership estimating revenue not yet received, which is 93,400 MCF at an average price of $1.37. These amounts are recorded as accounts receivable net of royalties approximating $14,000. The total estimate of expenses to be deducted from those amounts is approximately $73,000, which are typically transportation, well maintenance and lease operating expenses.

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PARTNERS CAPITAL

6 Months Ended

Jun. 30, 2016

Partners' Capital Notes [Abstract]

PARTNERS CAPITAL

NOTE 5 - PARTNERS’ CAPITAL

The Partnership Agreement provides that MDS shall review the accounts of the Partnership at least monthly to determine whether cash distributions are appropriate and the amount to be distributed, if any.

The Partnership Agreement provides for the enhancement of investor cash distributions if the Partnership does not meet a performance standard defined in the agreement during the first 8 years of operations beginning the earlier of the first full year of operation after all wells begin production or 12 months after the final closing of the Partnership. In general, if the cumulative distributions to the investors is less than 10% of their subscriptions for years 1 through 5 and 7.5% of their subscriptions for years 6 through 8, MDS will subordinate up to 60% of its share, as MGP, of Partnership gross production revenues. As a result of the trend of lower revenue per MCF that the industry is currently experiencing, the MGP has subordinated 60% of it revenue interest beginning in August 2014 and continuing through June 2016. During the six months ended June 30, 2016 and for the year ended December 31, 2015, MGP subordinated $11,633 and $51,002, respectively, which was distributed to investors. The MGP’s share of expenses exceeds its share of revenue, due to the subordination, thus, the MGP is not currently receiving distributions and owes the Partnership approximately $31,000 and $19,500 which is included with Accounts Receivable from Managing General Partner at June 30, 2016 and December 31, 2015 respectively.

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TRANSFERS AND PRESENTATIONS

6 Months Ended

Jun. 30, 2016

Transfers And Presentation [Abstract]

TRANSFERS AND PRESENTATIONS

NOTE 6 - TRANSFERS AND PRESENTATIONS

There is no established public trading market for the Partnership’s units and the Partnership does not anticipate that a market for the Partnership’s units will develop. The Partnership’s units may be transferred only in accordance with the provisions of the Partnership Agreement which require:

● the MGP may require an opinion of counsel that registration under applicable federal and state law is not required;

● the transfer not result in materially adverse tax consequences to the Partnership; and

● the transfer must not contravene any terms of the Partnership Agreement.

An assignee of a unit may become a substituted partner only upon meeting the following conditions:

● the assignor gives the assignee the right;

● the assignee pays to the Partnership all costs and expenses incurred in connection with the substitution; and

● the assignee executes and delivers the instruments, which the MGP requires to effect the substitution and to confirm his or her agreement to be bound by the terms of the Partnership Agreement.

A substitute partner is entitled to all of the rights of full ownership of the assigned units, including the right to vote.

Investor Partners may request that the MGP repurchase their units at any time beginning with the fifth anniversary after December 31, 2013 provided that certain conditions are met. The repurchase price is set at the greater of the partner’s share of (i) predominantly 70% of the Partnership’s present worth of future net revenues from the proved reserves as determined under the last reserve report and is reduced by an amount equal to all of the Partnership’s debts or (ii) an amount equal to three times the total amount of distributions paid by the Partnership to the participant during the previous twelve months. The MGP is also permitted to adjust the purchase price under certain conditions for changes occurring after the date of the presentment request. Repurchase requests are fulfilled by the MGP on a first-come, first-served basis and may not exceed 5% of the total units outstanding. The MGP may suspend the presentment feature at any time if it determines that it does not have sufficient cash flow or it is unable to borrow funds on terms it deems reasonable. As of June 30, 2016 the MGP has not repurchased any limited partnership units.

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NATURAL GAS PROPERTIES

6 Months Ended

Jun. 30, 2016

Oil and Gas Property [Abstract]

NATURAL GAS PROPERTIES

NOTE 7 - NATURAL GAS PROPERTIES

The Partnership is engaged solely in natural gas activities, all of which are located in Armstrong County, Pennsylvania. Costs capitalized for these activities are as follows:

	June 30, 2016		December 31, 2015
Leasehold Costs	$	124,987	$	124,987
Asset Retirement Obligation Asset		642,503		642,503
Development Costs		2,210,505		2,210,505
Natural Gas Properties, successful efforts method		2,977,995		2,977,995
Less: Accumulated Depreciation, Depletion and Amortization		2,657,628		2,581,280
Natural Gas Properties,  net	$	320,367	$	396,715

As of June 30, 2016, all fourteen wells are completed and are revenue producing.

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ASSET RETIREMENT OBLIGATION

6 Months Ended

Jun. 30, 2016

Asset Retirement Obligation Disclosure [Abstract]

ASSET RETIREMENT OBLIGATION

NOTE 8 - ASSET RETIREMENT OBLIGATIONS

Changes in carrying amount of asset retirement obligations associated with natural gas properties are as follows:

	June 30, 2016
December 31, 2015, beginning balance	$	651,870
Accretion expense		2,433
June 30, 2016	$	654,303

During the three months ended June 30, 2015, the Partnership recorded an Asset Retirement Obligation of $131,698 and incurred an Accretion expense of $2,068 for the same period.

The above accretion expense is included in depreciation, depletion and amortization in the Partnership’s statement of operations. As of June 30, 2016 the Partnership’s estimate of the costs to plug it’s wells was $60,000, which has increased from it’s initial assessment at June 30, 2015 of $21,000 due to better data available in regards to plugging of vertical Marcellus wells. The Partnership’s asset retirement obligation is measured using a discount rate of 5.57% and estimated useful lives of 4.8 to 20 years.

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RELATED-PARTY ACTIVITIES

6 Months Ended

Jun. 30, 2016

Related Party Transactions [Abstract]

RELATED-PARTY ACTIVITIES

NOTE 9 - RELATED-PARTY ACTIVITIES

MDS, through entities under common ownership, performs well services for the Partnership and is paid at competitive rates for these services. In addition, gathering, transportation and gas marketing is provided by Snyder Brothers, Inc. (“Snyder Brothers”), a wholly-owned subsidiary of Snyder Associated Companies, Inc. Snyder Associated Companies, Inc. is controlled by the father and uncle’s of Michael D. Snyder who is Chief Executive Officer and President of the MGP and the sole shareholder of MDS Associated Companies, Inc., the parent company of the MGP. Mr. Snyder is a minority shareholder of Snyder Associated Companies, Inc. The MGP also receives a fully accountable reimbursement for actual administrative costs. As of June 30, 2016 and 2015 the Partnership paid MDS approximately, $28,800 respectively in each period for well maintenance fees related to the revenue producing wells and this amount is included in the due to managing general partner account on the balance sheet. The Partnership also has an accrued liability of approximately $76,000 and $82,000 due to the MGP as of June 30, 2016 and December 31, 2015, respectively.

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FAIR VALUE MEASUREMENT

6 Months Ended

Jun. 30, 2016

Fair Value Disclosures [Abstract]

FAIR VALUE MEASUREMENT

NOTE 10 - FAIR VALUE MEASUREMENT

This Partnership's fair value measurements were estimated pursuant to a fair value hierarchy that requires this Partnership to maximize the use of observable inputs and minimize the use of unobservable inputs when measuring fair value. The valuation hierarchy is based upon the transparency of inputs to the valuation of an asset or liability as of the measurement date, giving the highest priority to quoted prices in active markets (Level 1) and the lowest priority to unobservable data (Level 3). In some cases, the inputs used to measure fair value might fall in different levels of the fair value hierarchy. In these cases, the lowest level input that is significant to a fair value measurement in its entirety determines the applicable level in the fair value hierarchy. Assessing the significance of a particular input to the fair value measurement in its entirety requires judgment, considering factors specific to the asset or liability, and may affect the valuation of the assets and liabilities and their placement within the fair value hierarchy levels. The carrying value of the financial instruments included in current assets and current liabilities approximate fair value due to the short-term maturities of these instruments.

The MGP utilizes fair value, on a non-recurring basis, to perform impairment testing on this Partnership's natural gas properties by comparing net capitalized costs, or carrying value, to estimated undiscounted future net cash flows. If net capitalized costs exceed undiscounted future net cash flows, the measurement of impairment is based on estimated fair value and is measured by the amount by which the net capitalized costs exceed their fair value, which is generally determined using the discounted cash flows.

The fair values were determined using the income approach and were based on the expected present values of the future cash flows from proved reserves. Significant level 3 assumptions associated with the calculation of discounted cash flows used in the impairment analysis included estimates of production costs, development expenditures, anticipated production of reserves, appropriate risk – adjusted discount rates and other relevant data.

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COMMITMENTS AND CONTINGENCIES

6 Months Ended

Jun. 30, 2016

Commitments and Contingencies Disclosure [Abstract]

COMMITMENTS AND CONTINGENCIES

NOTE 11 - COMMITMENTS AND CONTINGENCIES

Environmental

Due to the nature of the natural gas industry, the Partnership is exposed to environmental risks through the services provided to it by affiliated companies.

The affiliated companies have various policies and procedures to avoid environmental contamination and mitigate the risks from environmental contamination. The affiliated companies conduct periodic reviews to identify changes in their environmental risk profile. Liabilities are accrued when environmental assessments and/or clean-ups are probable and the costs can be reasonably estimated. The MGP is not aware of any environmental claims existing as of June 30, 2016. However, there can be no assurance that current regulatory requirements will not change or unknown past noncompliance with environmental laws will not be discovered on the Partnership’s properties.

Legal

Neither the Partnership nor the MGP are party to any pending legal proceeding that the MGP believes would have a materially adverse effect on the Partnership’s business, financial condition, results of operations or liquidity.

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SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Policies)

6 Months Ended

Jun. 30, 2016

Accounting Policies [Abstract]

Proved Property Impairment

Proved Property Impairment - The Partnership assesses its producing natural gas properties for possible impairment, upon a triggering event, by comparing net capitalized costs to estimated undiscounted future net cash flows on a well by well basis using estimated production based upon prices at which the Partnership reasonably estimates the commodities to be sold.  The estimates of future prices may differ from current market prices of natural gas.  Certain events, including but not limited to, downward revisions in estimates to the Partnership’s reserve quantities, expectations of falling commodity prices or rising operating costs, could result in a triggering event and, therefore, a possible impairment of the Partnership’s proved natural gas properties.  If net capitalized costs exceed undiscounted future net cash flows, the measurement of impairment is based on estimated fair value utilizing a future discounted cash flows analysis, which is predominantly unobservable data or inputs, and is measured by the amount by which the net capitalized costs exceed their fair value.  Estimated undiscounted future net cash flows are determined using prices from the forward price curve at the measurement date.  Estimated discounted future net cash flows are determined utilizing a risk adjusted discount rate that is based on rates utilized by market participants that are commensurate with the risks inherent in the development of the underlying natural gas reserves.  Due to the decrease in natural gas prices, as further discussed in Note 4, the Partnership reviewed its proved natural gas properties for impairment at June 30, 2016 and did not recognize an impairment charge for the second quarter 2016.  The Partnership has an accumulated impairment charge of proved natural gas properties of approximately $11,810,700 as of June 30, 2016 and December 31, 2015.

Asset Retirement Obligations

Asset Retirement Obligations - The Partnership applies the provisions of “Accounting for Asset Retirement Obligations” and “Accounting for Conditional Asset Retirement Obligations” and accounts for asset retirement obligations by recording the fair value of its plugging and abandonment obligations when incurred, which is at the time the well is completely drilled. Upon initial recognition of an asset retirement obligation, the Partnership increases the carrying amount of the long-lived asset by the same amount as the liability. Over time, the asset retirement obligations are accreted, over the estimated life of the related asset, for the change in their present value. The initial capitalized costs are depleted over the useful lives of the related assets, through charges to depreciation, depletion and amortization. If the fair value of the estimated asset retirement obligation changes, an adjustment is recorded to both the asset retirement obligation and the asset retirement cost. Revisions in estimated liabilities can result from revisions of estimated inflation rates, escalating retirement costs and changes in the estimated timing of settling asset retirement obligations.

Recent Accounting Pronouncements

Recent Accounting Pronouncements - In May 2014, the FASB and the International Accounting Standards Board issued their converged standard on revenue recognition that provides a single, comprehensive model that entities will apply to determine the measurement of revenue and timing of when it is recognized. The underlying principle is that an entity will recognize revenue to depict the transfer of goods or services to customers at an amount that the entity expects to be entitled to in exchange for those goods or services. The standard outlines a five-step approach to apply the underlying principle: (a) identify the contract with the customer, (b) identify the separate performance obligations in the contract, (c) determine the transaction price, (d) allocate the transaction price to separate performance obligations and (e) recognize revenue when (or as) each performance obligation is satisfied. The revenue standard is effective for annual reporting periods beginning after December 15, 2017, including interim periods within that reporting period, and can be adopted under the full retrospective method or simplified transition method. Early adoption is not permitted. The Partnership plans to adopt the revenue standard beginning January 1, 2018 and is currently evaluating the impact that these changes will have on our condensed financial statements.

In August 2014, the FASB issued Accounting Standards Update (ASU) No. 2014-15, Disclosures of Uncertainties About an Entity’s Ability to Continue as a Going Concern, new guidance related to the disclosures around going concern. The new standard provides guidance around management’s responsibility to evaluate whether there is substantial doubt about an entity’s ability to continue as a going concern and to provide related footnote disclosures. The new standard is effective for fiscal years, and interim periods within those fiscal years, beginning after December 15, 2017. Early adoption is permitted.

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NATURAL GAS PROPERTIES (Tables)

6 Months Ended

Jun. 30, 2016

Oil and Gas Property [Abstract]

Schedule of aggregate capitalized costs relating to oil and gas producing activities

	June 30, 2016		December 31, 2015
Leasehold Costs	$	124,987	$	124,987
Asset Retirement Obligation Asset		642,503		642,503
Development Costs		2,210,505		2,210,505
Natural Gas Properties, successful efforts method		2,977,995		2,977,995
Less: Accumulated Depreciation, Depletion and Amortization		2,657,628		2,581,280
Natural Gas Properties,  net	$	320,367	$	396,715

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ASSET RETIREMENT OBLIGATION (Tables)

6 Months Ended

Jun. 30, 2016

Asset Retirement Obligation Disclosure [Abstract]

Schedule of changes in carrying amount of asset retirement obligations

	June 30, 2016
December 31, 2015, beginning balance	$	651,870
Accretion expense		2,433
June 30, 2016	$	654,303

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ORGANIZATION AND NATURE OF OPERATIONS (Detail Textuals)	6 Months Ended
	Jun. 30, 2016
Organization and Nature Of Operations [Abstract]
Maximum partnership term (in years)	50 years
Partnership termination period (in years)	15 years or longer

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SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Detail Textuals) - USD ($)	Jun. 30, 2016	Dec. 31, 2015
Accounting Policies [Abstract]
Accumulated impairment charge of proved natural gas properties	$ 11,810,700	$ 11,810,700

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PARTICIPATION IN COSTS AND REVENUES (Detail Textuals) - Thousand Cubic Feet (MCF)	3 Months Ended
	Jun. 30, 2016 USD ($) $ / Mcf MMcf	Jun. 30, 2015 USD ($) $ / Mcf MMcf
Partners Participation In Costs and Revenues [Line Items]
Gross revenue from the sale of natural gas	$ 129,000	$ 69,400
Unit of production of natural gas | MMcf	99,000	46,700
Average price of natural gas per MCF | $ / Mcf	1.30	1.49
Royalties	$ 13,000
Partnership
Partners Participation In Costs and Revenues [Line Items]
Gross revenue from the sale of natural gas	$ 88,700	$ 128,000
Unit of production of natural gas | MMcf	65,000	93,400
Average price of natural gas per MCF | $ / Mcf	1.37	1.37
Royalties	$ 79,500	$ 14,000
Total estimate of expenses to be deducted	$ 63,300	$ 73,000

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PARTNERS CAPITAL (Detail Textuals)	6 Months Ended
	Jun. 30, 2016
Partners' Capital Notes [Abstract]
Period of performance standard as defined in the agreement	8 years
Period of performance standard after final closing of partnership	12 months
Minimum cumulative distributions for one through five years	10.00%
Minimum cumulative distributions for six through eight years	7.50%
Maximum percentage of share subordinated net production revenues	60.00%
Terms under partnership agreement	The Partnership Agreement provides for the enhancement of investor cash distributions if the Partnership does not meet a performance standard defined in the agreement during the first 8 years of operations beginning the earlier of the first full year of operation after all wells begin production or 12 months after the final closing of the Partnership.

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PARTNERS CAPITAL (Detail Textuals 1) - USD ($)	6 Months Ended	12 Months Ended
	Jun. 30, 2016	Dec. 31, 2015
Partners Capital [Line Items]
Amount owed from partnership	$ 31,143	$ 19,510
Managing General Partner
Partners Capital [Line Items]
Value of distributions subordinated to investors	$ 11,633	$ 51,002

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TRANSFERS AND PRESENTATIONS (Detail Textuals)	6 Months Ended
	Jun. 30, 2016
Transfers And Presentations [Abstract]
Partnerships present worth of future net revenues	70.00%
Maximum limit for request by MGP on a first-come first serve	not exceed 5%

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NATURAL GAS PROPERTIES - Summary of costs capitalized for gas activities (Details) - USD ($)	Jun. 30, 2016	Dec. 31, 2015
Oil and Gas Property [Abstract]
Leasehold Costs	$ 124,987	$ 124,987
Asset Retirement Obligation Asset	642,503	642,503
Development Costs	2,210,505	2,210,505
Natural Gas Properties, successful efforts method	2,977,995	2,977,995
Less: Accumulated Depreciation, Depletion and Amortization	2,657,628	2,581,280
Natural Gas Properties, net	$ 320,367	$ 396,715

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ASSET RETIREMENT OBLIGATION - Changes in carrying amount of asset retirement obligations associated with gas properties (Details)	6 Months Ended
	Jun. 30, 2016 USD ($)
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward]
December 31, 2015, beginning balance	$ 651,870
June 30, 2016	654,303
Natural gas properties
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward]
December 31, 2015, beginning balance	651,870
Accretion expense	2,433
June 30, 2016	$ 654,303

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ASSET RETIREMENT OBLIGATION (Detail Textuals) - USD ($)	3 Months Ended	6 Months Ended
	Jun. 30, 2015	Jun. 30, 2016
Asset retirement obligation	$ 131,698
Accretion expense	2,068
Partnership estimate of costs plug wells	$ 21,000	$ 60,000
Asset retirement obligation discount rate		5.57%
Minimum
Estimated useful lives		4 years 9 months 18 days
Maximum
Estimated useful lives		20 years

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RELATED-PARTY ACTIVITIES (Detail Textuals) - USD ($)	3 Months Ended		6 Months Ended
	Jun. 30, 2016	Jun. 30, 2015	Jun. 30, 2016	Jun. 30, 2015	Dec. 31, 2015
Related Party Transaction [Line Items]
Payment for well maintenance fees	$ 36,441	$ 36,376	$ 75,655	$ 83,669
Managing General Partner
Related Party Transaction [Line Items]
Payment for well maintenance fees			28,800	$ 28,800
Accrued liability	$ 76,000		$ 76,000		$ 82,000