United States

Securities and Exchange Commission ~~Washington, D.C. 20549~~

Washington, D.C. 20549

Form 10-K

(Mark One)

☒	ANNUAL REPORT PURSUANT TO SECTION 13 OR 15 (d) OF THE SECURITIES EXCHANGE ACT OF 1934
For the year ended December 31, 2014
☐	TRANSITION REPORT PURSUANT TO SECTION 13 OR 15 (d) OF THE SECURITIES EXCHANGE ACT OF 1934

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

For the ~~transition~~year ~~period~~ended ~~from~~December ~~__________~~31, ~~to __________~~ 2015

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

For the transition period from ___________ to ___________

Commission file number 0001551390

MDS ENERGY PUBLIC 2013 – A LP ~~(Name of small business issuer in its charter)~~

Delaware		90-0852601
(State or other jurisdiction of incorporation or organization)		(I.R.S. Employer Identification No.)
409 Butler Road Suite A Kittanning, PA (Address of principal executive offices)		16201 (zip code)

(Name of small business issuer in its charter)

Delaware		90-0852601
(State or other jurisdiction of incorporation or organization)		(I.R.S. Employer Identification No.)

409 Butler Road Suite A
Kittanning, PA		16201
(Address of principal executive offices)		(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 December 31, ~~2014~~2015, this Partnership had 1,~~500~~508.153 units of limited partnership interest outstanding and no units of additional general partnership interest outstanding.

MDS ENERGY PUBLIC 2013 - A LP

(A Delaware Limited Partnership)

INDEX TO ANNUAL REPORT

ON FORM 10-K

Implications of Being an Emerging Growth Company

		PAGE

Forward- Looking Statement

PART I

Item 1:	Business	3

Item 2:	Properties	6

Item 3:	Legal Proceedings	6

Item 4:	(Removed and Reserved)	7

PART II

Item 5:	Market for Registrant’s Common Equity and related Unit holder Matters	7

Item 7:	Management’s Discussion and Analysis of Financial Condition and Results of Operations	7

Item 8:	Financial Statements	11

Item 9:	Changes in and Disagreements with Accountants on Accounting and Financial Disclosure	21

Item 9A:	Controls and Procedures	21

PART III

Item 10:	Directors, Executive Officers and Corporate Governance	22

Item 11:	Executive Compensation	24

Item 12:	Security Ownership of Certain Beneficial Owners and Management	24

Item 13:	Certain Relationships and Related Transactions	24

Item 14:	Principal Accountant Fees and Services	25

PART IV

Item 15:	Exhibits	25

SIGNATURES		26

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 will continue to be an “emerging growth company” until the earliest of:

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;

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.

FORWARD-LOOKING STATEMENTS

The matters discussed within this report include forward-looking statements. These statements may be identified by the use of forward-looking terminology such as “anticipate,” “believe,” “continue,” “could,” “estimate,” “expect,” “intend,” “may,” “might,” “plan,” “potential,” “predict,” “should,” or “will,” or the negative thereof or other variations thereon or comparable terminology. In particular, statements about our expectations, beliefs, plans, objectives, assumptions or future events or performance contained in this report are forward-looking statements. We have based these forward-looking statements on our current expectations, assumptions, estimates, and projections. While we believe these expectations, assumptions, estimates, and projections are reasonable, such forward- looking statements are only predictions and involve known and unknown risks and uncertainties, many of which are beyond our control. These and other important factors may cause our actual results, performance or achievements to differ materially from any future results, performance or achievements expressed or implied by these forward-looking statements.

PART I

ITEM 1:

BUSINESS

Overview

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 vertical dry 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, as the sole limited partner. 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.

OnAs ~~May~~of 2,December ~~2013~~31, 2014, the Partnership’s ~~registration~~had ~~statement~~drilled onfourteen ~~Form~~gross ~~S-1~~vertical ~~(File~~gas ~~No.~~wells ~~333-181993,~~of ~~333-181993-01, 333-181993-02 and 333-181993-03) was declared effective for the Partnership’s public offering pursuant to~~ which ~~the~~twelve ~~Partnership~~were ~~began~~revenue ~~soliciting potential investors on a “best efforts” basis~~producing. The Partnership ~~sold~~has no ~~general~~employees and~~/or~~ ~~limited~~relies ~~partner~~on ~~units~~the atMGP afor ~~price of $10~~management,~~000~~ ~~per~~which ~~unit~~in turn, ~~subject~~relies toon ~~discounts~~employees ~~for certain classes~~ of ~~investors including the MGP and~~ its affiliates. ~~The~~for proceeds from the offering are being used to cover intangible drilling costs and equipment associated with the drilling of developmental natural gas wells in the Marcellus Shale formation in Pennsylvaniaservices.

As of December 31, ~~2013~~ 2015, the ~~offering termination date, the~~ Partnership had ~~received~~completed ~~total~~fourteen ~~cash~~vertical ~~and~~gas ~~subscriptions~~wells ~~from 358 investors of $15,001,000 (1,500.1 units) which were then paid to our MGP acting as operator~~ and ~~general drilling contractor under our drilling and operating agreement. Our MGP contributed leases ($124,987), paid for 3% of the 10% syndication/offering costs of $450,030, and paid for~~ all ~~organization~~fourteen ~~costs~~were ofrevenue ~~$750,050~~producing for a ~~total~~portion ~~MGP capital contribution~~ of ~~$1,325,067~~2015.

As of December 31, 2014, the Partnership had drilled fourteen gross vertical gas wells of which twelve were revenue producing and two were awaiting pipeline connections to commence deliveries to production facilities. We do not intend to drill any more wells. The Partnership had drilled no dry gas wells as of December 31, 2014. The Partnership has no employees and relies on the MGP for management, which in turn, relies on employees of its affiliates for services.

Business Strategy

We do not plan to sell any of our wells and will continue production until they are depleted or become uneconomical to produce, at which time they will be plugged and abandoned or sold. No other wells will be drilled and no additional funds will be required for drilling.

Our operating cash flows will be generated from the production and sale of dry natural gas from these wells. The produced dry natural gas will be delivered to market through gas gathering systems operated by ~~affiliated~~MDS ~~companies~~Energy LTD. (“MDS Energy”), and Snyder Brother’s Inc. (“SBI”). Snyder Brothers Gas Marketing will act as the gas marketer for the Partnership. It is our intention to operate the wells in a profitable manner to generate operating cash flows for distributions to investors.

Our ongoing operating and maintenance costs are expected to be fulfilled through revenues from the sale of our natural gas production. We will pay our MGP a well supervision fee of $800 per well per month as outlined in our drilling and operating agreement. The MGP from time to time may elect to waive the well supervision fee when revenues from the sale of natural gas do not exceed the fee, this is not necessary of the MGP but done in good faith to the investors.

This well supervision fee covers all normal and regularly recurring operating expenses for the production and sale of natural gas such as:

●· well tending and routine maintenance;

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

●· preparation of reports for government agencies and internal use.

The well supervision fees, however, do not include costs and expenses related to the purchase of certain equipment and materials and brine disposal. If these expenses are incurred, we pay the costs for third-party services, materials, and a competitive charge for services performed directly by our MGP or its affiliates. Also, beginning one year after each of our wells has been placed into production, our MGP, as operator, may retain $200 per month per well to cover the estimated future plugging and abandonment cost of the well. As of December 31, ~~2014~~2015 our MGP had not withheld any funds for this purpose.

Natural Gas Gathering Agreements

Virtually all natural gas produced will be gathered through one or more pipeline systems before sale or delivery to an end user, a marketer, or an interstate pipeline. A gathering fee will be charged for each gathering activity that is utilized and by each separate gatherer providing the service. Fees will vary depending on the distance the gas travels and whether additional services such as compression, blending, or contaminant removal are provided.

The MGP’s primary gathering agreements are with ~~its affiliates Snyder Brothers~~SBI, ~~Inc.,~~ Furnace Run Pipeline, LP, Mushroom Farm Pipeline, LP, and MDS Energy~~, Ltd~~., ~~and other affiliates of our MGP.~~ Under the gathering agreements, we dedicate our natural gas production for transportation to interstate pipeline systems, local distribution companies, and/or end users in the area, subject to certain exceptions.

Seasonal Nature of Business

Generally, but not always, the demand for natural gas decreases during the summer months and increases during the winter months. Seasonal anomalies such as mild winters or hot summers sometimes lessen this fluctuation. In addition, certain natural gas users utilize natural gas storage facilities and purchase some of their anticipated winter requirements during the summer. This can also lessen seasonal demand fluctuations. These seasonal anomalies may pose challenges and increase competition for equipment, supplies and personnel, which could lead to shortages and increase costs or delay our operations.

COMPETITION, MARKETS AND REGULATION

Competition and Markets

The Partnership operates in a highly competitive environment for acquiring leases, contracting for drilling services, marketing natural gas production from its wells and pricing for the product. It is anticipated that the wells drilled will produce mostly “dry gas,” such as the natural gas generally produced from wells situated in the Marcellus Shale primary area. Product availability and price are the principal means of competing in selling dry natural gas. Price obtained is determined by various factors beyond our control including domestic production, market demand, competition from other energy sources, and capacity of the gathering systems, political climate and weather. Many companies engage in natural gas drilling operations and most of our competitors in the areas where we will drill our wells will have financial resources and staffs larger than those available to us.

We do not consider our position in the industry to be significant and as such, we have little ability to significantly influence the price for our product.

Governmental Regulation

Governmental agencies, both Federal and State, regulate the production and transportation of natural gas. The Federal Energy Regulatory Commission regulates the interstate transportation of natural gas.

Natural gas operations in Pennsylvania are regulated by the Department of Environmental Protection, Division of Oil and Gas states, which ~~includes the~~include the Department of Environmental Resources for wells to be drilled in Pennsylvania. In this regard, the ~~Pennsylvania~~states ~~Department~~impose ~~of Environmental Resources imposes~~ a comprehensive statutory and regulatory scheme for natural gas operations, including supervising natural gas production activities and the transportation of natural gas sold in intrastate markets, which creates additional financial and operational burdens. The ~~Pennsylvania~~states ~~Department of Environmental Resources~~ also ~~has~~have broad regulatory and enforcement powers including those associated with pollution and the environment as discussed below.

Failure to comply with regulatory requirements can result in substantial fines and other penalties.

Environmental Regulation

The MGP ~~drilled~~will drill and ~~completed~~complete the wells and ~~supervises~~supervise the producing operations. Those activities ~~are~~ will be subject to various federal, state, and local laws covering the discharge of materials into the environment, or otherwise relating to the protection of the environment. The United States Environmental Protection Agency (the “EPA”) and state and local agencies will require obtaining permits and taking other measures with respect to:

(i)

the discharge of treated brine into navigable waters;

(ii)

the disposal, recycling or treatment of wastewater; and

(iii)

air pollutant emissions.

If these requirements or permits are violated there can be substantial civil and criminal penalties that will increase if there was negligence or misconduct. In addition, we may be subject to fines, penalties and unlimited liability for cleanup costs under various federal laws such as the Federal Clean Water Act, the Clean Air Act, the Resource Conservation and Recovery Act, the Oil Pollution Act of 1990, the Toxic Substance Control Act and the Comprehensive Environmental Response, Compensation and Liability Act of 1980 for oil and/or hazardous substance contamination or other pollution caused by our drilling activities or our wells and our production activities.

We and our investor general partners may incur environmental costs and liabilities due to the nature of our business and substances from our wells. Moreover, the possibility exists that stricter laws, regulations or enforcement policies may be enacted or adopted in the future which could significantly increase our compliance costs and the cost of any remediation that may become necessary in the future.

Employees

We do not directly employ any of the persons responsible for ~~our~~its management or operation. Rather, the personnel of the MGP’s affiliates manage and operate our business, and they will also spend a substantial amount of time managing their own business and affairs as well as the business and affairs of our MGP’s other affiliates, which creates a conflict regarding the allocation of their time between our MGP’s business and affairs and their other business interests.

Available Information

We make our periodic reports under the Securities Exchange Act of 1934, including our annual report on Form 10-K, our quarterly reports on Form 10-Q, our current reports on Form 8-K, and any amendments to those reports, available through our MGP’s website at www.mdsenergydev.com as soon as reasonably practicable after we electronically file such material with, or furnish it to, the Securities and Exchange Commission (the “SEC”). To view these reports, click on “Investment Programs”, then “Drilling Program SEC Filings” and finally our reports.

You may also receive, without charge, a paper copy of any such filings by request to us at telephone number 724-548-2501. A complete list of our filings is available on the SEC’s website at www.sec.gov. Any of our filings are also available at the Securities and Exchange Commission’s Public Reference Room at 100 F Street, N.E., Room 1580, Washington, D.C. 20549. The Public Reference Room may be contacted at telephone number (800) 732-0330 for further information.

ITEM 2:

PROPERTIES

Productive Wells

Productive wells consist of producing wells and wells capable of production, including natural gas wells awaiting pipeline connections to commence deliveries to production facilities. As of December 31, ~~2014~~2015, we had ~~drilled~~completed fourteen wells, of which ~~twelve~~fourteen ~~were~~are revenue ~~producing~~ ~~and two were awaiting connection to a gathering line~~producing. No additional ~~other~~ wells ~~are~~will ~~scheduled to~~ be drilled for the Partnership.

Developed Acreage

The leases for our wells generally have terms that extend for the life of the wells. We believe that we hold good and indefeasible title to our properties in accordance with standards generally accepted in the natural gas industry, subject to ~~certain~~ exceptions stated in the leases and titles us in the various areas in which we conduct our activities. We do not believe that these exceptions detract substantially from our use of any property. As is customary in the natural gas industry, we conduct only a perfunctory title examination at the time we acquire a property. Before we ~~began~~commenced drilling operations, ~~however,~~ we conducted an extensive title examination and we performed ~~curative~~ curative work on defects that we deemed significant.

Our properties are subject to royalty, overriding royalty and other outstanding interests customary in the industry. Our properties are also subject to burdens such as liens incident to operating agreements, taxes, development obligations under natural gas leases, farm-out arrangements and other encumbrances, easements and restrictions. We do not believe that any of these burdens will materially interfere with our use of our properties.

Natural Gas Reserves

Proved reserves are the estimated quantities of natural gas which geological and engineering data demonstrate with reasonable certainty to be recoverable in future years from known reservoirs under existing economic and operating conditions, i.e., prices and costs as of the date the estimate is made. Prices include consideration of changes in existing prices provided only by contractual arrangements, but not on escalations based upon future conditions. An independent third- party reserve engineer will estimate the natural gas reserves in the future.

~~Our reserves~~The Partnerships reserves are all located in the Marcellus ~~Shale~~shale formation and all are natural gas. As of December 31, ~~2014~~2015, ~~our~~ the Partnerships net proved reserves of natural gas were 31,~~999~~516 (MMCF).

Impairment of Natural Gas Properties

WeThe ~~assess~~Partnership ~~our~~assesses its producing natural gas properties for possible impairment, upon a triggering event which is usually annually, 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 ~~our~~the ~~MGP~~independent third-party reserve engineer reasonably estimates the commodities to be sold. During the year the market experienced a significant decline in commodity prices, which wethe Company viewed as a triggering event and, therefore, a possible impairment of ~~our~~the Partnership’s proved natural gas properties. At December 31, ~~2014~~2015 upon the receipt of a year-end reserve report, wethe Partnership reviewed ~~our~~the ~~proved~~proven natural gas properties for possible impairment. The net capitalized costs of ~~our~~the wells in the Partnership exceeded the undiscounted future net cash flows from well production. As a result, an impairment of the properties was recorded, of approximately $ 65,~~629~~182,000 for year end 2015, by calculating the difference between the future discounted cash flows from the properties and the net capitalized costs on the balance sheet. $3,735,000 was booked during the 3rd quarter of 2015 and $1,447,000 was booked in the 4th quarter of 2015 respectively.

ITEM 3:

LEGAL PROCEEDINGS

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

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

ITEM 4:

REMOVED AND RESERVED

PART II

ITEM 5:

MARKET FOR REGISTRANT’S COMMON EQUITY, RELATED UNITHOLDER MATTERS AND ISSUER PURCHASES OF EQUITY SECURITIES

There is no established public trading market for our units and we do not anticipate that a market for our units will develop. Our units may be transferred only in accordance with the provisions of our Partnership Agreement which requires:

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

●· the transfer will not result in materially adverse tax consequences to us; and

●· the transfer will not contravene any terms of our 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 us all costs and expenses incurred in connection with the substitution; and

●· the assignee executes and delivers the instruments which our MGP requires to effect the substitution and to confirm the assignee’s agreement to be bound by the terms of our Partnership Agreement.

A substitute partner is entitled to all of the rights of full ownership of the assigned units, including the right to vote. As of December 31, ~~2014~~2015 we had 358 ~~unitholders~~unit holders.

Our investor partners may request that our MGP repurchase their units at any time beginning with the fifth anniversary after December 31, 2013, provided that certain conditions of our Partnership Agreement are met. The repurchase price is set at ~~the greater of~~ (i) predominantly 70% of the 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 our debts of or (ii) an amount equal to three times the total amount of distributions paid by usthe Partnership to the participants as a group during the previous twelve months. Our 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 our MGP on a first-come, first- served basis and may not exceed 5% of the total units outstanding. ~~Our MGP may suspend the repurchase feature at any time if it determines we do not have the necessary cash flow or cannot borrow funds for this purpose on reasonable terms.~~

ITEM 7:

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

The discussion and analysis presented below provides information to assist in understanding our financial condition and results of operations. This discussion should be read in conjunction with Item 8: Financial Statements and Supplemental Data, which contains our financial statements.

Overview

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

As of December 31, ~~2014~~ 2015, the partnership had ~~drilled~~completed fourteen ~~gross~~ vertical wells of which twelve were revenue producing ~~and two~~for ~~were~~a ~~awaiting~~full ~~connection~~year toand athe ~~pipeline.~~remaining two Wewere doproducing ~~not~~for ~~intend~~a toportion ~~drill~~of ~~any~~the ~~additional~~year ~~wells~~. All wells were drilled in the Marcellus ~~Shale~~shale formation. No other activities had occurred at December 31, ~~2014~~2015.

~~Our MGP~~In ~~has~~2015 ~~agreed~~and ~~to subordinate up to 60% of its share~~2014, as the MGP, ofhad ~~our~~subordinated ~~partnership net production revenues during~~ a ~~96-month subordination~~total ~~period that began on January 1, 2014. As~~ of ~~December 31, 2014, the MGP had subordinated~~ $ 2778,~~533~~535 of distributions to the investors.

Our MGP is MDS, a Pennsylvania limited liability company. The MGP’s affiliates, MDS Energy, ~~Ltd.~~ and M/D Gas, Inc., have previously sponsored and serve as managing general partner of ~~eight~~ten private drilling partnerships, in the aggregate. Also, MDS sponsored its first private drilling partnership in 2012 and ithas sponsored an additional private drilling partnership in 2014 and 2015.

First Class Energy, LLC (First Class), an affiliate of our MGP, has provided ~~certain~~the necessary services to drill the wells on our behalf under our ~~drilling~~ drilling and operating agreement with our MGP. Our MGP ~~serves~~will serve as our drilling contractor and operator (“driller/operator”) and will supervise the drilling, completing, and operating (administrative, gathering, transportation, well services) of the wells to be drilled by us and it and its affiliates will be paid at competitive rates for their services. The gas marketing will be handled by ~~an affiliated company,~~ Snyder Brothers, ~~Inc.~~Gas Marketing, which may also gather, transport and purchase our natural gas production at competitive ~~rates~~ rates in the area. The personnel of the driller/operator’s affiliates’ (MDS ~~Energy, Ltd.~~ and First Class ~~Energy, LLC~~) ~~help our MGP~~ manage and operate ~~our~~the MGP’s business. These affiliates (MDS and First Class) have limited information with respect to the ultimate recoverable reserves and production decline rates of vertical wells drilled in the Marcellus Shale primary area. Our MGP and its affiliates will receive substantial fees and profits in connection with this business.

Governance

WeThe ~~have~~Partnership has no executive officers and currently do not have any directors. Because wethe doPartnership itself does not employ any persons, our MGP has determined that we will rely on a Code of Business Conduct and Ethics adopted by MDS that applies to the executive officers, employees and other persons performing services for our MGP. Our MGP has determined that it will not establish an independent Board of Directors with an Audit Committee for us at this time.

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 our MGP and its affiliates may be inconsistent in some respects, and our MGP’s actions may not be the most advantageous to investors.

~~We do~~The Partnership does not directly employ any of the persons responsible for ~~our~~its management or operation. Rather, the personnel of MDS Energy, ~~Ltd.~~ and ~~First Class Energy, LLC help our MGP~~ MDS manage and operate our MGP’s business, and they will also spend a substantial amount of time managing their own business and affairs as well as the business and affairs of our MGP’s other affiliates, which creates a conflict regarding the allocation of their time between us and our MGP’s business and affairs and their other business interests. In this regard, ~~our~~each partnership’s policies and procedures for reviewing, approving or ratifying related party transactions with our MGP ~~and its affiliates~~ are set forth in the partnership agreement.

Liquidity and Capital Resources

During 2015, the low commodity prices negatively affected our revenues, earning and cash flows for the Partnership. A further extended decline in commodity prices could also adversely have a significant impact on the value and quantities of our reserves. In response to the low commodity price environment, the MGP has evaluated the following, placing hedges for fixed commodity prices on behalf of the Partnership, waiving or suspending fees that are due to the MGP and also looking at other ways to reduce overhead costs associated to the Partnership. During 2015 the MGP suspended well tending fees for the Partnership as you will see below.

Natural Gas Sales

~~We currently~~The ~~use~~Partnership currently uses the “net-back” method of accounting for these arrangements related to ~~our~~its commodity sales. ~~We sell~~This Partnership sells commodities at the wellhead and ~~collect~~collects a price under contracts with monthly pricing provisions, based on a differential to the average monthly NYMEX (“NYMEX”) price and ~~recognize~~recognizes revenues based on the wellhead sales price as transportation ~~costs~~ costs downstream of the wellhead are incurred by the purchaser and reflected in the wellhead price. The net-back method results in the recognition of a sales price that is below the indices for which the production is based.

As of December 31, ~~2014~~ 2015, all of the aggregate capital ~~from our offering~~ of the units had been expended, and fourteen wells had been completed and ~~twelve are~~ revenue producing ~~with two awaiting connection to gathering lines which are expected to be connected by September 30, 2015~~. As of December 31, ~~2014~~2015, approximately $1616,~~193,~~000 of ~~net~~gross revenue from the sale of natural gas had been received for approximately ~~457~~ 387,000 MCF of production with an average realized price of $21.6159 per MCF. ~~The first well began producing in March, 2014.~~ In addition, approximately $~~220~~88,000 of net revenue from the sale of natural gas had been recorded as revenue as a result of ~~our~~the Partnership estimating revenue from production for which the proceeds of the sale of the natural gas had not yet been received and these amounts are recorded as accounts receivable. The average realizable price per MCF for this estimated revenue is $1.7938 per MCF for the estimated production of ~~123~~64,000 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 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.

Natural Gas Production Costs

Generally, natural gas production costs vary with changes in total natural gas production volumes. Transportation charges totaled approximately $~~224~~167,000 or 3937 cents per MCF. 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 and well maintenance costs for the year ended December 31, ~~2014~~2015 were approximately $ 94157,000 or 1635 cents per MCF.

~~Depreciation~~The MGP has the discretion of waiving or suspending the fees it receives for well maintenance when it is deemed necessary to provide the Partnership with additional income to make distributions to investors. During the year ended December 31, ~~Depletion~~2015, ~~and~~the ~~Amortization~~MGP has suspended fees of $28,800, with the intention of being able to recoup in the future as prices increase. These have been accrued by the Partnership.

DD&A expense for continuing operations was approximately $ 1,210,000 for the year ended December 31, 2014 as a result of production of 579,486 MCFs during 2014. The DD&A expense rate per MCF was approximately $ 2.17 for the year ended December 31, 2014.

At December 31, 2014 upon the receipt of a year-end reserve report, we reviewed our proved natural gas properties for possible impairment. The net capitalized costs of our wells exceeded the undiscounted future net cash flows from well production. As a result, an impairment of the properties was recorded, of approximately $ 6,629,000, by calculating the difference between the future discounted cash flows from the properties and the net capitalized costs as of December 31, 2014. Total capitalized costs as of December 31, 2014, before the impairment expense was $14,270,914.

Funding of Activities

We believe the cash flow from our operations is adequate to fund future operations and distributions to our partners.

~~Availability~~Depreciation, ofDepletion ~~Financing to the Managing General Partner~~ and ~~associated entities~~Amortization (DD&A)

~~In July,~~DD&A ~~2014,~~expense ~~certain of the wholly-owned companies of MDS Associated Companies, Inc., an affiliate of the managing general partner,~~for ~~agreed~~continuing tooperations ~~revise~~was ~~their~~approximately ~~existing line of credit with PNC Bank, National Association. Under the revised terms,~~ $31,~~000~~371,000 ~~of the~~for ~~existing balance on~~ the ~~line~~year ofended ~~credit was converted to a term note of 60 month duration with an interest rate of LIBOR plus 2.45%. As of~~ December 31, ~~2014,~~2015 ~~the~~as ~~outstanding balance was $2,750,000. In addition, there is~~ a ~~line~~result of ~~credit~~actual ~~for working~~production ~~capital in the amount~~ of $2473,000~~,000~~ MCFs ~~that~~during ~~matures~~2015. onAlso ~~July~~during 302015, ~~2015~~due ~~with~~to anthe ~~interest~~Partnership ~~rate~~using ofaccrual ~~LIBOR~~method ~~plus 2.45% and a line~~ of ~~credit~~accounting ~~for~~we ~~equipment~~had ina ~~the~~reversal ~~amount~~ of $422,~~500,~~000 ~~that matures July 31~~MCF, ~~2015 with an interest rate of LIBOR plus~~ ~~2.50%.~~which Asrepresented ~~of December 31, 2014, there was no outstanding balance under~~ the ~~working~~difference ~~capital~~between ~~line of credit and~~ the ~~outstanding balance~~accrual ~~under~~at the ~~equipment~~end ~~line~~ of ~~credit~~2014 ~~was~~and ~~$3,471,725~~actual ~~which~~production ~~was~~for ~~converted~~that toperiod ~~a term note~~ of 602014. ~~months~~The ~~duration with an~~DD&A ~~interest~~expense rate ofper ~~LIBOR~~MCF ~~plus~~was ~~2.5%.~~approximately ~~All~~$ ~~credit facilities are guaranteed by all the wholly-owned companies of MDS Associated Companies, Inc~~2.,90 ~~including~~for the ~~managing~~year ~~general~~ended ~~partner.~~December ~~The credit facilities are secured by all of the assets of the borrowers~~31, ~~including the managing general partner’s, except fixtures used in connection with wells and the production and transportation of natural gas and oil from the wells~~2015. ~~The obligations of the borrowers under these facilities have been guaranteed by Michael D. Snyder.~~

InAt ~~addition,~~December ~~MDS Energy~~31, ~~Ltd.,~~2015 anupon ~~affiliate~~the receipt of ~~our~~a ~~MGP,~~year-end isreserve areport, ~~borrower~~the ~~under~~Partnership ~~two~~reviewed ~~financing~~the ~~arrangements~~proven ~~(unsecured~~natural ~~line~~gas ofproperties for ~~credit~~possible ~~and~~impairment. anThe ~~unsecured~~net ~~demand~~capitalized ~~note)~~costs ~~with~~of ~~David~~the E.wells ~~Snyder,~~in the ~~father~~Partnership ofexceeded ~~Michael~~the D.undiscounted ~~Snyder.~~future Asnet ofcash ~~December~~flows from ~~31,~~well ~~2014~~production. ~~the~~As ~~aggregate principal~~a ~~amount~~result, ~~outstanding~~an ~~under~~impairment ~~these~~of ~~financing~~the ~~arrangements~~properties was recorded, of approximately $25,~~575~~182,000, ~~which~~by ~~may~~calculating ~~increase~~the difference orbetween ~~decrease in~~ the future~~. The~~ ~~unsecured~~discounted ~~line~~cash offlows ~~credit~~from isthe ~~for~~properties ~~$5,000,000~~ and ~~borrowings bear interest at~~ the ~~prime~~net ~~lending~~capitalized ~~rate~~costs ~~less 1.25%. The outstanding balance~~ as of December 31, ~~2014 was $1,325,000 and is payable on demand~~2015. ~~The unsecured demand note bears interest at the Federal~~ ~~Fund~~Total ~~target~~capitalized ~~Rate~~costs ~~plus~~as 1%of ~~with~~December a31, ~~2.5%~~2015, ~~floor~~before ~~and~~ the ~~outstanding~~impairment ~~balance~~charge was $15,~~250~~579,~~00 and is payable on demand with interest payable quarterly~~000. The financing arrangements are subordinated to MDS Associated Companies, Inc.’s obligations to PNC Bank, National Association, under the term note and line of credit described in the preceding paragraph.

~~Participation~~Direct in Costs ~~and~~– ~~Revenues~~General and ~~Distributions~~Administrative

~~Please~~Direct ~~refer~~costs tofor ~~Note~~year 3ending toDecember ~~the~~31, ~~financial~~2015 ~~statements~~were ~~for~~$229,000 ~~the details~~ of ~~how~~which ~~our~~$129,000 ~~costs~~represent ~~and~~impact ~~revenues~~fees ~~will be charged~~ and ~~credited between~~$100,000 ~~our MGP and our investors after deducting from our gross revenues the landowner royalties and any other lease burdens. Some~~ of ~~the~~professional ~~percentages will be determined either by the actual costs incurred by us to drill and complete our~~fees ~~wells~~during ~~or by~~ the ~~final amount of our MGP’s capital contribution to us, which will not be known until after all of our wells have been drilled and completed~~year.

~~Critical~~Financial ~~Accounting~~Condition, ~~Policies~~Liquidity and Capital Resources

The Partnership’s ~~discussion~~primary ~~and~~source ~~analysis~~ of ~~our~~liquidity ~~financial~~has ~~condition~~been iscash ~~based~~flows ~~upon~~from ~~our~~operating ~~condensed~~activities. ~~balance~~Fluctuations ~~sheets,~~in ~~which~~this ~~have~~Partnership’s ~~been~~operating ~~prepared~~cash inflows ~~accordance~~are ~~with~~substantially ~~accounting~~driven ~~principles~~by ~~generally~~changes ~~accepted~~ in ~~the~~commodity ~~United~~prices ~~States~~and ofsales ~~America~~volumes. WeThis ~~will~~source ~~base~~of ~~our~~cash ~~estimates on~~has ~~historical~~been ~~experience~~primarily ~~and~~used onto fund ~~various~~this ~~other~~Partnership’s ~~assumptions~~operating ~~that~~costs, wedirect ~~believe~~cost-general ~~are~~and ~~reasonable~~administrative, ~~under~~capital ~~the~~program ~~circumstances,~~ and ~~the results~~distributions ofto ~~which form~~ the investors ~~basis~~and ~~for making judgments about~~ the ~~carrying values of assets and liabilities that are not readily apparent from other sources~~MGP. ~~We will evaluate our estimates on an on-going basis.~~

~~Actual~~The Partnership’s ~~results~~future ~~may~~operations ~~differ~~are ~~from~~expected ~~these~~to ~~estimates~~be ~~under~~conducted ~~different~~with ~~assumptions~~available orfunds ~~conditions.~~and Arevenues ~~discussion~~generated offrom ~~significant~~natural ~~accounting~~gas ~~policies~~production activities. weNatural ~~have~~gas ~~adopted~~production ~~and~~from ~~followed~~existing properties is generally expected to continue a gradual decline in the ~~preparation~~rate of ~~our~~production ~~financial~~over the ~~statements~~remaining islife ~~included~~of ~~within~~the ~~“Notes~~wells. toAny ~~Financial Statements”~~additional infunds, ~~Part~~if Irequired, ~~Item~~will 1be obtained from production revenues, ~~“Financial~~advances ~~Statements”~~or inwaiving/suspending of ~~this~~fees ~~annual~~from ~~report~~the MGP.

Working Capital

As of December 31, 2015 this Partnership had working capital of $(17,000). The MGP will waive it’s fees, compensation and provide necessary loans if needed to ensure that the Partnership will be able to have working capital.

Cash Flows

Operating Activities

The Partnership’s cash flows from operating activities in 2015 were primarily impacted by commodity prices, operating costs, professional fees and declining production. Net cash flow from operating activities for the year ended December 31, 2015 were $228,300.

Financing Activities

The Partnership during year ended December 31, 2015 made distributions to investors that totaled $222,854, also during this period the MGP advanced the Partnership $28,000 to pay for professional fees.

~~REPORT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM~~Critical Accounting Policies

ToThe discussion and analysis of the ~~Partners~~Partnership’s financial condition is based upon the Partnership’s balance sheet, which have been prepared in accordance with accounting principles generally accepted in the United States of America. 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.

~~MDS~~Actual ~~Energy~~results ~~Public~~may differ ~~2013-~~from these estimates under different assumptions or conditions. A ~~LP:~~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 annual report.

We have audited the accompanying balance sheets of MDS Energy Public 2013-A Limited Partnership (Partnership) as of December 31, 2014 and 2013 and the related statements of operations, partners’ equity and cash flows for the years then ended. These financial statements are the responsibility of the Partnership’s management. Our responsibility is to express an opinion on these financial statements based on our audits.

We conducted our audits in accordance with the standards of the Public Company Accounting Oversight Board (United States). Those standards require that we plan and perform the audit to obtain reasonable assurance about whether the financial statements are free of material misstatement. The Partnership is not required to have, nor were we engaged to perform, an audit of its internal control over financial reporting. Our audits included consideration of internal controls over financial reporting as a basis for designing audit procedures that are appropriate in the circumstances, but not for the purpose of expressing an opinion on the effectiveness of the Partnership’s internal control over financial reporting. Accordingly, we express no such opinion. An audit also includes examining, on a test basis, evidence supporting the amounts and disclosures in the financial statements, assessing the accounting principles used and significant estimates made by management, and evaluating the overall financial statement presentation. We believe that our audits provide a reasonable basis for our opinion.

In our opinion, the financial statements referred to above present fairly, in all material respects, the financial position of MDS Energy Public 2013-A Limited Partnership as of December 31, 2014 and 2013, and the results of its operations and its cash flows for the years then ended, in conformity with accounting principles generally accepted in the United States of America.

As discussed in Note 8 to the financial statements, the Partnership has had significant related-party transactions with its Managing General Partner, MDS Energy Development, LLC.

Pittsburgh, Pennsylvania March 13, 2015

Schneider Downs & Co., Inc.	One PPG Place	41 S. High Street
www.schneiderdowns.com	Suite 1700	Huntington Center, Suite 2100
	Pittsburgh, PA 15222	Columbus, OH 43215
	TEL 412.261.3644	TEL 614.621.4060
	FAX 412.261.4876	FAX 614.621.4062

~~Condensed~~MDS ~~Balance~~ENERGY ~~Sheets~~PUBLIC 2013-A LP

	December 31
	2014		2013
Assets
Current Assets
Cash and Cash Equivalents	$	18,264	$	1,312,723
Accounts Receivable		250,097
Total Current Assets		268,361		1,312,723
Drilling advances to Managing General Partner		-		15,001,000
Oil and Gas properties, successful efforts method		6,431,436		124,987
Oil and Gas properties ‐ net		6,431,436		124,987
Total Assets	$	6,699,797	$	16,438,710
Liabilities
Current Liabilities
Due to Managing General Partner	$	-	$	2,448,088
Accrued Expenses		134,629
Total Liabilities		134,629		2,448,088
Asset Retirement Obligations		129,630		-
Partners’ Equity		6,435,538		15,038,885
Subscription Receivable		-		(1,048,263	)
Partners’ Equity		6,435,538		13,990,622
Total liabilities and partners’ equity	$	6,699,797	$	16,438,710

Balance Sheets

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

	2015			2014
Assets
Current Assets
Cash and Cash Equivalents	$	23,707		$	18,264
Accounts Receivable – Managing General Partner		19,510			-
Accounts Receivable – Related Party		78,760			250,097
Total Current Assets		121,977			268,361

Natural Gas properties		396,715			6,431,436

Total Assets	$	518,692		$	6,699,797

Liabilities
Current Liabilities
Due to Managing General Partner	$	28,000		$	-
Accrued Expenses-Related Party		28,800			-
Accrued Expenses		82,235			134,629
Total Current Liabilities		139,035			134,629

Long - Term Asset Retirement Obligations		651,870			129,630

Partners' (Deficit) Equity		(272,213	)		6,435,538

Total Liabilities and Partners’ Equity	$	518,692		$	6,699,797

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

~~The~~ MDS ENERGY PUBLIC 2013-A LP

~~For~~Statements ~~the~~of ~~Years Ended December 31, 2014 and 2013~~ Operations

	2014			2013
Revenue
Revenue	$	1,501,077		$	-
Miscellaneous		1,884			193
Total Revenue		1,502,961			193
Operating Costs and Expenses
Gathering Expense		224,350
Well Maintenance		94,114
DD&A Expense		1,215,236
Impact Fee		47,300
Accounting Fees		92,805
Bank Fees		72
Impairment Charge		6,629,108
Other expenses:
Organization Costs					82,522
Other					4,773
Total Expenses		8,302,985			87,295
Net Loss	$	(6,800,024	)	$	(87,102	)

For the Years Ended December 31, 2015 and 2014

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

	2015			2014

Natural Gas Revenue, net	$	625,770		$	1,501,077

Expenses
Gathering Expense		166,784			224,350
Well Maintenance		157,427			94,114
DD&A		1,375,411			1,215,236
Impact Fees		129,496			47,300
Professional Fees		99,999			92,805
Impairment Charge		5,181,550			6,629,108
Total Expenses		7,110,667			8,302,913
Operating Loss		(6,484,897	)		(6,801,836	)

Other Income		-			1,812
Net Loss	$	(6,484,897	)	$	(6,800,024	)

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

~~Statements~~MDS ofENERGY ~~Partner’s~~PUBLIC ~~Equity~~2013-A LP

	Investor Partners			Managing General Partner			Subscription Receivable			Total
Partners’ capital contribution
Capital Contribution	$	15,001,000		$	-		$	(1,048,263	)	$	13,952,737
Syndication costs					1,117,558			-			1,117,558
Leasehold Costs		-			124,987			-			124,987
Total Contributions		15,001,000			1,242,545			(1,048,263	)		15,195,282
											-
Syndication and offering costs, immediately charged to capital		-			(1,117,558	)		-			(1,117,558	)
		15,001,000			124,987			(1,048,263	)		14,077,724
Net Loss		(73,061	)		(14,041	)		-			(87,102	)
Balance December 31, 2013		14,927,939			110,946			(1,048,263	)		13,990,622
Collection of Subscription Receivable								1,048,263			1,048,263
Sales Commissions		(979,630	)		-						(979,630	)
Distriubtions		(707,726	)		(115,967	)		-			(823,693	)
Net Loss		(5,710,660	)		(1,089,364	)		-			(6,800,024	)
Balance at December 31, 2014	$	7,529,923		$	(1,094,385	)	$	-		$	6,435,538

Statements of Partner's (Deficit) Equity

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

	Investor			Managing General			Subscription
	Partners			Partner			Receivable			Total

Balance December 31, 2013	$	14,927,939		$	110,946		$	(1,048,263	)	$	13,990,622

Collection of Subscription Receivable		-			-			1,048,263			1,048,263
Sales Commissions		(979,630	)		-			-			(979,630	)
Distributions		(707,726	)		(115,967	)		-			(823,693	)
Net Loss		(5,710,660	)		(1,089,364	)		-			(6,800,024	)

Balance at December 31, 2014	$	7,529,923		$	(1,094,385	)		-		$	6,435,538

(Distributions) due from MGP		(242,364	)		19,510	*		-			(222,854	)
Net Loss		(5,439,555	)		(1,045,342	)		-			(6,484,897	)

Balance at December 31, 2015	$	1,848,004		$	(2,120,217	)		-		$	(272,213	)

*due to subordination

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

The MDS ENERGY PUBLIC 2013-A LP

~~For~~Statements ~~the~~of ~~Year~~Cash ~~Ended December 31~~Flows

	2014			2013
Cash flows from Operating activities
Net Loss	$	(6,800,024	)	$	(87,102	)
Adjustments to reconcile net loss to cash (used in) operations
Depletion		1,210,370			-
Impairement Charge		6,629,108			-
Accretion		4,866			-
Total Adjustments to net loss to reconcile to net cash provided by (used in) operating activities		1,044,320			(87,102	)
Changes in assets and liabilities
Accounts Receivable		(250,097	)		-
Accounts Payable and Accrued Expenses		134,629			-
Net Cash provided by operating activities		928,852			(87,102	)
Cash flows from investing activities
Drilling Advances paid to the Managing General Partner		207			(15,001,000	)
(Repayments to) Advances from the Managing General Partner		(2,448,088	)		2,448,088
Net cash used in investing activities		(2,447,881	)		(12,552,912	)
Cash flows from financing activities
Collection of Subscription Receivable		1,048,263			-
Investor Partners’ contributions		-			13,952,737
Distributions		(823,693	)		-
Net cash provided by financing activities		224,570			13,952,737
Net change in cash and cash equivalents		(1,294,459	)		1,312,723
Cash and cash equivalents at beginning of year		1,312,723			-
Cash and cash equivalents at end of year	$	18,264		$	1,312,723
SUPPLEMENTAL DISLOSURE OF NONCASH ACTIVITY
Asset retirement obligation, with corresponding increase to gas properties	$	124,764		$	-
Drilling Advances paid to the Managing General Partner	$	14,021,370
Investment in Gas Properties		(14,021,370	)
	$	-
Assets contributed by the managing general partner
Lease Costs				$	124,987
Organizational and offering costs					1,200,080
				$	1,325,067

For the Years Ended December 31

During 2013 that Partnership paid approximately $937,000 to the MGP to pay sales commission on their behalf, this amount was paid during 2014 and the partnerships capital balance was reduced accordingly.

	2015			2014
Cash flows from Operating activities
Net Loss	$	(6,484,897	)	$	(6,800,024	)
Adjustments to reconcile net loss to cash provided by operations
Depreciation Depletion & Amortization		1,375,411			1,215,236
Impairment Charge		5,181,550			6,629,108
Total Adjustments to net loss to reconcile to net cash from operating activities		72,064			1,044,320
Changes in assets and liabilities
Accounts Receivable		151,827			(250,097	)
Accounts Payable and Accrued Expenses		4,406			134,629
Net Cash provided by operating activities		228,297			928,852

Cash flows from investing activities
Drilling Advances paid to the Managing General Partner		-			207
Oil and Gas Properties		-			(2,448,088	)
Net cash used in investing activities		-			(2,447,881	)

Cash flows from financing activities
Collection of Subscription Receivable		-			1,048,263
Distributions		(222,854	)		(823,693	)
Advances from Managing General Partner		-			-
Net cash (used in) provided by financing activities		(222,854	)		224,570

Net change in cash and cash equivalents		5,443			(1,294,459	)
Cash and cash equivalents at beginning of year		18,264			1,312,723

Cash and cash equivalents at end of period	$	23,707		$	18,264

SUPPLEMENTAL DISCLOSURE OF NONCASH ACTIVITY
Asset Retirement obligation, change in estimate	$	526,741		$	-

Asset retirement obligation, with corresponding increase to gas properties	$	-		$	124,764

Drilling Advances paid to the Managing General Partner	$	-		$	14,021,370
Investment in Gas Properties	$	-		$	(14,021,370	)
	$	-		$	-

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

MDS ENERGY PUBLIC 2013-A LP ~~NOTES TO FINANCIAL STATEMENTS DECEMBER 31, 2014 AND 2013~~

NOTES TO FINANCIAL STATEMENTS

DECEMBER 31, 2015 AND 2014

NOTE 1 - ORGANIZATION AND NATURE OF OPERATIONS

MDS Energy Public 2013-A LP (Partnership), was organized in 2013, in accordance with the laws of the state of Delaware. The 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 MGP and M/D Gas, Inc. (M/D), a related party, as the sole limited partner. 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.

~~On May~~General 2,partner ~~2013,~~units were converted by the Partnership’s ~~registration~~to ~~statement~~limited onpartners ~~Form~~units ~~S-1~~upon ~~(File~~the ~~No.~~drilling ~~333-181993, 333-181993-01, 333-181993-02~~ and ~~333-181993-03)~~ ~~was~~completion ~~declared~~of ~~effective~~all ~~for~~of the Partnership’s ~~public~~wells. ~~offering~~In ~~pursuant~~accordance with ~~to which~~ the ~~Partnership~~terms ~~began soliciting~~of ~~potential~~the ~~investors~~Limited onPartnership aAgreement (“~~best efforts~~Agreement” ~~basis. By December 31~~), ~~2013,~~MDS ~~the~~manages ~~Partnership~~all ~~sold~~activates ~~1,500.1 units and received gross proceeds~~ of ~~$15,001,000 which were paid to~~ the ~~MGP acting as operator and general drilling contractor under the~~ Partnership’s ~~drilling~~ and ~~operating agreement. The MGP contributed leases, tangible equipment, and paid all syndication~~ ~~and~~acts ~~offering~~as ~~costs,~~the ~~excluding~~intermediary ~~sales commissions~~ for asubstantially ~~total~~all ~~capital~~Partnership ~~contribution of approximately $1,325,067~~transactions. The ~~proceeds~~Partnership ~~from the~~operates ~~offering~~a ~~will~~single bebusiness ~~used to cover intangible drilling costs and equipment associated with the drilling of developmental natural gas wells in the Marcellus Shale formation in Pennsylvania~~unit.

~~General~~Investor Partners may request that MDS ~~partner~~repurchase units ~~were~~at ~~converted~~any bytime beginning with the ~~Partnership~~fifth toanniversary ~~limited~~after ~~partner~~the ~~units~~offering ~~upon~~termination date when certain conditions are met. The repurchase price is set at predominantly 70% of the ~~drilling~~present worth of future net revenues from the Proved Reserves as determined under the last reserve report and ~~completion~~is ofreduced by an amount equal to all debts of the Partnership~~’s wells. In~~ ~~accordance~~or ~~with~~an amount equal to three times the ~~terms~~total amount of ~~the~~distributions ~~Limited~~paid by the Partnership ~~Agreement~~as ~~(“Agreement”),~~a group during the previous twelve months. MDS ~~manages~~is ~~all~~also permitted to ~~activities~~adjust the purchase price under certain conditions for changes occurring after the date of the ~~Partnership~~presentment request. Repurchase requests will be fulfilled by MDS on a first-come, first served basis and ~~acts~~may asnot exceed 5% of the ~~intermediary~~total ~~for~~units ~~substantially~~outstanding ~~all~~in ~~Partnership~~any calendar ~~transactions~~year. ~~The~~ During December 31, 2015 and 2014, the Partnership ~~operates~~did anot ~~single~~repurchase ~~business~~any ~~unit~~units from limited partners.

Investor partners may request that MDS repurchase units at any time beginning with the fifth anniversary after the offering termination date when certain conditions are met. The repurchase price is set at predominantly 70% of the 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 debts of the Partnership or, if greater, an amount equal to three times the total amount of distributions paid by the Partnership as a group during the previous twelve months. MDS is also permitted to adjust the purchase price under certain conditions for changes occurring after the date of the presentment request. Repurchase requests will be fulfilled by MDS on a first-come, first served basis and may not exceed 5% of the total units outstanding in any calendar year. As of December 31, 2014, the Partnership did not repurchase any units from limited partners. The repurchase feature may be suspended at any time if our MGP determines that we do not have any necessary cash flow or cannot borrow funds for this purpose on reasonable terms.

NOTE 2 - SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES

A summary of significant accounting policies consistently applied by management in the preparation of the accompanying financial statements follows:

Basis of Presentation – the financial statements include only those assets, liabilities and results of operations of the partners which relate to the business of the Partnership. The statements do not include any assets, liabilities, revenues or expenses attributable to any of the partners’ other activities.

Management’s ~~Estimates~~Estimate – The preparation of the Partnership’s financial statements in accordance with accounting principles generally accepted in the United States of America (“U.S. GAAP”) requires this Partnership to make estimates and assumptions that affect the amounts reported in this Partnership’s financial statements and accompanying notes. Actual results could differ from those estimates. Estimates which are particularly significant to the financial statements include estimates of natural gas and natural gas liquids (“NGL”) sales revenue, proved reserves, future cash flows from natural gas and NGL’s properties.

Cash and Cash Equivalents - The Partnership’s cash and cash equivalents include cash and interest-bearing money market deposits held by major financial institutions having original maturities of 90 days or less. The balance in the Partnership account is insured by Federal Deposit Insurance Corporations, up to $250,000. The balance in these accounts may at times be in excess of federally insured amounts. The Partnership has not experienced losses in any such accounts to date and limits the Partnership’s exposure to credit loss by placing its cash and cash equivalents with high-quality financial institutions.

Accounts Receivable –- related party – The Partnership records an estimate of revenue to be received in future months for production in the months prior to the end of the reporting period, based upon estimated production information that is available to it. Substantially all of the Partnership’s production is sold to a related party of the Partnership. Management determined that no allowance for uncollectible amounts was necessary at December 31, ~~2014~~ 2015 and ~~2013~~2014, respectively, however this estimate may change in the future periods.

Drilling Advances to Managing General Partner – the Partnership prepaid the cost of drilling the wells in the Program to the Managing General Partner.

NOTE 2 - SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (~~continued~~Continued)

Natural Gas Properties - The Partnership accounts for its natural gas properties under the successful efforts method of accounting. Costs of proved developed producing properties and developmental dry hole costs are capitalized and depreciated or depleted by the unit-of-production method based on estimated proved developed producing reserves. Property acquisition costs are depreciated or depleted on the unit-of-production method based on estimated proved reserves. Leased property was contributed by the managing general partner, and was utilized in the drilling efforts of the Partnership. The Partnership calculates depreciation, depletion and amortization (DD&A) expense by using as the denominator the Partnership’s estimated period-end reserves adjusted to add back current period production. Upon the sale or retirement of significant portions of or complete fields of depreciable or depletable property, the net book value thereof, less proceeds or salvage value, is recognized in the statement of operations as a gain or loss. Upon the sale of individual wells, the proceeds are credited to accumulated DD&A. Costs to drill exploratory wells that do not find proved reserves, geological and geophysical costs and costs of carrying and retaining unproved properties are expensed.

The estimates of proved reserves are based on quantities of gas that engineering and geological analysis demonstrates, with reasonable certainty, to be recoverable from established reservoirs in the future under current operating and economic conditions. Annually, the Partnership engages independent petroleum engineers to prepare a reserve and economic evaluation of all ~~the~~our ~~Partnership’s~~ properties on a well-by-well basis as of December 31. The process of estimating and evaluating gas reserves is complex, requiring significant decisions in the evaluation of available geological, geophysical, engineering and economic data. The data for a given property may also change substantially over time as a result of numerous factors, including additional development activity, evolving production history and a continual reassessment of the viability of production under changing economic conditions. As a result, revisions in existing reserve estimates occur from time to time. Although every reasonable effort is made to ensure that reserve estimates reported represent the Partnership’s most accurate assessments possible, the subjective decisions and variances in available data for various properties increase the likelihood of significant changes in these estimates. Because estimates of reserves significantly affect this Partnership’s DD&A expense, a change in this Partnership’s estimated reserves could have an effect on the Partnership’s income or loss.

Proved ~~Property~~ 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~~ 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 crude oil ~~and 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 availability of new reserve information, the Partnership reviewed its proved natural gas properties for impairment at December 31, ~~2014~~2015. The Partnership recognized an impairment charge of proved properties of approximately $5,182,000, and $6,629,000 for the year ended December 31, 2015, and 2014.

Production Tax Liability – Production tax liability represents estimated taxes, primarily ad valorem and property, to be paid to the states and counties in which the Partnership operates. The Partnership’s share of the tax expense is included in gathering expense. The Partnership’s taxes payable are included in accounts payable on the balance sheets.

Proceeds from the Sale of Wells/Leases - If the parties’ capital accounts are adjusted to reflect the depletion of a natural gas property of the Partnership, then the portion of the total amount realized by the Partnership on the taxable disposition of the property that represents recovery of its simulated tax basis in the property shall be allocated to the parties in the same proportion as the aggregate adjusted tax basis of the property was allocated to the parties or their predecessors in interest. If the parties’ capital accounts are adjusted to reflect the actual depletion of a natural gas property of the Partnership, then the portion of the total amount realized by the Partnership on the taxable disposition of the property that equals the parties’ aggregate remaining adjusted tax basis in the property shall be allocated to the parties in proportion to their respective remaining adjusted tax bases in the property. Thereafter, any excess will be allocated to the managing general partner in an amount equal to the difference, if any, between the fair market value of the lease at the time it was contributed to the Partnership and its simulated or actual adjusted tax basis at that time. Any excess shall be credited generally in accordance with the sharing ratio utilized for the allocation of production revenues.

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.

~~Transfers~~As ~~and~~managing ~~Presentments~~general –partner, ~~There~~MDS ishas ~~no established~~the ~~public~~right ~~trading~~to ~~market~~withhold ~~for~~$200 ~~the~~per month of Partnership’s ~~units~~revenues ~~and~~in wePartnership doreserves ~~not~~to ~~anticipate~~cover ~~that~~future aplugging ~~market~~and ~~for~~abandonment costs of the well, beginning one year after each Partnership well begins producing. This $200 also includes the managing general partner’s ~~units~~ ~~will~~share ~~develop~~of revenues. The ~~Partnership~~managing general partner’s ~~units~~retained ~~may~~revenues will be ~~transferred~~used ~~only~~exclusively infor ~~accordance~~plugging ~~with~~and abandonment of the ~~provisions~~well. To the extent any portion of those reserves ultimately is not required for the plugging and abandonment costs of the well it will be returned to the general operating revenue of the Partnership. ~~Agreement~~There were no funds withheld from the Partnership’s ~~which~~revenues ~~requires:~~for future plugging and abandonment costs during the years ended December 31, 2015 and 2014.

· 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 us and;

· the transfer does 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 us 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 term of the Partnership Agreement.

As managing general partner, MDS has the right to withhold $200 per month of Partnership revenues in Partnership reserves to cover future plugging and abandonment costs of the well, beginning one year after each Partnership well begins producing. This $200 also includes the managing general partner’s share of revenues. The managing general partner’s retained revenues will be used exclusively for plugging and abandonment of the well. To the extent any portion of those reserves ultimately is not required for the plugging and abandonment costs of the well it will be returned to the general operating revenue of the Partnership. There were no funds withheld from the Partnership’s revenues for future plugging and abandonment costs during the years ended December 31, 2014 and 2013.

NOTE 2 - SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (~~continued~~Continued)

Commitments- AsIn ~~Managing~~its ~~General~~capacity ~~Partner~~as MGP, MDS maintains performance bonds for plugging, reclaiming and abandoning of this Partnership’s wells as required by governmental agencies. If a government agency were required to access these performance bonds to cover plugging, reclaiming or abandonment costs on a Partnership well, this Partnership would be obligated to fund any amounts in excess of funds previously withheld by the managing general partner to cover these expenses.

Equipment Proceeds - Proceeds from the sale or other disposition of equipment will be credited to the parties charged with the costs of the equipment in the ratio in which the costs were charged.

Income Taxes - Since the taxable income or loss of the Partnership is reported in the separate tax returns of the individual partners, no provision has been made for income taxes by the Partnership.

Accounting for uncertainty in income taxes requires financial statement recognition, measurement and disclosure of uncertain tax positions recognized in an enterprise’s financial statements. Under this guidance, income tax positions must meet a more-likely-than-not recognition threshold at the effective date to be recognized upon the adoption of the standard. The Partnership did not have any unrecognized tax benefits, and there was no effect on its financial condition. The Partnership has not identified any uncertain tax positions and as such no interest or penalties have been included in other expense on the statement of operations. The Partnership will file a U.S. federal income tax return, but income will be passed through to the partners.

~~Fair~~Revenue ~~Value~~Recognition ~~Measurement~~ - ~~The~~Sales ~~Partnership~~of ~~measures~~gas are ~~assets~~recognized ~~and~~when ~~liabilities~~gas athas ~~fair~~been ~~value~~delivered into ~~accordance~~a ~~with~~custody ~~the~~transfer ~~Codification topic~~point, ~~Fair~~persuasive ~~Value~~evidence ~~Measurements~~of a sales arrangement exists, the rights and ~~Disclosures.~~responsibility ~~This~~of ~~topic~~ownership ~~defines~~pass ~~fair~~to ~~value~~the purchaser upon delivery, ~~establishes~~collection aof ~~framework~~revenue ~~for~~from ~~its~~the ~~measurement~~sale ~~and requires~~is ~~disclosures~~reasonably ~~regarding~~assured, and the ~~Partnership’s~~sales ~~fair~~price ~~value~~is ~~measurements.~~fixed ~~Fair~~or ~~value~~determinable. Gas is ~~defined~~sold asby MDS to Snyder Brothers Gas Marketing, in the ~~price~~market ~~that~~at ~~would~~prevailing beprices ~~received~~with tocertain ~~sell~~adjustments anbased ~~asset~~on, oramong ~~paid~~other tofactors, ~~transfer~~whether a ~~liability~~well indelivers anto ~~orderly~~a ~~transaction~~gathering ~~between~~or ~~market~~transmission ~~participants~~line, atquality of gas and prevailing supply and demand conditions, so that the ~~measurement~~price of the gas fluctuates to remain competitive with other available ~~date~~gas supplies. ~~The~~As ~~carrying~~a ~~amount~~result, of the Partnership’s ~~cash~~revenues from the sale of gas will suffer if market prices decline and ~~cash~~benefit if ~~equivalents,~~they ~~accounts~~increase. ~~receivable~~However, ~~drilling~~MDS ~~advances~~may from time to ~~Managing General~~time ~~Partner~~enter into derivative agreements, ~~Due~~usually with a term of two years or less which may either fix or collar a price in order to ~~Managing~~reduce ~~General~~market ~~Partner~~price ~~and~~fluctuations. ~~accrued~~The ~~liabilities~~Partnership ~~approximated~~believes ~~fair~~that ~~value~~the aspricing provisions of its gas contracts are customary in the industry. The Partnership did not enter into derivative agreements for the years ended December 31, 2015 and 2014.

~~Revenue Recognition~~Recent -Accounting ~~Sales~~Pronouncements of- ~~gas~~In ~~are~~May 2014, ~~recorded on~~ the ~~“net~~FASB ~~back”~~and ~~method.~~the ~~Sales~~International ~~are~~Accounting ~~recognized~~Standards ~~when~~Board ~~gas~~issued ~~has been~~their ~~delivered~~converged tostandard aon ~~custody~~revenue ~~transfer~~recognition ~~point,~~that ~~persuasive evidence of~~ provides a ~~sales arrangement exists~~single, ~~the~~comprehensive ~~rights~~model ~~and~~that ~~responsibility~~entities ~~of ownership~~will ~~pass~~apply to determine the ~~purchaser~~measurement ~~upon delivery, collection~~ of revenue ~~from~~and ~~the~~timing ~~sale~~of iswhen ~~reasonably~~it ~~assured,~~is ~~and~~recognized. The ~~the~~underlying ~~sales~~principle ~~price~~ is ~~fixed~~that oran ~~determinable. Gas~~entity iswill ~~sold~~recognize byrevenue ~~MDS~~ to ~~Snyder~~depict ~~Brothers,~~the ~~Inc,~~transfer ~~Agent,~~of angoods ~~affiliated~~or ~~entity,~~services into ~~the~~customers ~~market~~ at an ~~prevailing~~amount ~~prices~~that ~~with~~the ~~certain~~entity ~~adjustments~~expects ~~based~~to ~~on,~~be ~~among~~entitled ~~other~~to ~~factors,~~in ~~whether~~exchange afor ~~well~~those ~~delivers~~goods ~~to a gathering~~ or ~~transmission line,~~services. ~~quality~~The ofstandard ~~gas~~outlines ~~and~~a ~~prevailing~~five-step ~~supply~~approach to ~~and~~apply ~~demand~~the ~~conditions,~~underlying soprinciple: ~~that~~(a) identify the ~~price~~contract ofwith the ~~gas~~customer, ~~fluctuates~~(b) toidentify ~~remain~~the ~~competitive with~~separate ~~other~~performance ~~available~~obligations in ~~gas~~the ~~supplies. As~~contract, a(c) ~~result,~~determine the ~~Partnership’s~~transaction ~~revenues~~price, ~~from~~(d) allocate the ~~sale~~transaction ofprice ~~gas~~to ~~will~~separate ~~suffer~~performance ifobligations and ~~market~~(e) ~~prices~~recognize ~~decline~~revenue ~~and~~when ~~benefit~~(or ifas) ~~they~~each ~~increase. However,~~performance ~~MDS~~obligation ~~may~~is ~~from~~satisfied. ~~time~~The torevenue ~~time~~standard ~~enter~~is ~~into~~effective ~~derivative~~for ~~agreements,~~annual reporting ~~usually~~periods ~~with~~beginning aafter ~~term~~December of15, ~~two~~2017, ~~years~~including orinterim ~~less~~periods ~~which~~within ~~may~~that ~~either~~reporting ~~fix~~period, orand ~~collar~~can abe ~~price~~adopted inunder ~~order~~the full toretrospective ~~reduce~~method ~~market~~or ~~price~~simplified ~~fluctuations~~transition method. ~~The Partnership~~ ~~believes~~Early ~~that~~adoption ~~the~~is ~~pricing~~not ~~provisions~~permitted. ofThe ~~its~~Partnership ~~gas~~plans ~~contracts~~to ~~are~~adopt ~~customary in~~ the revenue ~~industry. The~~standard ~~Partnership did~~beginning ~~not~~January ~~enter~~1, ~~into~~2018 ~~derivative~~and ~~agreements~~is ~~for~~currently evaluating the ~~years~~impact ~~ended~~that ~~December~~these ~~31,~~changes ~~2014~~will ~~and~~have ~~2013~~on our financial statements.

~~Recent Accounting Pronouncements-~~ In ~~May~~August 2014, ~~the Financial Accounting Standards Board (~~FASB) issued ~~Accounting Standards Update (~~ASU) No. 2014-~~09 Revenue from Contracts with Customers (Topic 606) (ASU 2014-09), which affects any entity that either~~15 ~~enters~~Presentation ~~into contracts with customers to transfer goods or services or enters into contracts for the transfer~~ of ~~nonfinancial assets~~Financial ~~unless~~Statements ~~those~~- ~~contracts~~Going ~~are~~Concern ~~within the scope of other standards~~ (~~e.g.,~~Subtopic ~~insurance contracts or lease contracts~~205-40)~~. ASU~~: ~~2014-09~~Disclosure ~~will supersede the revenue recognition requirements in Topic 605 Revenue Recognition and most industry-specific guidance. In addition, the existing requirements for the recognition~~ of aUncertainties ~~gain~~about oran ~~loss~~Entity’s onAbility ~~the~~to ~~transfer~~Continue ofas ~~nonfinancial assets that are not in~~ a ~~contract~~Going ~~with a customer (e~~Concern.g., assets within the scope of Topic 360, Property, Plant, and Equipment, and intangible assets within the scope of Topic 350, Intangibles - Goodwill and Other) are amended to be consistent with the guidance on recognition and measurement (~~including the constraint on revenue) in~~ ASU ~~2014-09~~No. ~~The~~ ~~core principle of~~ 2014-15) ASU 2014-0915 is ~~that~~intended ~~an entity should recognize revenue~~ to ~~depict~~define ~~the~~management’s ~~transfer~~responsibility ofto ~~promised~~evaluate ~~goods~~whether orthere ~~services~~is tosubstantial ~~customers~~doubt inabout an ~~amount~~organization’s ~~that~~ability ~~reflects~~to ~~the~~continue ~~consideration~~as toa ~~which~~going ~~the~~concern ~~entity~~and ~~expects~~ to beprovide ~~entitled~~related infootnote ~~exchange for those goods or services~~disclosures. ~~The~~ ~~amendments in~~ ASU 2014-0915 ~~are~~is effective for annual reporting periods beginning after December 15, 2016, with early application ~~adoption~~ permitted. ~~The~~ Management ~~Partnership~~ is currently ~~evaluating~~ assessing the ~~impact~~provisions of ASU 2014-0915 and is evaluating the impact that it will have on its footnote disclosures, results of operations, financial ~~statements~~position or cash flows.

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~~related party who purchases from other Partnerships managed by the Partnership’s ~~Managing General Partner~~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 December 31, ~~2014~~2015 and ~~2013~~2014, the Partnership did not record an allowance for doubtful accounts. Inin making the estimate for receivables that are uncollectible, the ~~Managing~~MGP ~~General Partner~~ considers, among other things, subsequent collections, historical write-offs and overall creditworthiness of the Partnership’s customers. It is reasonably possible the estimate for uncollectible receivables will change periodically. Historically neither MDS nor any of the other Partnerships managed by the Partnership’s ~~Managing General Partner~~MGP, have experienced uncollectible accounts receivable. As of December 31, ~~2014~~2015 the Partnership sold 100% of the accounts receivable to a related party and did not incur any losses on accounts ~~receivable~~ receivable for the years ended December 31, ~~2014~~2015 and ~~2013~~2014, respectively.

NOTE 4 - PARTICIPATION IN COSTS AND REVENUES

~~As of~~For the year ended December 31, ~~2014~~2015, approximately $1704,~~193,~~000 of ~~net~~gross revenue from the sale of natural gas had been received or ~~was~~estimated ~~known~~for ~~with certainty, which is~~ approximately ~~457~~451,000 MCF at an average price ~~per MCF~~ of ~~approximately~~ $21.~~61. In~~56 addition approximately $220,000 of net 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 approximately 123,000 MCF at an average price per MCF ~~of $1~~.~~79. These~~ ~~amounts~~Royalties ~~are~~for ~~recorded as~~this ~~accounts~~period ~~receivable.~~were ~~The total estimate of expenses to be deducted from those amounts is~~ approximately $~~123~~78,000~~, which~~. ~~are~~The ~~typically~~estimated ~~transportation,~~amount ~~well~~is ~~maintenance~~further ~~and~~explained ~~lease operating expenses~~below.

~~The following~~For ~~table sets forth how~~ the ~~Partnership’s~~year ~~costs~~ended ~~and~~December ~~revenues~~31, ~~are~~2014, ~~charged and credited between the MGP and~~approximately ~~investors in the Partnership~~$1,707,000 ~~after~~of ~~deducting~~gross revenue from the ~~Partnership’s~~sale ~~gross revenues the landowner royalties and any other lease burdens. Some~~ of ~~the~~natural ~~line~~gas ~~items~~had inbeen ~~the~~received ~~table~~or doestimated ~~not~~for ~~have~~approximately ~~percentages stated~~580,000 ~~because~~MCF ~~the~~at ~~percentages~~an ~~were determined~~average byprice ~~the~~of ~~actual~~$2.94 ~~costs~~per ~~incurred~~MCF. byRoyalties ~~the~~for ~~Partnership~~this toperiod ~~drill~~were ~~and~~approximately ~~complete~~$205,000. ~~its~~The ~~wells~~estimated ~~and the final~~ amount ofis ~~the~~further ~~MGP’s capital~~explained ~~contribution to the Partnership at the effective date of the Partnership formation~~below.

	Managing General Partner			Units Issued by the Partnership
Partnership costs:
Dealer-Manager fee and organization and offering costs, except sales commissions		100	%	0	%
Sales Commissions (1)		0	%	100	%
Lease costs		100	%	0	%
Intangible drilling costs (2)		0	%	100	%
Equipment costs (3)		0	%	100	%
Operating, administrative, direct and all other costs		(4	)	(4	)
Partnership revenues:
Interest income on subscription proceeds (5)		0	%	100	%
Equipment proceeds (3)		0	%	100	%
All other revenues including production revenues and other interest income			(5)(6)(7)		(5)(6)(7)

For the year ended December 31, 2015, the estimated amount of approximately $88,000 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 64,400 MCF at an average price per MCF of $1.37. These estimates are recorded as accounts receivable net of royalties approximating $9,000. The total estimate of expenses to be deducted from those amounts is approximately $62,000, which are typically transportation, well maintenance and lease operating expense.

1For the year ended December 31, 2014, the estimated amount of approximately $250,000 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 123,000 MCF at an average price per MCF of $2.04. These estimates are recorded as accounts receivable net of royalties approximating $30,000. The ~~subscription~~total ~~proceeds~~estimate ~~were~~of ~~used~~expenses to ~~pay~~be ~~100%~~deducted offrom those ~~the~~amounts ~~sales~~is ~~commissions~~approximately $81,000, which are typically transportation, well maintenance and lease operating expense.

2. The subscription proceeds were used to pay 100% of the intangible drilling costs incurred by the Partnership in drilling and completing its wells.

3. The subscription proceeds of investors in the Partnership were used to pay 100% of the equipment costs incurred by the Partnership in drilling and completing its wells. Equipment proceeds, if any, and depreciation will also be allocated 100% to investors in the Partnership.

4. These costs, which will also include plugging and abandonment costs of the wells after the wells have been drilled, produced and depleted, will be charged to the parties in the same ratio as the related production revenues being credited.

5. The subscription proceeds earned interest until the escrow account was broken. This interest was credited to the investors’ account. All other interest income, including interest earned on the deposit of operating revenues, will be credited as natural gas production revenues are credited.

6. The MGP and the investors will share in all of the Partnership’s other revenues in the same percentage that their respective capital contributions bear to the Partnership’s total capital contributions, except that the MGP will receive an additional 8% of the Partnership’s revenues.

7. If a portion of the MGP’s Partnership net production revenue is subordinated, then the actual allocation of Partnership net production revenues between the MGP and the investors will vary from the allocation described in (6) above.

NOTE 5 – PARTNERS CAPITAL

MDS contributed leased property valued at $124,987 that was included as a contribution of partners’ capital at December 31, 2013.

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 ~~net~~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 its revenue interest beginning August 2014 and continuing through December 2015. During the years ended December 31, 2015 and December 31, 2014, the MGP subordinated $51,002 and $27,533, ofrespectively which ~~distributions~~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 $19,510 as of December 31, 2015, which is included with accounts receivable and due from MGP.

~~Subsequent to~~NOTE ~~December~~6 ~~31,~~– ~~2013,~~NATURAL ~~the~~GAS Partnership received approximately $1,048,000 of cash deposits for subscriptions receivable as of December 31, 2013. Cash on hand at December 31, 2013 was approximately $1,313,000. The MGP advanced to the Partnership approximately $2,361,000 at December 31, 2013, so that the Partnership could pay drilling advances to the drilling contractor. The advance of $2,361,000 was repaid by January 27, 2014. In addition, the sales commissions, which are deducted from the investors equity, were deducted from investor partners’ capital in the amount of $979,630. In 2013 the Managing General Partner contributed approximately $1,200,000 of organizational and offering cost to the partnership for partnership interest.PROPERTIES

~~NOTE~~The 6Partnership –is ~~PROPERTIES~~engaged solely in natural gas activities, all of which are located in Armstrong County, Pennsylvania. Costs capitalized for these activities are as follows:

The Partnership is engaged solely in gas activities, all of which are located in Pennsylvania. Costs capitalized for these activities at December 31, 2014 are as follows:

	December 31, 2015		December 31, 2014
Leasehold Costs	$	124,987	$	124,987
Asset Retirement Obligation Asset		642,503		124,764
Development Costs		2,210,505		7,392,055
Natural gas properties, successful efforts method		2,977,995		7,641,806
Less: Accumulated Depreciation, Depletion and
Amortization		2,581,280		1,210,370
Natural Gas Properties – net	$	396,715	$	6,431,436

Leasehold Costs	$	124,987
Asset Retirement Obligation		124,764
Development Costs		14,021,163
Oil and gas properties, successful efforts method		14,270,914
Less: Accumulated Depreciation, Depletion and
Amortization		1,210,370
Impairment Expense		6,629,108
Oil and Gas Properties – net	$	6,431,436

NOTE 7 – ASSET RETIREMENT OBLIGATIONS

~~Twelve wells~~Changes ~~were~~in ~~revenue~~carrying ~~producing~~amount of ~~and~~asset ~~two~~retirement ~~wells~~obligations ~~were~~associated ~~not~~with onnatural ~~line~~gas asproperties offor December 31, ~~2014.~~2015 are as follows:

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. 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 availability of new reserve information as of December 31, 2014, the Partnership reviewed its proved natural gas properties for impairment and recognized an impairment of proved properties of approximately $6,629,000.

	December 31, 2015		December 31, 2014
Balance beginning of year:	$	129,630		-
Change in Obligations assumed with development activities		-		124,764
Change in Estimate		526,741
Accretion expense		4,501		4,886
Balance at end of year:	$	651,870		$ 129 630

~~NOTE~~Cause 7for –Change ~~ASSET~~in ~~RETIREMENT~~Estimate ~~OBLIGATION~~–

~~Changes~~In in2015, ~~carrying~~the ~~amount~~MGP ofrevised its assumptions related to the cash outlay expected to be incurred to plug the Partnership's uneconomic wells. The revision in the asset retirement ~~obligations~~obligation ~~associated~~did ~~with~~not ~~gas~~have ~~properties~~an ~~for~~immediate ~~December~~effect ~~31,~~in ~~2014~~the ~~are~~current year statement of operations, as ~~follows:~~the increase in the revised obligation will be accreted and the offsetting capitalized amount will be depreciated over the useful lives of respective wells.

Balance at beginning of year:	$	- 0 -
Obligations assumed with development activities		124,764
Accretion expense		4,866
Balance at end of period	$	129,630

NOTE 8 - RELATED - PARTY ACTIVITIES

MDS will receive a fully accountable reimbursement for actual administrative costs. In its capacity as operator of the wells, MDS will also receive reimbursement for direct costs, well supervision fees and fees for gas gathering services and any other services it provides, at competitive rates.

MDS, through entities under common ownership or affiliates, have and will continue to perform drilling, administrative, gathering, transportation, well services and gas marketing for the Partnership and will be paid at competitive rates for these services. Drilling costs totaled approximately $14,021,370 for the year ended December 31, 2014 which were prepaid by the Partnership as of December 31, 2013. During the year ended December 31, 2014, MDS was paid approximately $2,559,000 to administer the drilling of the fourteen wells.

Transactions with Managing Partner and Affiliates

MDS is reimbursed for certain partnership expenses and receives fees for services as provided for in the Agreement. For the year ended December 31, ~~2014~~2015 the Partnership paid MDS approximately $85,600 for well maintenance, the Partnership also has an Accrued Liability of $56,800 due to the MGP as of December 31, 2015 compared to $94,000 ~~for~~of well maintenance being paid to MDS as of December 2014.

NOTE 9 ~~–CONTINGENCIES~~- FAIR VALUE MEASUREMENT

~~From~~This ~~time~~Partnership's fair value measurements were estimated pursuant to ~~time,~~a ~~the~~fair value hierarchy that requires this Partnership isto ~~involved~~maximize inthe ~~various~~use ~~legal~~of ~~proceedings~~observable ~~arising~~inputs ~~out~~and minimize the use of unobservable inputs when measuring fair value. The valuation hierarchy is based upon the ~~normal~~transparency ~~conduct~~of inputs to the valuation of ~~its~~an ~~business~~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 ~~opinion~~inputs used to measure fair value might fall in different levels of ~~management~~the fair value hierarchy. In these cases, the ~~ultimate~~lowest ~~resolution~~level ofinput ~~such~~that ~~matters~~is ~~will~~significant ~~not~~to ~~have~~a fair value measurement in its entirety determines the applicable level in the fair value hierarchy. Assessing the significance of a ~~material~~particular ~~effect~~input onto the ~~financial~~fair value ~~position~~measurement in its entirety requires judgment, ~~results~~considering offactors ~~operations~~specific to the asset or ~~cash~~liability, ~~flows~~and may affect the valuation of the ~~Partnership~~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 ~~Partnership~~ isMGP ~~subject~~utilizes tofair ~~various federal~~value, ~~state~~on ~~and~~a ~~local laws and regulations relating to the protection of the environment. The~~non-recurring ~~Partnership has established procedures for the ongoing evaluation of its operations~~basis, to ~~identify~~perform ~~potential~~impairment ~~environmental~~testing ~~exposures and~~on tothis ~~comply with regulatory policies and procedures. The~~ Partnership's ~~accounts~~natural ~~for~~gas ~~environmental~~properties ~~contingencies~~by incomparing ~~accordance with~~net ~~the~~capitalized ~~Contingencies~~costs, ~~topic of the Codification. Environmental expenditures that relate to current operations are expensed~~ or ~~capitalized as appropriate. [Expenditures~~carrying ~~that~~value, ~~relate~~ to anestimated ~~existing~~undiscounted ~~condition caused by past operations, and do not contribute on current or~~ future ~~revenue~~net ~~generation, as~~cash ~~expensed~~flows.~~] Liabilities~~ ~~are~~If ~~recorded~~net ~~when~~capitalized ~~environmental~~costs ~~assessments and/~~or ~~clean-ups~~carrying ~~are~~value ~~probably~~exceed ~~and~~undiscounted ~~the~~future ~~costs can~~net becash ~~reasonably~~flows, ~~estimated. The~~the ~~Partnership~~measurement ~~maintains~~of ~~insurance~~impairment ~~that~~is ~~may~~based ~~cover~~on inestimated ~~whole~~fair orvalue ~~in part certain environmental expenditures. During the years ended December 31, 2014~~ and ~~2013~~is asmeasured aby ~~result of~~ the ~~Managing~~amount ~~General~~by ~~Partner’s periodic~~which ~~review, there were no material environmental remediation projects identified. As such~~ the ~~Partnership~~net ~~did~~capitalized ~~not~~costs ~~record~~exceed atheir ~~liability~~fair orvalue, ~~expense~~which ~~for~~is ~~environmental~~generally ~~remediation~~determined ~~liabilities~~using ~~for~~ the ~~years~~discounted ~~ended~~cash ~~December 31, 2014 or 2013~~flows.

~~NOTE~~The fair values were determined using the 10income 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 – ~~SUBSEQUENT~~adjusted ~~EVENTS~~discount rates and other relevant data.

~~Subsequent events~~NOTE ~~are~~10 ~~defined~~– asCOMMITMENTS ~~events~~AND or transactions that occur after the balance sheet date, but before the balance sheet is issued or is available to be issued. Management has evaluated subsequent events through March 13, 2015, the date on which the balance sheet was available and have determined that there are no subsequent events that require additional disclosure.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 September 30, 2015. 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.

NOTE 11 – RESERVE INFORMATION (UNAUDITED)

The Partnership utilized the services of an independent petroleum engineer to estimate the Partnership’s proved natural gas reserves. These reserve estimates have been prepared in compliance with professional standards and reserve definitions prescribed by the SEC.

Proved reserves estimates may change, either positively or negatively, as additional information becomes available and as contractual, economic and political conditions change. This Partnership’'s net proved reserve estimates have been adjusted as necessary to reflect all contractual agreements, royalty obligations and interests owned by others at the time of the estimate. Proved developed reserves are the quantities of natural gas expected to be recovered from currently producing zones under the continuation of present operating methods. Proved undeveloped reserves are those reserves expected to be recovered from existing wells where a relatively major expenditure is required for additional reserve development. As of December 31, ~~2014~~ 2015 there ~~were~~are no proved undeveloped reserves for this Partnership.

~~During the~~The ~~year,~~price ~~the~~used ~~Partnership~~to ~~incurred total capitalized costs of approximately $14,021,000 for the drilling of vertical wells in~~estimate the ~~Marcellus Shale Formation. No dry holes were drilled and no development or exploratory costs were incurred. All~~ Partnership’s ~~wells~~reserves ~~are~~was ~~categorized~~approximately as$ ~~proved producing wells~~1.041.

The ~~price~~ ~~used~~following totable presents ~~estimate~~ the Partnership’s proved developed reserves ~~was~~as ~~approximately~~of $December ~~2.831/mcf.~~31, 2015, the last time a reserve report was prepared

Future cash flows and production costs from the wells are estimated to be $11,953,000 and $4,434,000 respectively, resulting in future net cash flows before income taxes of $7,519,000. The estimated annual discount of 10% for timing of cash flows would be $3,709,000, resulting in a standardized measure of discounted future net cash flows of $3,810,000.

Proved developed reserves	Gas (MMCF )
Beginning of period		4,200
New Discoveries		-
Revisions		(2,233	)
Production		(451	)
End of Period		1,516

The following table presents the Partnership’s proved developed reserves as of December 31, 2014, the last time a reserve report was prepared

Proved developed reserves	Gas (MMCF)
Beginning of period	- 0 -
New Discoveries		4,779
Revisions Production		(579	)
End of Period		4,200

ITEM 9:

CHANGES IN AND DISAGREEMENTS WITH ACCOUNTANTS ON ACCOUNTING AND FINANCIAL DISCLOSURE

None.

ITEM 9A

CONTROLS AND PROCEDURES

Conclusion Regarding the Effectiveness of Disclosure Controls and Procedures

Evaluation of Disclosure Controls and Procedures

Our management, with the participation of our Chief Executive Officer and President and our Chief Financial Officer ~~and Treasurer~~, evaluated the effectiveness of our disclosure controls and procedures as of December 31, ~~2014~~2015. 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 our ~~MGP’s~~ Chief Executive Officer and President, and Chief Financial Officer, we have carried out an evaluation of the effectiveness of our disclosure controls and procedures as of the end of the period covered by this report. Based upon that evaluation, our ~~MGP’s~~ Chief Executive Officer and President and Chief Financial Officer, concluded that, at December 31, ~~2014~~2015, our disclosure controls and procedures were effective at the reasonable assurance level.

Changes in Internal Control over Financial Reporting

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

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

PART III

ITEM 10:

DIRECTORS, EXECUTIVE OFFICERS, AND CORPORATE GOVERNANCE

Our MGP manages our activities. Unit holders do not directly or indirectly participate in our management or operation or have actual or apparent authority to enter into contracts on our behalf or to otherwise bind us.

The following table sets forth information as of March 1014, ~~2015~~2016 with respect to those persons who serve as the officers of our MGP:

NAME POSITION OR OFFICE Michael D. Snyder Chief Executive Officer and President ~~Dennis L. Hinderliter Chief Financial Officer and Treasurer~~ Randall L. Morris, Jr. Vice President of Operations ~~Brannon~~Mark PH. ~~McPherson~~Axel ~~Managing~~Chief ~~Vice~~Financial ~~President~~Officer Michael S. Knapp Vice President of Land & Public Relations Adam W. Zellman Vice President of Natural Gas Operations Jason C. Knapp Vice President of Partnership Administration and Secretary

With respect to the biographical information set forth below, the approximate amount of an individual’s professional time devoted to the business and affairs of the MGP and its affiliates, including MDS Energy, ~~Ltd.,~~ M/D Gas, Inc., and First Class Energy, have been aggregated.

Michael D. Snyder, age 3031, has served as the Chief Executive Officer and President of the MGP since its formation in February 2011. Mr. Snyder has over ten years of experience in all phases of natural gas ~~and oil~~ exploration and development in western Pennsylvania. He also serves as the Chief Executive Officer and President of ~~MDS Energy Partners GP, LLC since its formation in November 2014.~~ M/D Gas, Inc. since March 2008 and as the sole Director of M/D Gas, Inc. since January 2011. Mr. Snyder previously served as Vice President of M/D Gas, Inc. from its formation in May 2006 until March 2008 and as a director of M/D Gas, Inc. from May 2006 to January 2011. He further serves as President and Chief Executive Officer of First Class ~~Energy, LLC~~ since its formation in December 2007, and President of MDS Associated Companies, Inc. since its formation in January 2008 and sole Director of MDS Associated Companies, Inc. since January 2011. ~~Previously,~~ Mr. Snyder ~~served as a director of MDS Associated Companies, Inc. from January 2008 to January 2011 and as the President of MDS Securities, LLC from February 2012 to June 2012. Mr. Snyder~~ is a son of David E. Snyder, the Chairman, Chief Executive Officer and President of Snyder Brothers, Inc., the brother of Bryan K. Snyder, a Vice President of Snyder Brothers, Inc., a nephew of Mark A. Snyder, the corporate Secretary of Snyder Brothers, Inc. ~~and a cousin Benjamin T~~. ~~Snyder, the Vice President of Marketing of Synder Brothers, Inc.,~~ Mr. Michael Snyder is also an indirect minority shareholder of Snyder Brothers, Inc. There is no minimum amount of time that Mr. Snyder will devote exclusively to the business of MDS Energy Public 2013-A LP. Mr. Snyder devotes approximately 95% of his professional time to the business and affairs of the MGP and its affiliates.

~~Dennis~~ Randall L. ~~Hinderliter~~Morris, Jr., age 5734, has ~~serves~~served as the ~~Chief~~Vice ~~Financial~~President ~~Officer~~of ~~and~~Operations ~~Treasurer~~ of the MGP since ~~August~~July ~~15, 2014~~2012. Mr. ~~Hinderliter~~ Morris also serves as the ~~Chief~~Vice ~~Financial~~President ~~Officer~~of ~~and Treasurer~~ Operations of ~~MDS~~M/D ~~Energy Partners GP~~Gas, ~~LLC since its formation in November 2014~~Inc. and MDS Associated Companies, Inc., ~~First~~since ~~Class~~July ~~Energy, LLC, and M/D Gas, Inc~~2012. Previously, heMr. Morris served as the ~~Chief~~Vice ~~Financial~~President and Chief ~~Officer~~Engineer of ~~Texas~~the ~~Keystone,~~MGP ~~Inc.~~from ~~(“TKI”),~~February a2011 ~~Pittsburgh~~to ~~based~~July ~~exploration~~2012. ~~and~~Mr. ~~production~~Morris ~~company,~~also ~~until~~previously ~~August~~served ~~2014. He Joined TKI~~ as ~~Controller~~the inVice ~~August~~President ~~2000.~~and ~~Prior~~Chief toEngineer of ~~joining~~M/D ~~TKI~~Gas, heInc. ~~had~~and ~~served~~MDS asAssociated ~~Chief~~Companies, ~~Financial~~Inc. ~~Office/Treasurer~~from ~~for~~July ~~Arthur T.~~2008 ~~Walker~~to ~~Estate~~July ~~Corporation,~~2012. aBefore ~~privately~~that ~~held~~he ~~group~~was ofan ~~companies~~Engineer ~~with~~for ~~operations~~General inElectric from ~~natural~~May ~~gas,~~2005 ~~bituminous~~until ~~coal~~April ~~reserves~~2007 and ~~mining~~ ~~and~~he ~~railroad~~was ~~transportation~~a ~~located~~Field inEngineer ~~Western~~Specialist ~~Pennsylvania~~for ~~with~~Northrop ~~whom~~Grumman hefrom ~~worked~~July ~~for~~2004 19until ~~years~~May ~~(known~~2005. inMr. ~~the~~Morris received ~~region~~a asBachelor ~~Shawmut Companies).~~of HeScience ~~received~~degree ~~his~~in ~~B.S.~~Mechanical ~~Degree~~Engineering from ~~Clarion~~The ~~University~~Pennsylvania inState ~~Business~~University ~~Administration~~ in ~~1979~~2004. ~~Mr.~~There ~~Hinderliter~~is ~~has~~no ~~been involved~~minimum ~~with~~amount ~~the Institute~~ of ~~Management~~time ~~Accountants,~~that ~~Independent~~Mr. ~~Oil~~Morris &will ~~Gas~~devote ~~Association~~exclusively ofto ~~Pennsylvania and~~ the ~~Council~~business of ~~Petroleum Accountants~~MDS ~~Societies~~Energy Public 2013-A LP. Mr. ~~Hinderliter~~Morris devotes approximately 100% of his professional time to the business and affairs of the ~~managing~~ ~~general~~MGP ~~partner~~ and its affiliates.

~~Randall L~~Mark H. ~~Morris~~ Axel, ~~Jr.,~~ age 3338, has served as the ~~Vice~~Chief ~~President~~Financial ofOfficer ~~Operations~~ of the MGP since ~~July~~January ~~2012~~2016. ~~Mr.~~Prior ~~Morris~~to ~~also~~January ~~serves~~2016 ~~as the Vice President of Operations of MDS Energy Partners GP, LLC since its formation in November 2014, and M/D Gas, Inc. and MDS Associated Companies, Inc. since July 2012. Previously,~~ Mr. ~~Morris~~Axel served as the ~~Vice~~Controller ~~President and Chief Engineer~~ of the MGP from ~~February 2011~~April to2015 ~~July~~until ~~2012~~January 2016. Mr. ~~Morris~~Axel ~~also~~was ~~previously~~employed ~~served~~ as ~~the~~a ~~Vice~~Controller ~~President~~by ~~and~~Stonehaven ~~Chief Engineer of M/D Gas~~Energy, ~~Inc.~~LLC and ~~MDS~~Mid ~~Associated Companies,~~Atlantic Capital Group, Inc. ~~from~~for ~~July~~11 ~~2008~~years prior to ~~July~~joining ~~2012~~the MGP. ~~Before~~He ~~that he~~ was anresponsible ~~Engineer~~ for ~~General~~the ~~Electric~~day ~~from~~to ~~May~~day ~~2005~~accounting ~~until~~functions ~~April 2007~~ and hereported ~~was~~directly ato the ~~Field~~CEO, ~~Engineer~~CFO ~~Specialist~~and ~~for~~Board ~~Northrop~~of ~~Grumman from July 2004 until May 2005~~Directors. Mr. ~~Morris~~Axel received a Bachelor ~~of Science~~ degree in ~~Mechanical~~Accounting ~~Engineering~~with ~~from~~a ~~The~~minor ~~Pennsylvania~~in ~~State~~Management from Waynesburg University in ~~2004~~2000. There is no minimum amount of time that Mr. ~~Morris~~ Axel will devote exclusively to the business of MDS Energy Public 2013-A LP. Mr. ~~Morris~~Axel devotes approximately 100% of his professional time to the business and affairs of the MGP and its affiliates.

~~Brannon P~~Michael S. ~~McPherson~~ Knapp, age 4333, has served as the ~~Managing~~ Vice President of Land & Public Relations for the MGP since ~~January~~July ~~2013~~2012. Mr. ~~McPherson~~Knapp also serves as ~~Managing~~ the Vice President of Land ~~MDS~~& ~~Energy~~Public ~~Partners~~Relations ~~GP,~~for ~~LLC~~M/D ~~since~~Gas, ~~its~~Inc. ~~formation~~and inMDS ~~November~~Associated ~~2014~~Companies, Inc. ~~Previously,~~since MrJuly 2012. ~~McPherson~~Previously he served as ~~the~~founder ~~Managing~~and ~~Executive Vice~~ President of ~~Partnership~~Knapp ~~Administration~~Acquisitions ~~for~~& ~~the~~Production, ~~MGP~~LLC from December ~~2011~~2009 to ~~December~~July 2012~~. From March 2007 until joining the MGP in December 2011~~, ~~Mr.~~land ~~McPherson~~acquisition ~~was~~agent ~~employed~~for asMDS ~~a Regional Marketing Director by Atlas~~ Energy~~, L.P. He worked~~ asfrom aOctober ~~retirement~~2007 ~~sales~~to ~~consultant~~August 2009 and infounder ~~institutional sales~~ and ~~marketing~~President ~~for~~of ~~the~~OC ~~Teachers~~Pool ~~Insurance~~Management, ~~Annuity~~Inc. ~~Association – College Retirement Equities Fund~~ from ~~January~~March ~~1995~~2005 ~~until~~to ~~March~~October ~~2007~~2008. MrMichael S. ~~McPherson~~Knapp ~~was~~is ~~previously~~a ~~licensed~~brother asof anJason ~~associated~~C. ~~person with ARI Financial Services~~Knapp, ~~Inc.~~the ~~from~~President ~~December~~and ~~2011~~Chief toExecutive ~~December~~Officer ~~2012.~~of ~~Mr.~~MDS ~~McPherson~~Securities, ~~received a B~~LLC.A., ~~degree~~which inserves ~~Writing~~as ~~from Regis~~the ~~College~~dealer-manager inof ~~1994~~this ~~and a M~~offering.~~B.A.~~ ~~degree from Regis University in 1998.~~ There is no minimum amount of time that Mr. ~~McPherson~~Knapp will devote exclusively to the business of MDS Energy Public 2013-A LP. Mr. ~~McPherson~~Knapp devotes approximately 100% of his professional time to the business and affairs of the MGP and its affiliates.

~~Michael S~~Adam W. ~~Knapp~~ Zellman, age 3234, has served as the Vice President of ~~Land~~Natural &Gas ~~Public~~Operations ~~Relations~~ for the MGP since July 2012. Mr. ~~Knapp~~Zellman also serves as the Vice President of ~~Land~~Natural Gas &Operations ~~Public Relations~~ for M/D Gas, Inc. and MDS Associated Companies, Inc. since July 2012. Mr. ~~Knapp~~ ~~also~~Zellman ~~serves~~previously served as ~~Vice~~the ~~President~~Production Manager offor ~~Land & Public Relations of~~ MDS Energy ~~Partners GP, LLC~~ since ~~its~~October ~~formation~~2007. ~~in November 2014~~Mr. ~~Previously~~Zellman hesupervises ~~served~~and ascoordinates ~~founder~~the maintenance and ~~President~~production of ~~Knapp~~natural ~~Acquisitions & Production, LLC~~ gas from ~~December~~vertical ~~2009~~Marcellus toShale ~~July 2012~~wells, ~~land~~in ~~acquisition~~addition ~~agent~~to ~~for~~shallower ~~MDS~~wells ~~Energy,~~drilled ~~Ltd. from October 2007~~ to ~~August~~other ~~2009~~zones ~~and~~or ~~founder~~formations ~~and~~in ~~President~~the ofAppalachian ~~OC Pool Management,~~Basin. ~~Inc~~Mr. ~~from~~Zellman ~~March~~received ~~2005 to October 2008. Michael S. Knapp is~~ a ~~brother~~Bachelor of ~~Jason~~Science C.degree ~~Knapp,~~in ~~the~~Environmental ~~Vice~~Geography ~~President~~from ofIndiana ~~Partnership~~University ~~Administration and~~of ~~Secretary~~Pennsylvania ~~for~~in ~~the MGP~~2005. There is no minimum amount of time that Mr. ~~Knapp~~Zellman will devote exclusively to the business of MDS Energy Public 2013-A LP. Mr. ~~Knapp~~ Zellman devotes approximately 100% of his professional time to the business and affairs of the MGP and its affiliates.

~~Adam W~~Jason C. ~~Zellman~~ Knapp, age 3329, has served as the Vice President of ~~Natural~~Partnership ~~Gas~~Administration ~~Operations~~and Secretary for the MGP since ~~July~~January ~~2012~~2013. Mr. ~~Zellman~~Knapp also serves as the Vice President of ~~Natural~~Partnership ~~Gas~~Administration ~~Operations~~and ~~for~~Secretary of MDS ~~Energy~~Associated ~~Partners GP~~Companies, ~~LLC~~Inc. ~~since its formation in November 2014~~ and M/D Gas, Inc. ~~and~~since ~~MDS~~January ~~Associated~~2013. Mr. ~~Companies,~~Knapp ~~Inc.~~also ~~since~~serves ~~July~~as ~~2012.~~the MrSecretary of First Class. ~~Zellman~~Previously ~~previously~~he served as ~~the~~a ~~Production~~land ~~Manager~~ acquisition agent for MDS Energy, ~~Ltd.~~from ~~since~~July 2010 ~~October~~to ~~2007~~April 2012. Mr. ~~Zellman~~Knapp ~~supervises~~continues ~~and~~to ~~coordinates~~serve ~~the~~as ~~maintenance~~a ~~and~~land ~~production~~manager offor ~~natural~~MDS ~~gas from~~Energy ~~vertical~~Mr. ~~Marcellus~~Knapp ~~Shale~~is ~~wells,~~also insole ~~addition~~Director toof ~~shallower~~MDS ~~wells~~Securities, LLC, ~~drilled~~which toserves ~~other~~as ~~zones~~the ordealer-manager ~~formations~~of inthis ~~the Appalachian Basin~~offering. Mr. ~~Zellman~~Knapp received a Bachelor of ~~Science~~Arts degree in ~~Environmental~~Philosophy ~~Geography~~ from ~~Indiana~~the University of ~~Pennsylvania~~Maryland, College Park in ~~2005~~May 2010. There is no minimum amount of time that Mr. ~~Zellman~~Knapp will devote exclusively to the business of MDS Energy Public 2013-A LP. Mr. ~~Zellman~~ Knapp devotes approximately 100% of his professional time to the business and affairs of the MGP and its affiliates. Jason C. Knapp is a brother of Michael S. Knapp, the Vice President of Land & Public Relations for the MGP.

Jason C. Knapp, age 28, has served as the Vice President of Partnership Administration and Secretary for the MGP since January 2013. Mr. Knapp also serves as the Vice President of Partnership Administration and Secretary of MDS Energy Partners GP, LLC Since its formation in November 2014 and MDS Associated Companies, Inc. and M/D Gas, Inc. since January 2013. Mr. Knapp also serves as the Secretary of First Class Energy, LLC. Previously he served as a land acquisition agent for MDS Energy, Ltd. from July 2010 to April 2012. Mr. Knapp continues to serve as a land manager for MDS Energy, Ltd. Mr. Knapp is also President, Chief Executive Officer, and sole Director of MDS Securities, LLC, which serves as the dealer-manager of this offering. Mr. Knapp received a Bachelor of Arts degree in Philosophy from the University of Maryland, College Park in May 2010. There is no minimum amount of time that Mr. Knapp will devote exclusively to the business of MDS Energy Public 2013-A LP. Mr. Knapp devotes approximately 100% of his professional time to the business and affairs of the MGP and its affiliates. Jason C. Knapp is a brother of Michael S. Knapp, the Vice President of Land & Public Relations for the MGP.

ITEM 11:

EXECUTIVE COMPENSATION

Compensation Discussion and Analysis

Introduction

We do not directly employ any persons to manage or operate our businesses. Instead, all of the persons (including executive officers of our MGP and other personnel) necessary for the management of our business are employed and compensated by MDS Associated Companies, Inc. Pursuant to our partnership agreement, our MGP manages our operations and activities through its affiliates’ employees (including employees of the ~~MDS~~MGP ~~Energy, Ltd.~~ and ~~First~~MDS ~~Class~~ Energy~~, LLC~~). No officer or director of our MGP receives any direct enumeration or other compensation from us. (see “Item 13: Certain Relationships and Related Transactions” for a discussion of compensation paid by us to our MGP).

ITEM 12:

SECURITY OWNERSHIP OF CERTAIN BENEFICIAL OWNERS AND MANAGEMENT

As of December 31, ~~2014~~2015, we had 1,500.10 units outstanding. No officer or director of our MGP owns any units, with the exception of ~~our~~the ~~MGP’s~~ CEO and President ~~who~~ owns 28.4 units. Although, subject to certain conditions, investor partners may present their units to us beginning with the fifth calendar year after the partnership closes for purchase, our MGP is not obligated by the Partnership Agreement to purchase more than 5% of our total outstanding units in any calendar year. Our MGP is owned 100% by MDS Associated Companies, Inc. ~~Also, the repurchase feature may be suspended by our MGP at any time if it determines that we do not have the necessary cash flow or cannot borrow funds for this purpose on reasonable terms.~~

ITEM 13:

CERTAIN RELATIONSHIPS AND RELATED TRANSACTIONS, AND DIRECTOR INDEPENDENCE

~~Oil and~~ Natural Gas Revenues. - Our MGP is allocated approximately 16.1% of our oil and gas revenues in return for its payment and/or contribution of services towards our syndication and offering costs equal to 8% of our subscriptions, and its contributions to us of all of the oil and gas leases for a total capital contribution of $1,325,067. During the year ended December 31, ~~2014~~2015, our MGP received revenues of approximately $0 ~~223,000~~ from our net production revenues, due to subordination to Investors, compared to the MGP receiving $98,300 of revenues during year ended December 31, 2014.

~~Leases. Following the~~Well ~~final~~Charges ~~closing~~- ~~date~~Our ~~for~~MGP, ~~the~~as ~~offering~~ operator of our ~~units~~wells, tois ~~potential~~reimbursed ~~investors,~~at ~~which~~actual ~~was~~cost ~~December~~for ~~31,~~all ~~2013~~direct expenses incurred on our ~~MGP~~behalf ~~contributed~~and receives well supervision fees for ~~oil~~operating and ~~gas~~maintaining ~~leases~~the towells usduring ~~covering~~producing 13operations ~~undeveloped~~in ~~prospects~~the ~~for~~amounts ~~the~~of ~~wells~~$800 weper ~~drilled~~well ~~and~~per ~~our~~month ~~MGP~~subject ~~received~~to aan ~~credit~~annual adjustment for inflation. The well supervision fees are proportionately reduced to ~~its~~the extent we acquire less than 100% of the ~~capital~~working ~~account~~interest in a well. For the ~~amount~~year ofended December 31, 2015 and 2014, our MGP received $~~124~~85,~~987~~600 and $74,400 respectively, for well supervision fees.

~~Drilling Contracts. After~~Transportation ~~the~~Fee ~~closing~~- ~~date~~We ofwill ~~the~~pay gathering ~~offering~~fees ofto our ~~units~~MGP, toand ~~investors,~~other werelated ~~entered~~party ~~into~~companies aincluding ~~drilling~~Snyder ~~contract~~Brothers, ~~with~~Inc., ~~our~~MDS ~~MGP~~Energy, toFurnace ~~drill~~Run Pipeline, LP, and ~~complete~~Mushroom ~~approximately~~Farm 14Pipeline, ~~gross~~LP ~~and~~at ~~net~~a ~~wells~~competitive onrates for each MCF of our ~~behalf~~natural gas transported. ~~The~~For ~~total~~the ~~amount~~years ~~paid~~ended toDecember 31, ~~our~~2015 ~~MGP~~and ~~for~~2014, ~~drilling~~gathering ~~and~~fees ~~completing~~of ~~the~~approximately ~~wells~~$167,000 ~~was~~and $15224,~~001,~~000 ~~for~~respectively, ~~the~~were ~~year~~paid ~~ended~~to ~~December~~our ~~31,~~MGP ~~2013~~or to affiliated companies.

~~Well Charges. Our~~Accounting ~~MGP,~~Fee as– ~~operator~~The ofPartnership pays ~~our wells, is reimbursed at actual cost for all direct expenses incurred on our behalf and receives well supervision fees for operating and maintaining~~ the ~~wells~~costs ~~during~~associated ~~producing~~with ~~operations~~filing in the ~~amount~~tax ofreturns ~~$800~~and ~~per~~audits ~~well~~directly ~~per month subject~~ to antheir ~~annual~~outside ~~adjustment~~independent ~~for~~audit ~~inflation~~firm. ~~The~~During ~~well supervision fees are proportionately reduced to the extent we acquire less than 100% of the working interest in a well. For the~~ year ended December 31, ~~2014~~2015 and ~~2013~~December 31, ~~our~~2014 ~~MGP~~the ~~received~~Partnership paid $ 7463,~~400~~000 and $ ~~-0-~~10,700 respectively, for ~~well~~accounting ~~supervision~~ fees.

~~Dealer-Manager Fees. As~~Subordination ~~part~~– ofThe ~~the~~MGP ~~offering~~during year ofended ~~our~~2015, ~~units~~was tostill ~~potential~~subordinating ~~investors,~~revenues ~~MDS~~to ~~Securities,~~the ~~LLC,~~Partnership anper ~~affiliate~~the ofoffering ~~our~~documents. The MGP ~~and~~ ~~the~~received ~~dealer-manager~~$0 ofin ~~our~~revenues during ~~initial~~2015 ~~offering,~~compared ~~received~~to areceiving 3%$98,300 ~~dealer-manager~~in ~~fee~~2014. ~~and~~The alow 7%commodity ~~sales~~prices ~~commission~~have ~~for~~resulted ain ~~total syndication~~the ~~offering~~need ~~fee~~for ~~amount~~greater ofsubordination by ~~$1,420,660~~the MGP.

Transportation Fee. We pay gathering fees to our MGP, and other affiliated companies including Snyder Brothers, Inc., MDS Energy, Ltd., Furnace Run Pipeline, LP, and Mushroom Farm Pipeline, LP at a competitive rates for each MCF of our natural gas transported. For the years ended December 31, 2014 and 2013, gathering fees of approximately $ 224,000 and $ -0- respectively, were paid to our MGP or to affiliated companies.

Other Compensation. - For the year ended December 31, ~~2013~~2015 our MGP ~~advanced~~did advance funds to us, ~~for~~and ~~a short period at~~ the ~~end~~funds ofadvanced ~~the~~have ~~year.~~not ~~The~~been ~~funds advanced were~~ repaid byas ~~January~~of 27February 29, ~~2014.~~2016

ITEM 14:

PRINCIPAL ACCOUNTANT FEES AND SERVICES

For the years ended December 31, ~~2014~~2015 and ~~2013~~ 2014, the accounting fees and services charged by our independent registered auditors, Schneider Downs & Co., Inc., were as follows:

	Years Ended December 31,
	2014		2013
	2015			2014
Audit fees	$	2063,000		~~44,500~~$	11,000

Audit Committee Pre-Approval Policies and Procedures

We do not have an ~~audit~~Audit ~~committee~~Committee nor does our MGP. On at least an annual basis, our MGP’s CEO &and President and Chief Financial Officer will review audit and non-audit services performed by Schneider Downs & Co., Inc. as well as the fees charged by Schneider Downs & Co., Inc. for such services. Our policy is that all audit and non-audit services must be pre-approved by our MGP’s CEO &and President and Chief Financial Officer. All of such services and fees were pre- approved during ~~2014~~2015 and ~~2013~~2014.

PART IV

ITEM 15:

EXHIBITS AND FINANCIAL STATEMENT SCHEDULES

Description	~~Location~~	Location
Certificate of Limited Partnership for MDS Energy Public 2013-A, LP (1)	~~Previously filed on our Form S-1~~	Previously filed on our Form S-1
Amended and Restated Certificate and Agreement of Limited Partnership for MDS Energy Public 2013-A, LP (1)	~~Previously filed on our Form S-1~~	Previously filed on our Form S-1
Drilling and Operating Agreement for MDS Energy Public 2013-A, LP (1)	~~Previously filed on our Form S-1~~	Previously filed on our Form S-1
(1) Filed on (June 8, 2012) in the Form S-1 Registration Statement dated June 8, 2012, File No. ###-##-####

(1)

Filed on (June 8, 2012) in the Form S-1 Registration Statement dated (June 8, 2012), File No. ###-##-####

EXHIBIT INDEX

Exhibit No.	Description
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	Filed herewith
32	Section 1350 Certification of Principal Executive Officer and Principal Financial Officer.	Filed herewith

SIGNATURES

Pursuant to the requirements of the Securities 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

MDS ENERGY PUBLIC 2013 - A LP

	MDS Energy Development, LLC, its Managing General Partner

Date: March 14, 2016		/s/ Michael D. Snyder
		Michael D. Snyder, Chief Executive Officer and President

Date: March 14, 2016		/s/ Mark H Axel
		Mark H Axel, Chief Financial Officer

	MDS Energy Development, LLC, its Managing General Partner
Date: March 13, 2015		/s/ Michael D. Snyder
		Michael D. Snyder, Chief Executive Officer and President
Date: March 13, 2015		/s/ Dennis L. Hinderliter
		Dennis L. Hinderliter, Chief Financial Officer

Filing Compare · MDS ENERGY PUBLIC 2013-A LP