UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

WASHINGTON, D.C. 20549

FORM 10-K

☒

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

For the year ended December 31, ~~2015~~2016

☐

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

For the transition period from ~~_______________~~ ____________ to ~~_________________~~____________

Commission File No. 333-85994-01

MEWBOURNE ENERGY PARTNERS 03-A, L.P.

Delaware		27-0055431
(State or jurisdiction of incorporation or organization)		(I.R.S. Employer Identification Number)
3901 South Broadway, Tyler, Texas		75701
(Address of principal executive offices)		(Zip code)
Registrant’s Telephone Number, including area code:	(903) 561-2900

3901 South Broadway, Tyler, Texas		75701
(Address of principal executive offices)		(Zip code)
Registrant’s Telephone Number, including area code:	(903) 561-2900

Securities registered pursuant to Section 12(b) of the Act: None.

Securities registered pursuant to section 12(g) of the Act:

Limited Partner Interests (Title of class) General Partner Interests (Title of class)

(Title of class)

General Partner Interests

(Title of class)

Indicate by check mark if the registrant is a well-known seasoned issuer, as defined in Rule 405 of the Securities Act.

Yes ☐ No ☒

Indicate by check mark if the registrant is not required to file reports pursuant to Section 13 or 15(d) of the Act.

Yes ☐ No ☒

Note: Checking the box above will not relieve any registrant required to file reports pursuant to Section 13 or 15 (d) of the Exchange Act from their obligations under those Sections.

Indicate by check mark whether the registrant (1) has filed all reports required to be filed by Section 13 of 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 ☒ No ☐

Indicate by check mark if disclosure of delinquent filers pursuant to Item 405 of Regulation S-K is not contained herein, and will not be contained, to the best of the registrant’s knowledge, in definitive proxy or information statements incorporated by reference in Part III of this Form 10-K or any amendment to this Form 10-K. ☒

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 ☒ 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 definitions of “large accelerated filer”, “accelerated filer” and “smaller reporting company” in Rule 12b-2 of the Exchange Act. (Check one):

Large accelerated filer ☐		Accelerated filer	☐
Non-accelerated filer ☐	(Do not check if a smaller reporting company)	Smaller reporting company	☒

Indicate by check mark if the registrant is a shell company (as defined in Rule 12b-2 of the Exchange Act).

Yes ☐ No ☒

No market currently exists for the limited partner interests of the Registrant. Based on original purchase price the aggregate market value of limited and general partner interests owned by non-affiliates of the Registrant is $18,000,000.

The following documents are incorporated by reference into the indicated parts of this Annual Report on Form 10-K: Part of the information called for by Part IV of the Annual Report on Form 10-K is incorporated by reference from the Registrant’s Registration Statement on Form S-1, File No. 333-85994-01.

MEWBOURNE ENERGY PARTNERS 03-A, L.P.
INDEX
Part I
	Item 1.	Business
	Item 1A.	Risk Factors
	Item 1B.	Unresolved Staff Comments
	Item 2.	Properties
	Item 3.	Legal Proceedings
	Item 4.	Mine Safety Disclosure
Part II
	Item 5.	Market for Registrant's Common Equity and Related Stockholder Matters
	Item 6.	Selected Financial Data
	Item 7.	Management's Discussion and Analysis of Financial Condition and Results of Operations
	Item 7A.	Quantitive and Qualitative Disclosures about Market Risk
	Item 8.	Financial Statements and Supplementary Data
	Item 9.	Changes in and Disagreements with Accountants on Accounting and Financial Disclosure
	Item 9A.	Controls and Procedures
Part III
	Item 10.	Directors and Executive Officers of the Registrant
	Item 11.	Executive Compensation
	Item 12.	Security Ownership of Certain Beneficial Owners and Management
	Item 13.	Certain Relationships and Related Transactions
	Item 14.	Principal Accountant Fees and Services
Part IV
	Item 15.	Exhibits, Financial Statements, Financial Statement Schedules and Reports on Form 8K
SIGNATURES
INDEX TO EXHIBITS
Certification of CEO Pursuant to Section 302
Certification of CFO Pursuant to Section 302
Certification of CEO Pursuant to Section 906
Certification of CFO Pursuant to Section 906
Report of Forrest A. Garb & Associates, Inc.

MEWBOURNE ENERGY PARTNERS 03-A, L.P.

INDEX

Part I			3
	Item 1.	Business	3
	Item 1A.	Risk Factors	4
	Item 1B.	Unresolved Staff Comments	6
	Item 2.	Properties	6
	Item 3.	Legal Proceedings	7
	Item 4.	Mine Safety Disclosure	7
Part II			8
	Item 5.	Market for Registrant’s Common Equity and Related Stockholder Matters	7
	Item 6.	Selected Financial Data	7
	Item 7.	Management’s Discussion and Analysis of Financial Condition and Results of Operations	7
	Item 7A.	Quantitative and Qualitative Disclosures about Market Risk	11
	Item 8.	Financial Statements and Supplementary Data	11
	Item 9.	Changes in and Disagreements with Accountants on Accounting and Financial Disclosure	12
	Item 9A.	Controls and Procedures	12
Part III			17
	Item 10.	Directors and Executive Officers of the Registrant	13
	Item 11.	Executive Compensation	14
	Item 12.	Security Ownership of Certain Beneficial Owners and Management	14
	Item 13.	Certain Relationships and Related Transactions	15
	Item 14.	Principal Accountant Fees and Services	15
Part IV			23
	Item 15.	Exhibits, Financial Statements, Financial Statement Schedules and Reports on Form 8K	16
	Item 16.	Form 10-K Summary	16

SIGNATURES			17
INDEX TO EXHIBITS			28
Certification of CEO Pursuant to Section 302
Certification of CFO Pursuant to Section 302
Certification of CEO Pursuant to Section 906
Certification of CFO Pursuant to Section 906
Report of Forrest A. Garb & Associates, Inc.

PART I

ITEM 1. Business

Mewbourne Energy Partners 03-A, L.P. (the “Registrant” or the “Partnership”) is a limited partnership organized under the laws of the State of Delaware on February 19, 2003 (date of inception). Mewbourne Development Corporation (“MD”), a Delaware Corporation, has been appointed as the Registrant’s managing general partner. MD has no significant equity interest in the Registrant.

A Registration Statement was filed pursuant to the Securities Act of 1933, as amended, registering limited and general partnership interests in a series of two Delaware limited partnerships formed under Mewbourne Energy 02-03 Drilling Programs. General and limited partnership interests were offered at $1,000 each. The maximum offering amount was $18,000,000 (18,000 interests) per partnership. The Registration Statement was declared effective by the Securities and Exchange Commission on(“SEC”) on May 16, 2003. On July 9, 2003, the offering of limited and general partnership interests in the Registrant was closed, with interests aggregating $18,000,000 originally being sold to 710 subscribers of which $16,107,005 were sold to 644 subscribers as general partner interests and $1,892,995 were sold to 66 subscribers as limited partner interests. During 2005 all general partner equity interests were converted to limited partner interests.

The Partnership participates in oil and gas activities through a Drilling Program Agreement (the “Program”). The Partnership and MD are parties to the Program Agreement. The Registrant engages primarily in oil and gas development and production and is not involved in any other industry segment. The Program is governed by a Drilling Program Agreement between the Registrant, MD and Mewbourne Oil Company (“MOC”), the program manager and a wholly owned subsidiary of Mewbourne Holdings, Inc., which is also the parent of MD. MD does not make any capital contributions directly to the Registrant; rather, MD makes its capital contributions directly to the Program. See the financial statements in Item 8 of this report for a summary of the Registrant’s revenue, income and identifiable assets.

The sale of crude oil and ~~natural~~ gas produced by the Registrant will be affected by a number of factors that are beyond the Registrant’s control. These factors include the price of crude oil and ~~natural~~ gas, the fluctuating supply of and demand for these products, competitive fuels, refining, transportation, extensive federal and state regulations governing the production and sale of crude oil and ~~natural~~ gas, and other competitive conditions. It is impossible to predict with any certainty the future effect of these factors on the Registrant.

The market for crude oil is such that the Registrant anticipates it will be able to sell all the crude oil it can produce. ~~Natural~~Gas ~~gas~~ will be sold to gas marketers and end users on the spot market. The spot market reflects immediate sales of ~~natural~~ gas without long-term contractual commitments. The future market condition for ~~natural~~ gas cannot be predicted with any certainty, and the Registrant may experience delays in marketing ~~natural~~ gas production and fluctuations in ~~natural~~ gas prices.

Many aspects of the Registrant’s activities are highly competitive including, but not limited to, the acquisition of suitable drilling prospects and the procurement of drilling and related oil field equipment, and are subject to governmental regulation, both at Federal and state levels. The Registrant’s ability to compete depends on its financial resources and on the managing general partner’s staff and facilities, none of which are significant in comparison with those of the oil and gas exploration, development and production industry as a whole. Federal and state regulation of oil and gas operations generally includes operational activity, drilling and spacing of wells on producing acreage, the imposition of maximum allowable production rates, the taxation of income and other items, and the protection of the environment.

The Registrant does not have any employees of its own. MD is responsible for all management functions. ~~Mewbourne Oil Company (“~~MOC”), a wholly owned subsidiary of Mewbourne Holdings, Inc., which is also the parent of the Registrant’s managing general partner, has been appointed Program Manager and is responsible for activities in accordance with a Drilling Program Agreement entered into by the Registrant, MD and MOC. At March 3031, ~~2016~~2017, MOC employed ~~395~~399 persons, many of whom dedicated a part of their time to the conduct of the Registrant’s business during the period for which this report is filed.

The production of oil and gas is not considered subject to seasonal factors although the price received by the Registrant for ~~natural~~ gas sales will generally tend to increase during the winter months. Order backlog is not pertinent to the Registrant’s business.

ITEM 1A. Risk Factors

Oil and ~~natural~~ gas prices are volatile. An absence of significant price increases could adversely affect the Registrant’s financial position, financial results, and cash flows.

Revenues, operating results, and profitability depend primarily upon the prices received for oil and ~~natural~~ gas sales. Prices also affect the amount of cash flow available for distribution. Absent significant price increases, cost ceiling write-downs may be necessary in the future.

Historically, the markets for oil and ~~natural~~ gas have been volatile and they are likely to continue to be volatile. Wide fluctuations in oil and ~~natural~~ gas prices may result from relatively minor changes in the supply of and demand for oil and ~~natural~~ gas, market uncertainty and other factors that are beyond the Registrant’s control, including:

· • worldwide and domestic supplies of oil and ~~natural~~ gas;

· • weather conditions;

· • the level of consumer demand;

· • the price and availability of alternative fuels;

· • the proximity, accessibility and capacity of ~~natural~~ gas pipelines and other transportation facilities;

· • regional imbalances in supply and demand;

· • the price and level of foreign imports;

· • domestic and foreign governmental regulations and taxes;

· • the ability of the members of the Organization of Petroleum Exporting Countries to agree to and maintain oil price and production controls;

· • political instability or armed conflict in oil-producing regions; and

· • overall domestic and global economic conditions.

These factors and the volatility of the energy markets make it extremely difficult to predict future oil and ~~natural~~ gas price movements with any certainty. Declines in oil and ~~natural~~ gas prices would not only reduce revenue, but could reduce the amount of oil and ~~natural~~ gas that can be produced economically and, as a result, could have a material adverse effect on the Registrant’s financial condition, results of operations and reserves. For the year ended December 31, ~~2015~~2016, a 10% change in the price received for oil and gas production would have had an approximate $3125,000 impact on revenue.

The actual quantities and present value of proved reserves may prove to be lower than estimated.

This report contains estimates of proved reserves. These estimates are based upon various assumptions, including assumptions required by the SEC relating to oil and ~~natural~~ gas prices, drilling and operating expenses, capital expenditures, taxes and availability of funds. The process of estimating oil and ~~natural~~ gas reserves is complex. The process involves significant decisions and assumptions in the evaluation of available geological, geophysical, engineering and economic data for each reservoir. Therefore, these estimates are inherently imprecise.

Actual future production, oil and ~~natural~~ gas prices, revenues, taxes, development expenditures, operating expenses and quantities of recoverable oil and ~~natural~~ gas reserves most likely will vary from these estimates. Such variations may be significant and could materially affect the estimated quantities and present value of proved reserves. In addition, the Registrant may adjust estimates of proved reserves to reflect production history, results of exploration and development drilling, prevailing oil and ~~natural~~ gas prices and other factors, many of which are beyond the Registrant’s control. The Registrant’s properties may also be susceptible to hydrocarbon drainage from production by operators on adjacent properties.

The absence of significant future price increases may result in a write-down of asset carrying values.

The Registrant utilizes the full-cost method of accounting for costs related to oil and ~~natural~~ gas properties. Under this method, all such costs (for both productive and nonproductive properties) are capitalized and amortized on an aggregate basis over the estimated lives of the properties using the unit-of-production method. However, these capitalized costs are subject to a ceiling test which limits such pooled costs to the aggregate of the present value of future net revenues attributable to proved oil and ~~natural~~ gas reserves discounted at 10% plus the lower of cost or market value of unproved properties. The full-cost ceiling is evaluated at the end of each quarter using the oil and gas pricing guidelines established by the ~~Securities and Exchange Commission~~SEC. The absence of significant price increases in oil and ~~natural~~ gas prices from current levels or the presence of other factors, without other mitigating circumstances, could cause a future write-down of capitalized costs and a non-cash charge against future earnings.

The Registrant’s ceiling test calculations indicated animpairments ~~impairment~~ of oil and ~~natural~~ gas properties of $164,474 and $775,067 during the years ~~year~~ ended December 31, ~~2015~~2016 and ~~no impairment during the year ended December 31~~2015, ~~2014~~respectively.

Oil and ~~natural~~ gas drilling and producing operations can be hazardous and may expose the Registrant to environmental liabilities.

Oil and ~~natural~~ gas operations are subject to many risks, including well blowouts, cratering and explosions, pipe failure, fires, formations with abnormal pressures, uncontrollable flows of oil, ~~natural~~ gas, brine or well fluids, and other environmental hazards and risks. If any of these risks occurs, the Registrant could sustain substantial losses as a result of:

· • injury or loss of life;

· • severe damage to or destruction of property, natural resources and equipment;

· • pollution or other environmental damage;

· • clean-up responsibilities;

· • regulatory investigations and administrative, civil and criminal penalties; and

· • injunctions resulting in limitation or suspension of operations.

There is inherent risk of incurring significant environmental costs and liabilities in exploration and production operations due to generation, handling, and disposal of materials, including wastes and petroleum hydrocarbons. The Registrant may incur joint and several, strict liability under applicable U.S. federal and state environmental laws in connection with releases of petroleum hydrocarbons and wastes on, under or from leased or owned properties, some of which have been used for oil and ~~natural~~ gas exploration and production activities for a number of years, often by third parties not under the Registrant’s control. While the Registrant maintains insurance against some, but not all, of the risks described above, the Registrant’s insurance may not be adequate to cover casualty losses or liabilities. Also, in the future the Registrant may not be able to obtain insurance at premium levels that justify its purchase.

In addition, in response to studies suggesting that emissions of certain gases may be contributing to warming of the earth’s atmosphere, many states are beginning to consider initiatives to track and record these gases, generally referred to as “greenhouse gases,” with several states having already adopted regulatory initiatives aimed at reducing emissions of greenhouse gases. Methane, a primary component of ~~natural~~ gas, and carbon dioxide, a byproduct of the burning of ~~natural~~ gas, are included among the types of gases targeted by greenhouse gas initiatives and laws. This movement is in its infancy but regulatory initiatives or legislation placing restrictions on emissions of methane or carbon dioxide that may be imposed in various states of the United States could adversely affect operations of oil and gas wells and the demand for oil and gas products.

ITEM 1B. Unresolved Staff Comments

None.

ITEM 2. Properties

Property Interests

The Registrant’s properties consist primarily of interests in properties on which oil and gas wells are located. Such property interests are often subject to landowner royalties, overriding royalties and other oil and gas leasehold interests.

Fractional working interests in developmental oil and gas prospects, located primarily in the Anadarko Basin of Western Oklahoma, the Texas Panhandle, and the Permian Basin of New Mexico and West Texas, were acquired by the Registrant, resulting in the Registrant’s participation in the drilling of oil and gas wells. At December 31, ~~2015~~2016, the Registrant owned working interests in seventy-two producing wells. The Registrant had no drilling activity for the years ended December 31, ~~2015~~2016 and ~~2014~~2015.

Third Party Review of Reserves Estimate

The reserves estimate shown herein has been independently evaluated by Forrest A. Garb & Associates, Inc. Their reserves estimate is filed with this report as Exhibit 99.1. The qualifications of William Donald Harris III, P.E., the technical person primarily responsible for overseeing his firm’s preparation of the Partnership’s reserve estimates are set forth below.

·• Over 25 years of practical experience in petroleum engineering ~~· Registered professional engineer in the state of Texas · Bachelor of Science Degree in Petroleum Engineering · Master of Business Administration~~

6• Registered professional engineer in the state of Texas

~~Internal~~• ~~Controls~~Bachelor ~~Over~~of ~~Reserves~~Science ~~Estimate~~Degree in Petroleum Engineering

~~MD,~~• ~~the~~Master ~~Registrant’s managing general partner, maintains internal controls such as the following to ensure the reliability~~ of ~~reserves~~Business ~~estimation:~~Administration

· No employee’s compensation is tied to the amount of reserves booked. · Comprehensive SEC-compliant internal policies are followed to determine and report proved reserves. · Reserves estimate is made by experienced reservoir engineers or under their direct supervision. · The reservoir engineers review all the Partnership’s reported proved reserves at the close of each quarter. 6

~~ITEM~~Internal Controls ~~3. Legal~~Over ~~Proceedings~~Reserves Estimate

~~From time to time~~MD, the Registrant’s ~~may~~managing begeneral ~~a party~~partner, tomaintains ~~certain~~internal ~~legal~~controls ~~actions~~such ~~and~~as ~~claims arising in~~ the ~~ordinary~~following ~~course~~to ofensure ~~business. While~~ the ~~outcome~~reliability of ~~these events cannot~~ bereserves ~~predicted with certainty, the Partnership does not expect these matters to have a material effect on its financial position or results of operations.~~estimation:

~~ITEM~~• ~~4. Mine~~No ~~Safety~~employee’s ~~Disclosure~~compensation is tied to the amount of reserves booked.

~~Not~~• ~~Applicable~~Comprehensive SEC-compliant internal policies are followed to determine and report proved reserves.

~~PART~~• IIReserves estimate is made by experienced reservoir engineers or under their direct supervision.

~~ITEM~~• ~~5. Market~~The ~~for~~reservoir ~~Registrant~~engineers review all the Partnership’s ~~Common~~ ~~Equity~~reported ~~and~~proved ~~Related~~reserves ~~Stockholder~~at ~~Matters~~the close of each quarter.

~~At March 30, 2016, the Registrant had 18,000~~ITEM ~~outstanding limited partnership interests held of record by 710 subscribers~~3. Legal ~~There is no established public or organized trading market for the partner interests.~~Proceedings

~~Revenues which, in the sole judgment of the~~From ~~managing~~time ~~general~~to ~~partner~~time, ~~are not required to meet~~ the Registrant’s ~~obligations~~may ~~will~~ be ~~distributed~~a party to ~~the~~certain ~~partners~~legal atactions ~~least quarterly~~and inclaims ~~accordance~~arising ~~with~~in the ~~Registrant’s~~ordinary ~~Partnership~~course ~~Agreement~~of business. ~~Distributions~~While the ~~made~~outcome toof ~~partners~~these ~~during~~events ~~the~~cannot ~~years~~be ~~ended December~~predicted 31with certainty, ~~2015~~the ~~and~~Partnership ~~2014~~does ~~were~~not ~~$26,816~~expect ~~and~~these ~~$299,792,~~matters ~~respectively.~~to ~~Since~~have ~~inception,~~a ~~the~~material effect ~~Partnership~~on ~~has~~its ~~made~~financial ~~distributions~~position ~~of $20,448,648,~~or ~~inclusive~~results of ~~state tax payments~~operations.

ITEM 6 4. ~~Selected~~ Mine ~~Financial~~Safety ~~Data~~Disclosure

Not ~~required under Regulation S-K, Item 301 for smaller reporting~~ ~~companies.~~Applicable

~~ITEM 7. Management’s~~PART ~~Discussion and Analysis of Financial Condition and Results of Operations~~II

~~General~~ITEM 5. Market for Registrant’s Common Equity and Related Stockholder Matters

~~The Registrant was organized as a Delaware~~At ~~limited~~March ~~partnership~~31, ~~on February 19~~2017, ~~2003.~~the ~~The~~Registrant ~~offering~~had of18,000 outstanding limited ~~and general~~ partnership interests ~~began~~held ~~May 16, 2003 as a part~~ of anrecord ~~offering~~by ~~registered~~710 ~~under the name Mewbourne Energy Partners 02-03 Drilling Programs~~subscribers. ~~The~~There ~~offering of limited and general~~is ~~partner~~no ~~interests~~established inpublic ~~the~~or ~~Registrant~~organized ~~concluded~~trading ~~July~~market 9,for ~~2003,~~the ~~with total investor~~ partner ~~contributions of $18,000,000~~interests.

~~The~~Revenues which, ~~Registrant~~in ~~was~~the ~~formed~~sole tojudgment ~~engage~~of ~~primarily in~~ the ~~business~~managing ofgeneral ~~drilling~~partner, ~~development~~are ~~wells,~~not required to ~~produce~~meet ~~and~~the ~~market~~Registrant’s ~~crude~~obligations ~~oil~~will be ~~and~~distributed ~~natural~~to ~~gas~~the ~~produced~~partners ~~from~~at ~~such~~least ~~properties,~~quarterly ~~to distribute~~in ~~any~~accordance ~~net~~with ~~proceeds~~the ~~from~~Registrant’s ~~operations~~Partnership Agreement. Distributions made to partners and state tax payments for the ~~general~~benefit ~~and~~of ~~limited~~investor partners ~~and~~during to the ~~extent~~years ~~necessary~~ended December 31, ~~acquire~~2016 ~~leases~~and ~~which~~2015 ~~contain~~were ~~drilling~~$2,661 ~~prospects~~and $26,816, respectively. ~~The~~No ~~economic~~distributions ~~life~~to ofpartners were made during the ~~Registrant~~year ~~depends~~ended onDecember 31, 2016. Since inception, the ~~period~~Partnership ~~over~~has ~~which~~made ~~the~~distributions ~~Registrant’s~~of ~~oil~~$20,451,310, ~~and gas~~inclusive ~~reserves~~of ~~are~~state ~~economically~~tax ~~recoverable~~payments.

7ITEM 6. Selected Financial Data

~~Results~~Not required ofunder ~~Operations~~Regulation S-K, Item 301 for smaller reporting companies.

~~The following is a comparative discussion of~~ITEM ~~the results of operations for the periods indicated~~7. ItManagement’s ~~should~~Discussion ~~be read in conjunction with the financial statements~~ and ~~the~~Analysis ~~related notes to the financial statements, which begin on page 20. As a result~~ of ~~declines~~Financial inCondition ~~prices~~and ~~for~~Results ~~commodities, the results~~ of ~~our operations for 2015 may not be indicative of results in 2016 as realized prices for production may remain low or continue to decline.~~Operations

~~Year ended December 31, 2015 compared to the year ended December 31, 2014:~~General

	Year Ended December 31,
	2015		2014
Oil sales	$	69,321	$	200,636
Barrels produced		1,571		2,363
Average price/bbl	$	44.13	$	84.91
Gas sales	$	235,773	$	511,128
Mcf produced		107,264		118,431
Average price/mcf	$	2.20	$	4.32

The Registrant was formed to engage primarily in the business of drilling development wells, to produce and market crude oil and gas produced from such properties, to distribute any net proceeds from operations to the general and limited partners and to the extent necessary, acquire leases which contain drilling prospects. The economic life of the Registrant depends on the period over which the Registrant’s oil and gas reserves are economically recoverable.

~~Oil and gas revenues. As shown in the above table, total oil and gas sales decreased by $406,670, a 57.1% decline, for the year ended December 31, 2015 as compared to the year ended December 31, 2014.~~ 7

~~Of this decline, $96,368 and $250,809 were~~Results ~~due to decreases in the average prices~~ of oil and gas sold, respectively. The average price fell to $44.13 from $84.91 per barrel (bbl) and to $2.20 from $4.32 per thousand cubic feet (mcf) for the year ended December 31, 2015 as compared to the year ended December 31, 2014.Operations

~~Also~~The following ~~contributing~~is toa comparative discussion of the ~~decline~~results inof ~~sales~~operations ~~were~~for the periods indicated. It should be read in conjunction ~~$34,947~~with the financial statements and ~~$24,546~~the ~~due~~related notes to ~~lower~~the ~~volumes~~financial statements, which begin on page 20. As a result of ~~oil~~declines in ~~and~~prices ~~gas~~for ~~sold~~commodities, ~~respectively,~~the byresults ~~792~~of ~~bbls~~operations ~~and~~for ~~11,167~~2016 ~~mcf~~may not be indicative of results in 2017 as realized prices for production may remain low or continue to decline.

~~Lease operations. Lease operating expense during~~Year ~~the year~~ ended December 31, ~~2015~~2016 ~~decreased~~compared to ~~$309,550 from $330,198 for~~ the year ended December 31, ~~2014 due to fewer well repairs and workovers.~~2015:

Production taxes. Production taxes during the year ended December 31, 2015 decreased to $20,689 from $49,182 for the year ended December 31, 2014. This was due to lower overall oil and gas revenue for the year ended December 31, 2015.

	Year Ended December 31,
	2016		2015
Oil sales	$	53,479	$	69,321
Barrels produced		1,431		1,571
Average price/bbl	$	37.37	$	44.13

Gas sales	$	200,754	$	235,773
Mcf produced		101,050		107,264
Average price/mcf	$	1.99	$	2.20

~~Administrative~~ Oil and ~~general~~gas ~~expense~~revenues. ~~Administrative and~~As ~~general~~shown ~~expense~~in ~~for~~ the ~~year~~above ~~ended~~table, ~~December~~total ~~31,~~oil ~~2015~~and ~~fell~~gas tosales decreased by $4150,~~971~~861, ~~from~~a ~~$52~~16.7% decline,~~372~~ for the year ended December 31, ~~2014~~2016 ~~due to~~as ~~decreased~~compared ~~administrative~~to ~~expenses~~the ~~allocable~~year toended ~~the~~December ~~Partnership~~31, 2015.

~~Depreciation~~Of this decline, ~~depletion~~$10,610 and ~~amortization. Depreciation~~$22, ~~depletion~~674 ~~and~~were ~~amortization~~due ~~for~~to decreases in the ~~year~~average ~~ended~~prices ~~December~~of 31oil and gas sold, ~~2015~~respectively. ~~decreased~~The average price fell to $~~126,839~~37.37 from $~~133,028~~44.13 per barrel (bbl) and to $1.99 from $2.20 per thousand cubic feet (mcf) for the year ended December 31, ~~2014.~~2016 ~~This~~as ~~was~~compared ~~due~~ to the ~~overall~~year ~~decrease~~ended inDecember ~~oil~~31, ~~and gas production~~2015.

~~Cost~~Also contributing ~~ceiling~~to ~~write-down.~~the ~~There~~decline ~~were~~in ~~cost~~sales ~~ceiling write-downs~~were ~~totaling~~ $~~775~~5,~~067~~232 ~~for~~and ~~the year ended December 31~~$12,345 ~~2015. These were~~ due to lower ~~average~~volumes of oil and gas ~~prices~~sold, ~~for~~respectively, ~~the twelve~~by ~~months~~140 ~~preceding~~bbls and ~~the write-downs. There were no cost ceiling write-downs for the year ended December 31~~6,214 ~~2014~~mcf.

8Lease operations. Lease operating expense during the year ended December 31, 2016 decreased to $178,463 from $309,550 for the year ended December 31, 2015 due to fewer well repairs and workovers as well as lower pumping expenses and overhead.

~~Absent~~Production taxes. ~~significant~~Production ~~price~~taxes ~~increases,~~during the ~~sustained lower~~year ~~oil~~ended ~~prices~~December ~~experienced~~31, in2016 ~~2015~~decreased ~~will continue~~ to ~~impact~~$15,875 ~~our~~from ~~proved~~$20,689 ~~reserves adversely as the prices used~~ for ~~such estimates under SEC rules are based on~~ the ~~trailing~~year ~~12-month~~ended ~~unweighted average prices, which were substantially higher at~~ December 31, ~~2014 than current oil prices~~2015. ~~Lower~~This ~~prices~~was ~~used in estimating proved reserves may result in a reduction in volumes~~ due to ~~economic~~lower ~~limits, which~~overall inoil ~~turn,~~and ~~may~~gas ~~make~~revenue itfor ~~more likely that we will in~~ the ~~future~~year ~~incur~~ended ~~impairment~~December ~~charges~~31, ~~under full cost accounting~~2016.

~~Liquidity~~Administrative and general expense. Administrative and ~~Capital~~general ~~Resources~~expense for the year ended December 31, 2016 fell to $40,304 from $41,971 for the year ended December 31, 2015 due to decreased administrative expenses allocable to the Partnership.

~~Cash~~Depreciation, depletion ~~decreased~~and byamortization. $5Depreciation,~~255~~ ~~during~~depletion and amortization for the year ended December 31, ~~2015.~~2016 ~~All~~decreased ~~wells~~to ~~for~~$55,036 from ~~which~~$126,839 ~~funds~~for ~~have~~the ~~been~~year ~~committed~~ended ~~have~~December ~~been~~31, ~~drilled~~2015. ~~Any~~This ~~incidental~~was ~~future~~due ~~capital~~to ~~expenditures incurred~~cost ~~will~~ceiling bewrite-downs ~~paid~~that ~~with~~reduced ~~current available cash and revenues generated through oil and gas sales. Revenues which, in~~ the ~~sole judgment~~balance of the ~~managing~~full cost ~~general~~pool ~~partner,~~subject ~~are not required~~ to ~~meet~~amortization ~~the~~as ~~Registrant’s~~well ~~obligations~~as ~~will~~an beoverall ~~distributed~~decrease ~~to the partners at least quarterly~~ in ~~accordance~~oil ~~with~~and ~~the~~gas ~~Registrant’s Partnership Agreement~~production.

~~The Partnership had no cash flows from operations~~Cost inceiling ~~2015~~write-down. ~~due~~There towere ~~the~~cost ~~steep~~ceiling ~~decline~~write-downs intotaling ~~oil~~$164,474 and ~~gas~~$775,067 ~~prices~~for ~~during~~ the ~~year~~years ended December 31, ~~2015.~~2016 ~~Distributions were made out of~~and ~~proceeds from asset sales (not from operating cashflows). In addition~~2015, ~~considering these negative operating cashflows, the Partnership does not anticipate resuming distributions until prices improve~~respectively. ~~Also,~~These ~~the~~were ~~Partnership’s~~due ~~revenue~~to ~~and~~lower ~~cashflow~~average ~~could~~oil ~~be enhanced by the reversion of farmouts during the course of the calendar year ending December 31, 2016. The Partnership’s revenue~~ and ~~cash~~gas ~~flow from operating activities are highly dependent on commodity~~ prices~~. MOC~~ ~~has~~for ~~informed~~ the ~~Partnership~~twelve ~~that~~months ifpreceding ~~such~~the ~~cash flows are insufficient to fund its operating costs, MOC will not demand immediate payment of amounts owed to it~~write-downs.

~~Critical Accounting Policies~~ 8

~~The~~Absent significant ~~preparation~~price ofincreases, ~~financial~~the ~~statements~~sustained ~~in conformity~~lower ~~with~~oil ~~generally~~prices ~~accepted~~experienced ~~accounting~~in ~~principles~~2016 ~~requires~~will ~~management~~continue to ~~make~~impact proved reserves adversely as the prices used for such estimates ~~and~~under ~~assumptions~~SEC ~~that~~rules ~~affect~~are based on the ~~reported~~ ~~amounts~~trailing of12-month ~~assets~~unweighted ~~and~~average ~~liabilities~~prices. ~~and~~Lower ~~disclosure~~prices used ofin ~~contingent~~estimating ~~assets~~proved ~~and~~reserves ~~liabilities~~may atresult ~~the~~in ~~date~~a ofreduction ~~the~~in ~~financial~~volumes ~~statements and~~due ~~the~~to ~~reported~~economic ~~amounts~~limits, ofwhich ~~revenues~~in ~~and~~turn, ~~expenses~~may ~~during~~make ~~the~~it ~~reporting~~more likely ~~period.~~that ~~Actual~~we ~~results~~will ~~could~~in ~~differ~~the ~~from~~future ~~those~~incur ~~estimates~~impairment charges under full cost accounting.

~~Significant estimates inherent in the Registrant’s~~Liquidity ~~financial statements include the estimate of oil~~ and ~~gas~~Capital reserves and future abandonment costs. Changes in oil and gas prices and the changes in production estimates could have a significant effect on reserve estimates. The reserve estimates directly impact the computation of depreciation, depletion, and amortization, asset retirement obligation, and the ceiling test for the Registrant’s oil and gas properties.Resources

~~All~~Cash decreased ~~financing~~by ~~activities~~$4,017 ofduring the ~~Registrant are~~year ~~reported~~ended inDecember ~~the~~31, ~~financial~~2016. ~~statements~~All wells for which funds have been committed have been drilled. Any ~~The~~incidental ~~Registrant~~future ~~does~~capital ~~not~~expenditures ~~engage~~incurred inwill ~~any~~be ~~off-balance~~paid ~~sheet~~with ~~financing~~current ~~arrangements~~available cash and revenues generated through oil and gas sales. ~~Additionally~~Revenues which, in the ~~Registrant~~sole ~~has~~judgment noof ~~contractual~~the ~~obligations~~managing ~~but~~general ~~has~~partner, aare ~~financial~~not ~~obligation~~required to ~~plug~~meet ~~and~~the ~~abandon~~Registrant’s obligations ~~non-producing~~will ~~properties~~be asdistributed ~~discussed below~~to the partners at least quarterly in accordance with the Registrant’s Partnership Agreement.

~~Full~~The Partnership ~~Cost~~had ~~Method~~negative cash flows from operations of $692 and a decrease in cash of $4,017 for the year ended December 31, 2016. At December 31, 2016, it had negative working capital of ~~Accounting~~$1,843. Management has evaluated the significance of these conditions in relation to the company’s ability to meet its obligations and has implemented a plan for alleviation. Included in this plan are temporarily halting distributions to partners, reducing pumping and overhead expenses, and obtaining an agreement with MOC to not demand immediate payment from the Partnership if the Partnership’s cash flows are insufficient to fund its operating costs. Based upon management’s plan which considers these and other factors, management believes that events and circumstances as of March 31, 2017, considered in the aggregate, do not raise substantial doubt about the Partnership’s ability to continue as a going concern through April 1, 2018.

~~The Registrant follows the full-cost method~~Critical ofAccounting accounting for its oil and gas activities. Under the full-cost method, all productive and non-productive costs incurred in the acquisition, exploration and development of oil and gas properties are capitalized. Depreciation, depletion and amortization of oil and gas properties subject to amortization is computed on the units-of-production method based on the proved reserves underlying the oil and gas properties. Oil and gas properties are subject to a quarterly ceiling test that limits such costs to the aggregate of the present value of future net cash flows of proved reserves and the lower of cost or fair value of unproved properties. The present value of future net cash flows has been prepared by using the oil and gas pricing guidelines established by the Securities and Exchange Commission, projected development and production costs and a 10 percent annual discount rate.Policies

~~Asset~~The preparation ~~Retirement~~of ~~Obligations~~financial statements in conformity with generally accepted accounting principles requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities and disclosure of contingent assets and liabilities at the date of the financial statements and the reported amounts of revenues and expenses during the reporting period. Actual results could differ from those estimates.

~~The Partnership has recognized an estimated~~Significant ~~liability~~estimates ~~for~~inherent ~~future~~in ~~plugging~~the ~~and~~Registrant’s ~~abandonment~~financial ~~costs.~~statements Ainclude ~~liability for~~ the ~~estimated~~estimate ~~fair value~~ of ~~the~~oil ~~future~~and ~~plugging~~gas reserves and future abandonment costs. isChanges ~~recorded~~in ~~with~~oil aand ~~corresponding~~gas ~~increase~~prices inand the ~~full~~changes ~~cost~~in ~~pool~~production atestimates ~~the~~could ~~time~~have a ~~new~~significant ~~well~~effect ison ~~drilled~~reserve estimates. The ~~Depreciation~~reserve ~~expense~~estimates ~~associated with~~directly ~~estimated~~impact ~~plugging~~the computation of depreciation, depletion, and ~~abandonment~~amortization, ~~costs~~asset isretirement ~~recognized~~obligation, and inthe ~~accordance~~ceiling ~~with~~test for the ~~full~~Registrant’s ~~cost~~oil ~~methodology~~and gas properties.

9All financing activities of the Registrant are reported in the financial statements. The Registrant does not engage in any off-balance sheet financing arrangements. Additionally, the Registrant has no contractual obligations but has a financial obligation to plug and abandon non-producing properties as discussed below.

~~The Partnership estimates a liability for plugging~~Recent ~~and~~Accounting abandonment costs based on historical experience and estimated well life. The liability is discounted using the credit-adjusted risk-free rate. Revisions to the liability could occur due to changes in well plugging and abandonment costs or well useful lives, or if federal or state regulators enact new well restoration requirements. The Partnership recognizes accretion expense in connection with the discounted liability over the remaining life of the well.Developments

AIn May ~~reconciliation~~2014, the Financial Accounting Standards Board (“FASB”) issued Accounting Standards Update (“ASU”) 2014-09, Revenue from Contracts with Customers, concerning revenue recognition. The standard is effective for annual periods beginning after December 15, 2016, and interim periods therein. In April 2015, the FASB proposed to delay the effective date one year, beginning in fiscal year 2018 and such proposal was subsequently adopted by the FASB in August 2015. The Partnership is currently determining the impacts of the new revenue recognition standard on its contracts. The Partnership’s approach include evaluating its ~~liability~~key ~~for~~revenue ~~well~~contracts ~~plugging~~representative of its revenue and ~~abandonment~~comparing ~~costs~~historical ~~for~~accounting policies and practices to the ~~years~~new ~~ended~~standard. The ~~December~~Partnership’s ~~31,~~revenue ~~2015~~contracts are primarily normal purchase/normal sale contracts with index pricing that settle monthly and ~~December~~as 31such, ~~2014~~the isPartnership does not expect that the new revenue recognition standard will have a material impact on its financial statements upon adoption. The new revenue recognition standard will require new disclosure related to revenue. The Partnership intends to apply the new standard utilizing a modified retrospective basis that could result in a cumulative effect adjustment as ~~follows:~~of January 1, 2018.

	2015			2014
Balance, beginning of period	$	513,303		$	494,343
Liabilities incurred		—			1,711
Liabilities reduced due to settlements and plugging and abandonments		(5,260	)		(679	)
Accretion expense		17,347			17,928
Balance, end of period	$	525,390		$	513,303

~~Organization~~Full Cost ~~and~~Method ~~Related~~of ~~Party Transactions~~Accounting

The Registrant ~~Partnership~~follows ~~was~~the ~~organized~~full-cost onmethod ~~February~~of 19accounting for its oil and gas activities. Under the full-cost method, all productive ~~2003~~and innon-productive ~~accordance~~costs ~~with~~incurred in the ~~laws~~acquisition, ofexploration ~~the~~and ~~state~~development of ~~Delaware~~oil and gas properties are capitalized. MDDepreciation, depletion aand ~~Delaware~~amortization ~~Corporation,~~of ~~has~~oil ~~been~~and ~~appointed~~gas asproperties subject to amortization is computed on the ~~Registrant’s~~units-of-production method based ~~managing~~on ~~general~~the ~~partner~~proved reserves underlying the oil and gas properties. MDOil ~~has~~and nogas ~~significant~~properties ~~equity~~are ~~interest~~subject into a quarterly ceiling test that limits such costs to the ~~Registrant.~~aggregate ~~MOC~~of isthe ~~operator~~present value of ~~oil~~future ~~and~~net ~~gas~~cash ~~properties~~flows ~~owned by~~of proved reserves and the ~~Partnership.~~lower ~~Mewbourne~~of ~~Holdings,~~cost ~~Inc~~or fair value of unproved properties. isThe ~~the~~present ~~parent~~value of ~~both~~future MDnet cash flows has been prepared by using the oil and ~~MOC.~~gas ~~Substantially~~pricing ~~all~~guidelines established ~~transactions~~by ~~are~~the ~~with~~SEC, MDprojected development and ~~MOC~~production costs and a 10 percent annual discount rate.

~~In the ordinary course of business, MOC will~~Asset ~~incur~~Retirement certain costs that will be passed on to well owners of the well for which the costs were incurred. The Partnership will receive their portion of these costs based upon their ownership in each well incurring the costs. These costs are referred to as operator charges and are standard and customary in the oil and gas industry. Operator charges include recovery of gas marketing costs, fixed rate overhead, supervision, pumping, and equipment furnished by the operator, some of which will be included in the full cost pool pursuant to Rule 4-10(c)(2) of Regulation S-X. Amounts accrued for and paid to MOC for operator charges totaled $218,799 and $209,182 for the years ended December 31, 2015 and 2014, respectively. Operator charges are billed in accordance with the Program and Partnership Agreements.Obligations

~~In accordance with the~~ The Partnership ~~agreement, during~~has ~~any~~recognized ~~particular~~an ~~calendar~~estimated ~~year,~~liability ~~the~~for ~~total~~future ~~amount~~plugging ofand ~~administrative~~abandonment ~~expenses~~costs. ~~allocated~~A toliability for the ~~Partnership~~estimated ~~by MOC shall not~~fair ~~exceed~~value ~~the greater~~ of ~~(a) 3.5% of~~ the ~~Partnership’s~~future ~~gross~~plugging ~~revenue from the sale of oil~~ and ~~natural~~abandonment ~~gas production during each year (calculated without any deduction for operating~~ costs oris ~~other~~recorded ~~costs~~with ~~and~~a ~~expenses)~~corresponding orincrease ~~(b)~~in the ~~sum~~full ofcost ~~$50,000~~pool ~~plus~~at ~~.25% of~~ the ~~capital~~time a ~~contributions~~new ofwell ~~limited~~is ~~and general partners~~drilled. ~~Administrative~~Depreciation ~~expenses~~expense ~~can~~associated ~~only~~with beestimated ~~paid~~plugging ~~out of funds available for distributions. Under this arrangement, $13,514~~ and ~~$25,629~~abandonment ~~were~~costs ~~allocated~~is torecognized ~~the~~in ~~Partnership~~accordance with ~~during~~ the ~~years~~full ~~ended~~cost ~~December 31, 2015 and 2014, respectively~~methodology.

10The Partnership estimates a liability for plugging and abandonment costs based on historical experience and estimated well life. The liability is discounted using the credit-adjusted risk-free rate. Revisions to the liability could occur due to changes in well plugging and abandonment costs or well useful lives, or if federal or state regulators enact new well restoration requirements. The Partnership recognizes accretion expense in connection with the discounted liability over the remaining life of the well.

~~The Partnership participates in oil and gas~~A ~~activities~~reconciliation ~~through~~of ~~a Drilling Program Agreement (~~the ~~“Program”). The~~ Partnership’s ~~and~~liability MDfor ~~are~~well ~~parties~~plugging toand ~~the~~abandonment ~~Program Agreement. The~~ costs ~~and~~for ~~revenues of~~ the ~~Program~~years ~~are~~ended ~~allocated~~December to31, MD 2016 and ~~the~~December ~~Partnership~~31, 2015 is as follows:

		Partnership:			MD (1)
	2016			2015
Revenue:
Balance, beginning of period	$	525,390		$	513,303
Proceeds from disposition of depreciable and depletable properties		60	%		40	%
Liabilities reduced due to plugging and abandonments		—			(5,260	)
All other revenues		60	%		40	%
Accretion expense		17,788			17,347
Costs and expenses:
Balance, end of period	$	543,178		$	525,390
Organization and offering costs (1)		0	%		100	%
Lease acquisition costs (1)		0	%		100	%
Tangible and intangible drilling costs (1)		100	%		0	%
Operating costs, reporting and legal expenses, general and
administrative expenses and all other costs		60	%		40	%

~~(1) As noted above, pursuant to the Program, MD must contribute 100% of organization~~ Organization and ~~offering~~Related ~~costs~~Party and lease acquisition costs which should approximate 30% of total capital costs. To the extent that organization and offering costs and lease acquisition costs are less than 30% of total capital costs, MD is responsible for tangible drilling costs until its share of the Program’s total capital costs reaches approximately 30%. The Partnership’s financial statements reflect its respective proportionate interest in the Program.Transactions

~~ITEM~~The Partnership 7Awas organized on February 19, 2003 in accordance with the laws of the state of Delaware. ~~Quantitative~~MD, a Delaware Corporation, has been appointed as the Registrant’s managing general partner. MD has no significant equity interest in the Registrant. MOC is operator of oil and ~~Qualitative~~gas ~~Disclosures~~properties ~~about~~owned ~~Market~~by ~~Risk~~the Partnership. Mewbourne Holdings, Inc. is the parent of both MD and MOC. Substantially all transactions are with MD and MOC.

~~Not~~In the ~~required~~ordinary ~~under~~course of business, MOC will incur certain costs that will be passed on to well owners of the well for which the costs were incurred. The Partnership will receive their portion of these costs based upon their ownership in each well incurring the costs. These costs are referred to as operator charges and are standard and customary in the oil and gas industry. Operator charges include recovery of gas marketing costs, fixed rate overhead, supervision, pumping, and equipment furnished by the operator, some of which will be included in the full cost pool pursuant to Rule 4-10(c)(2) of Regulation S-KX. Amounts accrued for and paid to MOC for operator charges totaled $133,640 ~~Item~~and ~~305~~$218,799 for ~~smaller~~the ~~reporting~~years ended December 31, 2016 and 2015, respectively. Operator ~~companies~~charges are billed in accordance with the Program and Partnership Agreements.

~~ITEM 8. Financial Statements and Supplementary Data~~ 10

~~The~~In accordance ~~required~~with ~~financial~~the ~~statements~~Partnership ofagreement, during any particular calendar year, the ~~Registrant~~total amount of administrative expenses allocated ~~are~~to ~~contained~~the inPartnership by MOC shall not exceed the greater of (a) ~~separate~~3.5% ~~section~~of the Partnership’s gross revenue from the sale of ~~this~~oil and ~~report~~gas ~~following~~production during each year (calculated without any deduction for operating costs or other costs and expenses) or (b) the ~~signature~~sum ~~attestation~~of $50,000 plus .25% ~~See~~of ~~“Item~~the 15capital contributions of limited and general partners. ~~Exhibits,~~Administrative ~~Financial~~expenses can only be ~~Statements,~~paid ~~Financial~~out ~~Statement~~of ~~Schedules~~funds ~~and~~available ~~Reports~~for ondistributions. ~~Form~~Under this arrangement, $8~~-K”~~,700 and $13,514 were allocated to the Partnership during the years ended December 31, 2016 and 2015, respectively.

11The Partnership participates in oil and gas activities through a Drilling Program Agreement (the “Program”). The Partnership and MD are parties to the Program Agreement. The costs and revenues of the Program are allocated to MD and the Partnership as follows:

ITEM 9. Changes in and Disagreements with Accountants on Accounting and Financial Disclosure

	Partnership			MD (1)
Revenues:
Proceeds from disposition of depreciable and depletable properties		60	%		40	%
All other revenues		60	%		40	%
Costs and expenses:
Organization and offering costs (1)		0	%		100	%
Lease acquisition costs (1)		0	%		100	%
Tangible and intangible drilling costs (1)		100	%		0	%
Operating costs, reporting and legal expenses, general and administrative expenses and all other costs		60	%		40	%

~~None~~(1) As noted above, pursuant to the Program, MD must contribute 100% of organization and offering costs and lease acquisition costs which should approximate 30% of total capital costs. To the extent that organization and offering costs and lease acquisition costs are less than 30% of total capital costs, MD is responsible for tangible drilling costs until its share of the Program’s total capital costs reaches approximately 30%. The Partnership’s financial statements reflect its respective proportionate interest in the Program.

ITEM 9A 7A. ~~Controls~~Quantitative and ~~Procedures~~Qualitative Disclosures about Market Risk

~~(a)~~Not required ~~Evaluation~~under ofRegulation ~~Disclosure~~S-K, ~~Controls and~~Item ~~Procedures~~305 for smaller reporting companies.

~~As of the end of the period covered by~~ITEM this report, MD’s management conducted an evaluation, under the supervision and with the participation of MD’s principal executive officer and principal financial officer, of the Registrant’s disclosure controls and procedures (as defined in Rules 13a-15(e) and 15d-15(e) under the Exchange Act)8. ~~Based~~Financial onStatements ~~this evaluation, MD’s principal executive officer~~ and ~~principal financial~~Supplementary officer concluded that, as of the end of the period covered by this report, the Registrant’s disclosure controls and procedures are effective. Notwithstanding the foregoing, a control system, no matter how well designed and operated, can provide only reasonable, not absolute, assurance that it will detect or uncover failures within the Registrant to disclose material information otherwise required to be set forth in the Registrant’s periodic reports.Data

~~(b)~~The required MDfinancial ~~Management’s~~statements ~~Annual~~of ~~Report~~the onRegistrant ~~Internal~~are ~~Control~~contained in a separate section of this report following the signature attestation. ~~Over~~See “Item 15. Exhibits, Financial ~~Reporting~~Statements, Financial Statement Schedules and Reports on Form 8-K”.

MD’s management is responsible for establishing and maintaining adequate internal control over financial reporting, as such term is defined in Exchange Act Rules 13a-15(f). Under the supervision and with the participation of MD’s management, including MD’s principal executive officer and principal financial officer, MD conducted an evaluation of the effectiveness of the Partnership’s internal control over financial reporting based on the framework in “Internal Control — Integrated Framework” (1992) issued by the Committee of Sponsoring Organizations of the Treadway Commission. Based on MD’s evaluation under the framework in “Internal Control — Integrated Framework”, MD’s management concluded that internal control over financial reporting was effective as of December 31, 2015. This annual report does not include an attestation report of the Registrant’s independent registered public accounting firm regarding internal control over financial reporting. Management’s report was not subject to attestation by the Registrant’s independent registered public accounting firm pursuant to rules of the Securities and Exchange Commission that permit the Registrant to provide only management’s report in this annual report. There have been no changes in MD’s internal controls for the quarter ended December 31, 2015 or in other factors which have materially affected, or are reasonably likely to materially affect the internal controls over financial reporting. 11

12ITEM 9. Changes in and Disagreements with Accountants on Accounting and Financial Disclosure

~~PART III~~None.

ITEM 10 9A. ~~Directors~~ Controls and ~~Executive Officers of the Registrant~~Procedures

~~The Registrant does not have any officers or~~(a) ~~directors.~~Evaluation ~~Under~~of ~~the~~Disclosure ~~Registrant’s~~Controls ~~Partnership Agreement, the Registrant’s managing partner, MD, is granted the exclusive right~~ and ~~full authority to manage, control and administer the Registrant’s business. MD is a wholly owned subsidiary of Mewbourne Holdings, Inc.~~Procedures

~~Set~~As of ~~forth~~the ~~below~~end ~~are~~of the ~~names~~period covered by this report, ~~ages~~MD’s ~~and~~management ~~positions of~~conducted an evaluation, under the ~~directors~~supervision and ~~executive~~with the ~~officers~~participation of MD’s principal executive officer and principal financial officer, of the Registrant’s ~~managing~~disclosure controls ~~general~~and ~~partner~~procedures (as defined in Rules 13a-15(e) and 15d-15(e) under the Exchange Act). ~~Directors~~Based ofon this evaluation, MD’s principal ~~are~~executive ~~elected~~officer ~~to serve~~and ~~until~~principal ~~the~~financial ~~next~~officer ~~annual~~concluded ~~meeting~~that, as of ~~stockholders~~the orend ~~until~~of ~~their~~the ~~successors~~period covered by this report, the Registrant’s disclosure controls and procedures are ~~elected~~effective. Notwithstanding the foregoing, a control system, no matter how well designed and ~~qualified~~operated, can provide only reasonable, not absolute, assurance that it will detect or uncover failures within the Registrant to disclose material information otherwise required to be set forth in the Registrant’s periodic reports.

Name	Age as of December 31, 2015		Position
J. Roe Buckley		53	Chairman of the Board and Chief Financial Officer
Kenneth S. Waits		55	Chief Executive Officer
Alan Clark		63	Treasurer and Controller
Dorothy M. Cuenod		55	Assistant Secretary and Director
Ruth M. Buckley		54	Assistant Secretary and Director
Julie M. Greene		52	Assistant Secretary and Director

(b) MD Management’s Annual Report on Internal Control Over Financial Reporting

J.MD’s management ~~Roe~~is ~~Buckley~~responsible for establishing and maintaining adequate internal control over financial reporting, as such term is ~~age~~defined ~~53,~~in ~~joined~~Exchange ~~Mewbourne~~Act ~~Holdings,~~Rules ~~Inc~~13a-15(f). inUnder ~~July,~~the ~~1990~~supervision and ~~serves~~with asthe ~~Chairman~~participation of ~~the~~MD’s ~~Board~~management, including MD’s principal executive officer and ~~Chief~~principal ~~Financial~~financial ~~Officer~~officer, MD conducted an evaluation of ~~Mewbourne~~the effectiveness of the ~~Holdings,~~Partnership’s ~~Inc~~internal control over financial reporting based on the framework in “Internal Control — Integrated Framework” (1992) issued by the Committee of Sponsoring Organizations of the Treadway Commission., Based on MD’s ~~and~~evaluation under ~~MOC.~~the ~~Mr.~~framework ~~Buckley~~in ~~was~~“Internal ~~employed~~Control by— ~~Mbank~~Integrated ~~Dallas~~Framework”, ~~from~~MD’s ~~1985~~management toconcluded ~~1990~~that ~~where~~internal control heover ~~served~~financial reporting was effective as aof ~~commercial~~December ~~loan~~31, ~~officer~~2016. He ~~received~~This aannual ~~Bachelor~~report does not include an attestation report of ~~Arts~~the inRegistrant’s ~~Economics~~independent ~~from~~registered ~~Sewanee~~public inaccounting ~~1984.~~firm Mrregarding internal control over financial reporting. ~~Buckley~~Management’s report iswas ~~married~~not subject to ~~Ruth~~attestation M.by ~~Buckley~~the Registrant’s independent registered public accounting firm pursuant to rules of the SEC that permit the Registrant to provide only management’s report in this annual report. HeThere ishave ~~also~~been no changes in MD’s internal controls for the ~~brother-~~quarter ended December 31, 2016 or in~~-law~~ other factors which have materially affected, or ofare ~~Dorothy~~reasonably M.likely ~~Cuenod~~to ~~and~~materially ~~Julie~~affect M.the ~~Greene~~internal controls over financial reporting.

Kenneth S. Waits, age 55, Chief Executive Officer of Mewbourne Holdings, Inc., MD and MOC, has been with MOC since February 1984. He joined the company following his graduation from the University of Oklahoma where he received a Bachelor of Science in Petroleum Engineering in December, 1983. He currently manages all of MOC’s exploration efforts. He has also served as Exploration Manager for Western Oklahoma. Previously at MOC, he held positions in Operations and in Reservoir/Evaluations. 12

13PART III

~~Alan Clark, age~~ITEM ~~63, joined MOC in 1979 and serves as Treasurer and Controller of both MD and MOC~~10. ~~Prior~~Directors ~~to joining MOC, Mr. Clark was employed by Texas Oil~~ and ~~Gas~~Executive ~~Corporation~~Officers ~~as Assistant Supervisor~~ of joint interest accounting from 1976 to 1979. Mr. Clark has served in several accounting/finance positions with MOC prior to his current assignment. Mr. Clark received a Bachelor of Business Administration from the ~~University of Texas at Arlington.~~Registrant

~~Dorothy M. Cuenod,~~The ~~age~~Registrant ~~55,~~does ~~received~~not ahave ~~Bachelor~~any ofofficers ~~Arts~~or ~~degree~~directors. inUnder ~~Art~~the ~~History~~Registrant’s ~~from~~Partnership ~~The~~Agreement, ~~University~~the ~~of Texas and a Masters of Business Administration~~Registrant’s ~~Degree~~managing ~~from~~partner, ~~Southern~~MD, ~~Methodist~~is ~~University.~~granted ~~Since~~the ~~1984~~exclusive ~~she~~right ~~has served as a Director~~ and ~~Assistant~~full ~~Secretary~~authority ofto ~~both~~manage, MDcontrol and ~~MOC. Ms.~~administer ~~Cuenod is~~ the ~~sister of Ruth M~~Registrant’s business. ~~Buckley~~MD ~~and Julie M. Greene. She~~ is ~~also~~a ~~the~~wholly ~~sister-in-law~~owned subsidiary of J.Mewbourne ~~Roe~~Holdings, ~~Buckley~~Inc.

~~Ruth~~Set forth M.below ~~Buckley, age~~are 54the names, ~~received~~ages aand ~~Bachelor~~positions of ~~Science~~the ~~Degree~~directors ~~in both Engineering~~ and ~~Geology~~executive ~~from~~officers ~~Vanderbilt~~of ~~University.~~MD, ~~Since~~the ~~1987~~Registrant’s ~~she~~managing ~~has served~~general aspartner. aDirectors ~~Director and Assistant Secretary~~ of ~~both~~ MD ~~and~~are ~~MOC.~~elected ~~Ms.~~to ~~Buckley~~serve isuntil the ~~sister~~next ofannual ~~Dorothy~~meeting M.of ~~Cuenod~~stockholders ~~and~~or ~~Julie~~until M.their ~~Greene.~~successors ~~She~~are elected isand ~~also the wife of J~~qualified. ~~Roe Buckley.~~

Julie M. Greene, age 52, received a Bachelor of Arts degree in Business Administration from The University of Oklahoma. Since 1988 she has served as a Director and Assistant Secretary of both MD and MOC. Prior to that time she was employed by Rauscher, Pierce, Refsnes, Inc. Ms. Greene is the sister of Dorothy M. Cuenod and Ruth M. Buckley. She is also the sister-in-law of J. Roe Buckley.

Name	Age as of December 31, 2016	Position

J. Roe Buckley	54	Chairman of the Board and Chief Financial Officer

Kenneth S. Waits	56	Chief Executive Officer

Alan Clark	64	Treasurer and Controller

Dorothy M. Cuenod	56	Assistant Secretary and Director

Ruth M. Buckley	55	Assistant Secretary and Director

Julie M. Greene	53	Assistant Secretary and Director

~~The~~J. Roe ~~organizational~~Buckley, ~~structure~~age 54, joined Mewbourne Holdings, Inc. in July, 1990 and serves as Chairman of the ~~Partnership does~~Board ~~not~~and ~~provide~~Chief ~~for~~Financial Officer anof ~~audit~~Mewbourne ~~committee~~Holdings, Inc., MD and ~~therefore~~MOC. ~~the~~Mr. ~~Partnership~~Buckley ~~does~~was ~~not~~employed ~~have~~by anMbank ~~audit~~Dallas ~~committee~~from or1985 ~~financial~~to ~~expert~~1990 ~~serving~~where he served as a commercial loan officer. He received a Bachelor of Arts in ~~such~~Economics ~~capacity~~from Sewanee in 1984. Mr. Buckley is married to Ruth M. Buckley. He is also the brother-in-law of Dorothy M. Cuenod and Julie M. Greene.

~~ITEM 11~~Kenneth S. Waits, age 56, Chief Executive ~~Compensation~~Officer of Mewbourne Holdings, Inc., MD and MOC, has been with MOC since February 1984. He joined the company following his graduation from the University of Oklahoma where he received a Bachelor of Science in Petroleum Engineering in December, 1983. He currently manages all of MOC’s exploration efforts. He has also served as Exploration Manager for Western Oklahoma. Previously at MOC, he held positions in Operations and in Reservoir/Evaluations.

The Registrant does not have any officers or directors. Management of the Registrant is vested in the managing general partner. None of the officers or directors of MD or MOC will receive remuneration directly from the Registrant, but will continue to be compensated by their present employers. The Registrant will reimburse MD and MOC and affiliates thereof for certain costs of overhead falling within the definition of Administrative Costs, including without limitation, salaries of the officers and employees of MD and MOC; provided that no portion of the salaries of the directors or of the executive officer of MOC or MD may be reimbursed as Administrative Costs. 13

14Alan Clark, age 64, joined MOC in 1979 and serves as Treasurer and Controller of both MD and MOC. Prior to joining MOC, Mr. Clark was employed by Texas Oil and Gas Corporation as Assistant Supervisor of joint interest accounting from 1976 to 1979. Mr. Clark has served in several accounting/finance positions with MOC prior to his current assignment. Mr. Clark received a Bachelor of Business Administration from the University of Texas at Arlington.

~~ITEM~~Dorothy M. 12Cuenod, age 56, received a Bachelor of Arts degree in Art History from The University of Texas and a Masters of Business Administration Degree from Southern Methodist University. ~~Security~~ ~~Ownership~~Since 1984 she has served as a Director and Assistant Secretary of ~~Certain~~both ~~Beneficial~~MD ~~Owners~~and MOC. Ms. Cuenod is the sister of Ruth M. Buckley and ~~Management~~Julie M. Greene. She is also the sister-in-law of J. Roe Buckley.

(Ruth M. Buckley, age 55, received a) ~~Beneficial~~Bachelor ~~owners~~of Science Degree in both Engineering and Geology from Vanderbilt University. Since 1987 she has served as a Director and Assistant Secretary of ~~more~~both ~~than~~MD ~~five~~and ~~percent~~MOC. Ms. Buckley is the sister of Dorothy M. Cuenod and atJulie ~~March~~M. ~~30,~~Greene. ~~2016~~She is also the wife of J. Roe Buckley.

Class of	Name and Address of	Amount and Nature of	Percent of Limited
Ownership	Beneficial Owner	Beneficial Owner	Partnership Interests
Limited	Mewbourne Development Corp	927 Limited	5.15%
Partnership	3901 S. Broadway	Partnership Interests
Interest	Tyler, TX 75701

Julie M. Greene, age 53, received a Bachelor of Arts degree in Business Administration from The University of Oklahoma. Since 1988 she has served as a Director and Assistant Secretary of both MD and MOC. Prior to that time she was employed by Rauscher, Pierce, Refsnes, Inc. Ms. Greene is the sister of Dorothy M. Cuenod and Ruth M. Buckley. She is also the sister-in-law of J. Roe Buckley.

OfThe organizational ~~the~~structure ~~number~~ of ~~interests~~the inPartnership ~~column~~does ~~3, none~~not ~~are~~provide ~~interests~~for ~~with~~an ~~respect~~audit tocommittee ~~which~~and ~~such~~therefore ~~listed~~the ~~beneficial~~Partnership ~~owner~~does ~~has~~not ~~the~~have an ~~right~~audit tocommittee ~~acquire~~or ~~beneficial~~financial ~~ownership~~expert ~~as specified~~serving in ~~Rule~~such ~~13d-3(d)(1) under the Exchange Act~~capacity.

~~(b)~~ITEM 11. ~~Security ownership of management~~Executive Compensation

The Registrant does not have any officers or directors. ~~The~~Management of the Registrant is vested in the managing general partner. None of the ~~Registrant,~~officers ~~MD,~~or ~~has~~directors ~~the~~of ~~exclusive~~MD ~~right~~or toMOC ~~manage~~will ~~and~~receive ~~administer~~remuneration directly from the Registrant’s, but will continue to be compensated ~~business.~~by ~~Under~~their ~~the~~present employers. The Registrant’s ~~Partnership~~will ~~Agreement,~~reimburse ~~limited~~MD and ~~general~~MOC ~~partners~~and ~~holding~~affiliates athereof ~~majority~~for certain costs of ~~the~~overhead ~~outstanding~~falling ~~limited~~within ~~and~~the ~~general~~definition ~~partnership~~of ~~interests~~Administrative ~~have~~Costs, including without limitation, salaries of the ~~right~~officers toand ~~take~~employees ~~certain~~of ~~actions,~~MD ~~including~~and MOC; ~~the~~provided ~~removal~~that no portion of the ~~managing~~salaries ~~general partner.~~of ~~The~~the ~~Registrant~~directors isor ~~not~~of ~~aware~~the ofexecutive ~~any~~officer ~~current~~of ~~arrangement~~MOC or ~~activity~~MD ~~that~~ may ~~lead~~be toreimbursed ~~such~~as ~~removal~~Administrative Costs.

ITEM 13 12. Security Ownership of Certain ~~Relationships~~Beneficial Owners and ~~Related~~ ~~Transactions~~Management

~~Transactions~~(a) Beneficial ~~with~~owners MDof ~~and~~more ~~its~~than ~~affiliates~~five percent at March 31, 2017

Pursuant to the Registrant’s Partnership Agreement, the Registrant had the following related party transactions with MD and its affiliates for the years ended December 31, 2015 and 2014:

Class of Ownership	Name and Address of Beneficial Owner	Amount and Nature of Beneficial Owner	Percent of Limited Partnership Interests
Limited	Mewbourne Development Corp	1465.2 Limited	8.14%
Partnership	3901 S. Broadway	Partnership Interests
Interest	Tyler, TX 75701

	2015		2014
Administrative and general expense, management
fees (if applicable) and payment of well charges
and supervision charges in accordance with
standard industry operating agreements	$	232,313	$	234,811

Of the number of interests in column 3, none are interests with respect to which such listed beneficial owner has the right to acquire beneficial ownership as specified in Rule 13d-3(d)(1) under the Exchange Act.

~~The Registrant participates in oil and gas~~(b) ~~activities~~Security ~~through~~ownership ~~a drilling program created by the Program. Pursuant to the Program, MD pays approximately 30%~~ of the Program’s capital expenditures and approximately 40% of its operating and general and administrative expenses. The Registrant pays the remainder of the costs and expenses of the Program. In return, MD is allocated approximately 40% of the Program’s revenues.management

~~ITEM~~The Registrant 14does not have any officers or directors. ~~Principal~~ ~~Accountant~~The ~~Fees~~managing general partner of the Registrant, MD, has the exclusive right to manage and ~~Services~~administer the Registrant’s business. Under the Registrant’s Partnership Agreement, limited and general partners holding a majority of the outstanding limited and general partnership interests have the right to take certain actions, including the removal of the managing general partner. The Registrant is not aware of any current arrangement or activity that may lead to such removal.

The Partnership has retained BDO USA, LLP as their independent registered public accounting firm to perform auditing services. BDO USA, LLP’s fees for the years ended December 31, 2015 and 2014 are set forth below: 14

		2015				2014
Audit Fees		$	24,667			$	25,585

ITEM 13. Certain Relationships and Related Transactions

15Transactions with MD and its affiliates

~~PART~~Pursuant to IVthe Registrant’s Partnership Agreement, the Registrant had the following related party transactions with MD and its affiliates for the years ended December 31, 2016 and 2015:

ITEM 15. Exhibits, Financial Statements, Financial Statement Schedules and Reports on Form 8-K

		2016				2015
Administrative and general expense, management fees (if applicable) and payment of well charges and supervision charges in accordance with standard industry operating agreements		$	142,340			$	232,313

(a)	1.	Financial statements
		The following are filed as part of this annual report:
			Report of Independent Registered Public Accounting Firm
			Balance sheets as of December 31, 2015 and 2014
			Statements of operations for the years ended December 31, 2015 and 2014
			Statements of changes in partners’ capital for the years ended December 31, 2015 and 2014
			Statements of cash flows for the years ended December 31, 2015 and 2014
			Notes to financial statements
	2.	Financial statement schedules
		Not required for smaller reporting companies
	3.	Exhibits
		The exhibits listed on the accompanying index are filed or incorporated by reference as part of this annual report.
(b)	Reports on Form 8-K
		None.

The Registrant participates in oil and gas activities through a drilling program created by the Program. Pursuant to the Program, MD pays approximately 30% of the Program’s capital expenditures and approximately 40% of its operating and general and administrative expenses. The Registrant pays the remainder of the costs and expenses of the Program. In return, MD is allocated approximately 40% of the Program’s revenues.

16ITEM 14. Principal Accountant Fees and Services

~~SIGNATURES~~The Partnership has retained BDO USA, LLP as their independent registered public accounting firm to perform auditing services. BDO USA, LLP’s fees for the years ended December 31, 2016 and 2015 are set forth below:

Pursuant to the requirements of Section 13 or 15(d) of the Securities Exchange Act of 1934, the Registrant has duly caused this report to be signed on its behalf by the undersigned, thereto duly authorized.

		2016				2015
Audit Fees		$	25,737			$	24,667

	Mewbourne Energy Partners 03-A, L.P.
	By:	Mewbourne Development Corporation
		Managing General Partner
	By:	/s/ Kenneth S. Waits
		Kenneth S. Waits
		Chief Executive Officer

~~Pursuant to the requirements of the Securities~~PART ~~Exchange Act of 1934, this report has been signed below by the following persons on behalf of the Registrant and in the capacities and on the date indicated.~~IV

/s/ Kenneth S. Waits	Chief Executive Officer	March 30, 2016
Kenneth S. Waits
/s/ J. Roe Buckley	Chairman of the Board
J. Roe Buckley	Chief Financial Officer	March 30, 2016
/s/ Alan Clark	Treasurer and Controller	March 30, 2016
Alan Clark
/s/ Dorothy M. Cuenod	Director	March 30, 2016
Dorothy M. Cuenod
/s/ Ruth M. Buckley	Director	March 30, 2016
Ruth M. Buckley
/s/ Julie M. Greene	Director	March 30, 2016
Julie M. Greene

ITEM 15. Exhibits, Financial Statements, Financial Statement Schedules and Reports on Form 8-K

~~Supplemental Information to be Furnished With Reports Filed Pursuant to Section 15~~(da) of1. ~~the~~Financial ~~Act by Registrants Which Have Not Registered Securities Pursuant to Section 12 of the Act~~statements

NoThe following ~~annual~~are ~~report~~filed oras ~~proxy~~part ~~material~~of ~~has~~this ~~been~~annual ~~sent to the Registrant’s security holders.~~report:

17Report of Independent Registered Public Accounting Firm

~~MEWBOURNE~~Balance sheets ~~ENERGY~~as ~~PARTNERS~~of ~~03-A~~December 31, ~~L.P.~~2016 and 2015

~~FINANCIAL~~Statements of ~~STATEMENTS~~operations for the years ended December 31, 2016 and 2015

~~WITH~~Statements of ~~REPORT~~changes OFin ~~INDEPENDENT~~partners’ ~~REGISTERED~~capital ~~PUBLIC ACCOUNTING~~for ~~FIRM~~the years ended December 31, 2016 and 2015

As Statements of ~~and~~cash flows for the years ended December 31, ~~2015~~ 2016 and ~~2014~~2015

18Notes to financial statements

~~Report~~2. ofFinancial ~~Independent~~statement ~~Registered Public Accounting Firm~~ schedules

ToNot ~~the~~required ~~Partners~~for ofsmaller ~~Mewbourne~~reporting ~~Energy Partners 03-A, L.P. and to the Board of Directors of Mewbourne Development Corporation~~companies

~~Tyler, Texas~~3. Exhibits

WeThe ~~have~~exhibits ~~audited~~listed on the accompanying ~~balance~~index ~~sheets~~are offiled ~~Mewbourne~~or ~~Energy~~incorporated ~~Partners~~by ~~03-A,~~reference ~~L.P. (Partnership)~~ as ofpart ~~December 31, 2015 and 2014 and the related statements~~ of ~~operations,~~this ~~changes~~annual ~~in partners’ capital and cash flows for the years then ended~~report. ~~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~~b). ~~Those standards~~Reports 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 control 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~~Form 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, as well as evaluating the overall financial statement presentation. We believe that our audits provide a reasonable basis for our opinion.8-K

In our opinion, the financial statements referred to above present fairly, in all material respects, the financial position of the Partnership at December 31, 2015 and 2014, 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 AmericaNone.

~~/s/BDO~~ITEM ~~USA,~~16. ~~LLP~~Form 10-K Summary

~~Dallas, Texas~~None.

~~March 30, 2016~~ 16

19SIGNATURES

~~MEWBOURNE~~Pursuant to ~~ENERGY~~the ~~PARTNERS~~requirements ~~03-A~~of Section 13 or 15(d) of the Securities Exchange Act of 1934, ~~L.P.~~the ~~BALANCE~~Registrant ~~SHEETS~~has duly caused this report to be signed on its behalf by the undersigned, thereto duly authorized.

		December 31, 2015			December 31, 2014
	Mewbourne Energy Partners 03-A, L.P.
ASSETS
	By:	Mewbourne Development Corporation Managing General Partner
Cash		$	4,775		$	10,030
	By:	/s/ Kenneth S. Waits
Accounts receivable, affiliate			36,620			88,759
		Kenneth S. Waits
Prepaid state taxes			1,994			770
		Chief Executive Officer
Total current assets			43,389			99,559
Oil and gas properties at cost, full-cost method			19,618,601			19,619,942
Less accumulated depreciation, depletion,
amortization and impairment			(18,721,720	)		(17,795,199	)
			896,881			1,824,743
Total assets		$	940,270		$	1,924,302
LIABILITIES AND PARTNERS' CAPITAL
Accounts payable, affiliate		$	58,165		$	41,099
Total current liabilities			58,165			41,099
Asset retirement obligation			525,390			513,303
Partners' capital			356,715			1,369,900
Total liabilities and partners' capital		$	940,270		$	1,924,302

~~The~~Pursuant to ~~accompanying~~the ~~notes~~requirements ~~are~~of anthe ~~integral~~Securities ~~part~~Exchange Act of 1934, this report has been signed below by the ~~financial~~following ~~statements~~persons on behalf of the Registrant and in the capacities and on the date indicated.

/s/ Kenneth S. Waits	Chief Executive Officer	March 31, 2017
Kenneth S. Waits

/s/ J. Roe Buckley	Chairman of the Board
J. Roe Buckley	Chief Financial Officer	March 31, 2017

/s/ Alan Clark	Treasurer and Controller	March 31, 2017
Alan Clark

/s/ Dorothy M. Cuenod	Director	March 31, 2017
Dorothy M. Cuenod

/s/ Ruth M. Buckley	Director	March 31, 2017
Ruth M. Buckley

/s/ Julie M. Greene	Director	March 31, 2017
Julie M. Greene

~~MEWBOURNE~~Supplemental Information ~~ENERGY~~to ~~PARTNERS~~be ~~03-A,~~Furnished ~~L.P.~~With ~~STATEMENTS~~Reports OFFiled ~~OPERATIONS~~Pursuant to Section 15(d) of the Act by Registrants Which Have Not Registered Securities Pursuant to Section 12 of the Act

	For the Years Ended
	December 31,
	2015			2014
Revenues:
Oil sales	$	69,321		$	200,636
Gas sales		235,773			511,128
Total revenues		305,094			711,764
Expenses:
Lease operating expense		309,550			330,198
Production taxes		20,689			49,182
Administrative and general expense		41,971			52,372
Depreciation, depletion, and amortization		126,839			133,028
Cost ceiling write-down		775,067			—
Asset retirement obligation accretion		17,347			17,928
Total expenses		1,291,463			582,708
Net (loss) income	$	(986,369	)	$	129,056

No annual report or proxy material has been sent to the Registrant’s security holders.

~~The accompanying notes are an integral part of the financial statements.~~ 17

21MEWBOURNE ENERGY PARTNERS 03-A, L.P.

~~MEWBOURNE ENERGY PARTNERS 03-A, L.P.~~ FINANCIAL STATEMENTS ~~OF CHANGES IN PARTNERS' CAPITAL For the years ended December 31, 2015 and 2014~~

	Partners'
	Capital
Balance at December 31, 2013	$	1,540,636
Cash distributions		(299,792	)
Net income		129,056
Balance at December 31, 2014		1,369,900
Cash distributions		(26,816	)
Net loss		(986,369	)
Balance at December 31, 2015	$	356,715

WITH REPORT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM

~~The accompanying~~As ~~notes~~of ~~are~~and anfor ~~integral~~the ~~part~~years ofended ~~the~~December ~~financial~~31, ~~statements.~~2016 and 2015

2218

~~MEWBOURNE~~Report of ~~ENERGY~~Independent ~~PARTNERS~~Registered ~~03-A,~~Public ~~L.P.~~Accounting ~~STATEMENTS OF CASH FLOWS~~Firm

	For the Years Ended
	December 31,
	2015			2014
Cash flows from operating activities:
Net (loss) income	$	(986,369	)	$	129,056
Adjustments to reconcile net (loss) income to net cash
provided by operating activities:
Depreciation, depletion, and amortization		126,839			133,028
Cost ceiling write-down		775,067			—
Asset retirement obligation accretion		17,347			17,928
Plugging and abandonment cost paid from asset retirement obligation		(7,729	)		(1,767	)
Changes in operating assets and liabilities:
Accounts receivable, affiliate		52,139			22,071
Prepaid state taxes		(1,224	)		—
Accounts payable, affiliate		17,066			5,327
Net cash provided by (used in) operating activities		(6,864	)		305,643
Cash flows from investing activities:
Proceeds from sale of oil and gas properties		35,887			2,956
Purchase and development of oil and gas properties		(7,462	)		—
Net cash provided by investing activities		28,425			2,956
Cash flows from financing activities:
Cash distributions to partners		(26,816	)		(299,792	)
Net cash used in financing activities		(26,816	)		(299,792	)
Net increase (decrease) in cash		(5,255	)		8,807
Cash, beginning of period		10,030			1,223
Cash, end of period	$	4,775		$	10,030
Supplemental Cash Flow Information:
Change to net oil & gas properties related to asset retirement
obligation liabilities	$	2,469		$	1,032
Change to property, plant and equipment related to accrual of
leaseholds	$	—		$	—

To the Partners of Mewbourne Energy Partners 03-A, L.P. and to the Board of Directors of Mewbourne Development Corporation

~~The accompanying~~Tyler, ~~notes are an integral part of the financial statements.~~Texas

23We have audited the accompanying balance sheets of Mewbourne Energy Partners 03-A, L.P. (the “Partnership”) as of December 31, 2016 and 2015 and the related statements of operations, changes in partners’ capital 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.

~~Mewbourne~~We conducted ~~Energy~~our ~~Partners~~audits ~~03-A~~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, Lnor were we engaged to perform, an audit of its internal control over financial reporting.P Our audits included consideration of internal control 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, as well as evaluating the overall financial statement presentation. We believe that our audits provide a reasonable basis for our opinion.

~~NOTES~~In our TOopinion, ~~FINANCIAL~~the ~~STATEMENTS~~financial statements referred to above present fairly, in all material respects, the financial position of the Partnership at December 31, 2016 and 2015, 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.

~~1. Description~~/s/BDO USA, ~~of Business~~LLP

~~Mewbourne Energy Partners 03-A~~Dallas, ~~L.P., (the~~ ~~“Registrant” or the “Partnership”), a Delaware limited partnership engaged primarily in oil and gas development and production in~~ Texas, Oklahoma, and New Mexico, was organized on February 19, 2003. The offering of limited and general partnership interests began May 16, 2003 as a part of an offering registered under the name Mewbourne Energy Partners 02-03 Drilling Programs, (the “Program”), and concluded July 9, 2003, with total investor contributions of $18,000,000 originally being sold to 710 subscribers of which $16,107,005 were sold to 644 subscribers as general partner equity interests and $1,892,995 were sold to 66 subscribers as limited partner equity interests. During 2005 all general partner equity interests were converted to limited partner interests. The managing general partner has no significant equity interest in the Partnership.

~~The Partnership’s sole business is the~~March development and production of oil and gas. A substantial portion of the Partnership’s gas production is being sold regionally in the spot market. Due to the highly competitive nature of the spot market31, prices are subject to seasonal and regional pricing fluctuations. In addition, such spot market sales are generally short-term in nature and are dependent upon obtaining transportation services provided by pipelines. The prices received for the Partnership’s oil and gas are subject to influences such as global consumption and supply trends.2017

~~2. Summary of Significant Accounting Policies~~19

~~The preparation of financial statements in~~MEWBOURNE ~~conformity~~ ENERGY ~~with~~PARTNERS ~~generally~~03-A, accepted accounting principles requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities and disclosure of contingent assets and liabilities at the date of the financial statements and the reported amounts of revenues and expenses during the reporting periodL. ~~Actual results could differ from those estimates~~P.

~~Significant estimates inherent in the Registrant’s~~BALANCE financial statements include the estimate of oil and gas reserves and future abandonment costs. Changes in oil and gas prices and the changes in production estimates could have a significant effect on reserve estimates. The reserve estimates directly impact the computation of depreciation, depletion, and amortization, asset retirement obligation, and the ceiling test for the Registrant’s oil and gas properties. SHEETS

Full Cost Accounting

	December 31, 2016			December 31, 2015

ASSETS

Cash	$	758		$	4,775
Accounts receivable, affiliate		46,640			36,620
Prepaid state taxes		694			1,994
Total current assets		48,092			43,389

Oil and gas properties at cost, full-cost method		19,619,265			19,618,601
Less accumulated depreciation, depletion, amortization and cost ceiling write-downs		(18,937,897	)		(18,721,720	)
		681,368			896,881

Total assets	$	729,460		$	940,270

LIABILITIES AND PARTNERS’ CAPITAL

Accounts payable, affiliate	$	49,935		$	58,165
Total current liabilities		49,935			58,165

Asset retirement obligation		543,178			525,390

Partners’ capital		136,347			356,715

Total liabilities and partners’ capital	$	729,460		$	940,270

The ~~Partnership~~accompanying ~~follows~~notes the full-cost method of accounting for its oil and gas activities. Under the full-cost method, all productive and non-productive costs incurred in the acquisition, exploration and development of oil and gas properties are ~~capitalized.~~an ~~Depreciation,~~integral ~~depletion~~part ~~and amortization~~ of ~~oil~~ ~~and gas properties subject to amortization is computed on~~ the ~~units-of-production~~financial ~~method based on the proved reserves underlying the oil and gas properties~~statements. At December 31, 2015 and 2014, all capitalized costs were subject to amortization. Proceeds from the sale or other disposition of properties are credited to the full cost pool. Gains and losses are not recognized unless such adjustments would significantly alter the relationship between capitalized costs and the proved oil and gas reserves. Capitalized costs are subject to a quarterly ceiling test that limits such costs to the aggregate of the present value of estimated future net cash flows of proved reserves, computed using the 12-month unweighted average of first-day-of the-month oil and natural gas prices, discounted at 10%, and the lower of cost or fair value of unproved properties. If unamortized costs capitalized exceed the ceiling, the excess is charged to expense in the period the excess occurs. There were cost ceiling write-downs totaling $775,067 for the year ended December 31, 2015. There were no cost ceiling write-downs for the year ended December 31, 2014.

2420

~~Cash~~MEWBOURNE ENERGY PARTNERS 03-A, L.P.

~~The Partnership maintains all its cash in one~~STATEMENTS ~~financial~~ OF ~~institution. At various times throughout the year, the cash amount may be in excess of the amount insured by the Federal Deposit Insurance Corporation.~~OPERATIONS

Fair Value of Financial Instruments

	For the Years Ended December 31,
	2016			2015
Revenues:
Oil sales	$	53,479		$	69,321
Gas sales		200,754			235,773
Total revenues		254,233			305,094

Expenses:
Lease operating expense		178,463			309,550
Production taxes		15,875			20,689
Administrative and general expense		40,304			41,971
Depreciation, depletion, and amortization		55,036			126,839
Cost ceiling write-down		164,474			775,067
Asset retirement obligation accretion		17,788			17,347
Total expenses		471,940			1,291,463

Net loss	$	(217,707	)	$	(986,369	)

The ~~Financial~~accompanying ~~Accounting~~notes ~~Standards~~are ~~Board~~an ~~(“FASB”) has~~integral ~~issued~~part ~~guidance~~of ~~on determining~~ the ~~estimated fair value for~~ financial ~~instruments~~statements. This disclosure states that the fair value of financial instruments is determined at discrete points in time based on relevant market information. Such estimates involve uncertainties and cannot be determined with precision. The estimated fair value of cash, accounts receivable and accounts payable approximates their carrying value due to their short-term nature.

~~Asset Retirement Obligations~~21

~~The Partnership has recognized an estimated~~MEWBOURNE ~~liability~~ ENERGY ~~for~~PARTNERS ~~future plugging and abandonment costs.~~ 03-A, ~~liability for the estimated fair value of the future plugging and abandonment costs is recorded with a corresponding increase in the full cost pool at the time a new well is drilled~~L. ~~Depreciation expense associated with estimated plugging and abandonment costs is recognized in accordance with the full cost methodology~~P.

~~The Partnership estimates a liability for plugging~~STATEMENTS ~~and~~ OF ~~abandonment~~CHANGES ~~costs~~IN ~~based~~PARTNERS’ on historical experience and estimated well life. The liability is discounted using the credit-adjusted risk-free rate. Revisions to the liability could occur due to changes in well plugging and abandonment costs or well useful lives, or if federal or state regulators enact new well restoration requirements. The Partnership recognizes accretion expense in connection with the discounted liability over the remaining life of the well.CAPITAL

~~A reconciliation of the Partnership’s liability for well plugging~~For ~~and abandonment costs for~~ the years ended December 31, ~~2015~~2016 and ~~December 31, 2014 is as follows:~~2015

	2015			2014
	Partners’ Capital
Balance, beginning of period	$	513,303		$	494,343
Balance at December 31, 2014	$	1,369,900
Liabilities incurred		—			1,711
Cash distributions		(26,816	)
Liabilities reduced due to settlements and plugging and abandonments		(5,260	)		(679	)
Net loss		(986,369	)
Accretion expense		17,347			17,928
Balance at December 31, 2015		356,715
Balance, end of period	$	525,390		$	513,303
Cash distributions		(2,661	)
Net loss		(217,707	)
Balance at December 31, 2016	$	136,347

25The accompanying notes are an integral part of the financial statements.

~~Oil and Gas Sales~~22

~~The Partnership’s oil and condensate~~MEWBOURNE ~~production~~ ENERGY isPARTNERS ~~sold and revenue recognized at or near the Partnership’s wells under short~~03-term purchase contracts at prevailing prices in accordance with arrangements which are customary in the oil industry. Sales of gas applicable to the Partnership’s interest are recorded as revenue when the gas is metered and title transferred pursuant to the gas sales contracts covering the Partnership’s interest in gas reserves. The Partnership uses the sales method to recognize oil and gas revenue whereby revenue is recognized for the amount of production taken regardless of the amount for which the Partnership is entitled based on its working interest ownership. As of December 31A, ~~2015 and 2014, no material gas imbalances between the Partnership and other working interest owners existed~~L.P.

~~Substantially all of the Partnership’s~~STATEMENTS ~~accounts~~ OF ~~receivable~~CASH result from oil and natural gas sales to third parties in the oil and natural gas industry. This concentration of customers may impact the Partnership’s overall credit risk in that these entities may be similarly affected by changes in economic and other conditions. Historically, the Partnership has not experienced significant credit losses on such receivables. No bad debt expense was recorded in 2015 or 2014. The Partnership cannot ensure that such losses will not be realized in the future.FLOWS

Comprehensive Income

	For the Years Ended December 31,
	2016			2015
Cash flows from operating activities:
Net loss	$	(217,707	)	$	(986,369	)
Adjustments to reconcile net loss to net cash used in operating activities:
Depreciation, depletion, and amortization		55,036			126,839
Cost ceiling write-down		164,474			775,067
Asset retirement obligation accretion		17,788			17,347
Plugging and abandonment cost paid from asset retirement obligation		(3,333	)		(7,729	)
Changes in operating assets and liabilities:
Accounts receivable, affiliate		(10,020	)		52,139
Prepaid state taxes		1,300			(1,224	)
Accounts payable, affiliate		(8,230	)		17,066
Net cash used in operating activities		(692	)		(6,864	)

Cash flows from investing activities:
Proceeds from sale of oil and gas properties		—			35,887
Purchase and development of oil and gas properties		(664	)		(7,462	)
Net cash (used in) provided by investing activities		(664	)		28,425

Cash flows from financing activities:
Cash distributions to partners		(2,661	)		(26,816	)
Net cash used in financing activities		(2,661	)		(26,816	)

Net decrease in cash		(4,017	)		(5,255	)
Cash, beginning of period		4,775			10,030

Cash, end of period	$	758		$	4,775

Supplemental Cash Flow Information:
Change to net oil & gas properties related to asset retirement obligation liabilities	$	—		$	2,469

~~Comprehensive~~The ~~income~~accompanying isnotes ~~defined~~are asan aintegral ~~change in~~part ~~equity~~ of a business enterprise during a period from transactions and other events and circumstances from non-partner sources and includes all changes in equity during a period except those resulting from investments by partners and distributions to partners. The Partnership has no items of comprehensive income, other than net income, in any period presented. Therefore, net income as presented in the ~~statements~~financial ~~of operations equals comprehensive income~~statements.

~~Income Taxes~~23

~~The Partnership is treated as a partnership~~Mewbourne ~~for~~Energy ~~income~~Partners ~~tax purposes and~~03-A, ~~as a result, income of the Partnership is reported on the tax returns of the partners and no recognition is given to income taxes in the financial statements~~L. ~~The Partnership’s financial reporting basis of its net assets exceeded the tax basis of its net assets by $873,082 and $1,802,276 at December 31, 2015 and 2014, respectively~~P.

~~The Partnership accounts for uncertainty in~~NOTES ~~income~~TO ~~taxes~~FINANCIAL in accordance with applicable accounting guidance and recognizes the effects of those positions only if they are more likely than not of being sustained. As no liability had been recognized as of December 31, 2015 or 2014, the Partnership did not accrue for any interest or penalties.STATEMENTS

31. ~~Organization~~ Description of ~~and Related Party Transactions:~~Business

~~The~~Mewbourne Energy Partners 03-A, L.P., (the “Registrant” or the “Partnership”), a Delaware limited partnership engaged primarily in oil and gas development and production in Texas, Oklahoma, and New Mexico, was organized on February 19, 2003. inThe offering ~~accordance~~of ~~with~~limited ~~the~~and ~~laws~~general ofpartnership ~~the~~interests ~~state~~began May 16, 2003 as a part of ~~Delaware.~~an offering registered under the name Mewbourne Energy ~~Development~~Partners ~~Corporation~~02-03 Drilling Programs, (the “MDProgram”), aand ~~Delaware~~concluded ~~Corporation~~July 9, ~~has~~ ~~been~~2003, ~~appointed~~with astotal ~~the~~investor ~~Registrant’s~~contributions of ~~managing~~$18,000,000 ~~general~~originally ~~partner.~~being MDsold ~~has~~to no710 ~~significant~~subscribers ~~equity~~of ~~interest~~which in$16,107,005 ~~the~~were ~~Registrant. Mewbourne~~sold ~~Oil~~to ~~Company~~644 ~~(MOC)~~subscribers isas ~~operator~~general ofpartner ~~oil~~equity interests and ~~gas~~$1,892,995 ~~properties~~were ~~owned~~sold byto ~~the~~66 ~~Partnership.~~subscribers ~~Mewbourne~~as ~~Holdings,~~limited ~~Inc~~partner equity interests. isDuring ~~the~~2005 ~~parent~~all general partner equity ofinterests ~~both~~were MDconverted ~~and~~to ~~MOC~~limited partner interests. ~~Substantially~~The ~~all~~managing ~~transactions~~general ~~are~~partner ~~with~~has MDno ~~and~~significant ~~MOC~~equity interest in the Partnership.

26The Partnership’s sole business is the development and production of oil and gas. A substantial portion of the Partnership’s gas production is being sold regionally in the spot market. Due to the highly competitive nature of the spot market, prices are subject to seasonal and regional pricing fluctuations. In addition, such spot market sales are generally short-term in nature and are dependent upon obtaining transportation services provided by pipelines. The prices received for the Partnership’s oil and gas are subject to influences such as global consumption and supply trends.

~~In the ordinary course of business, MOC will incur certain costs that will be passed on to well owners of the well on which the costs were incurred~~2. ~~The Partnership will be~~ Summary ~~charged their portion~~ of ~~these~~Significant ~~costs~~Accounting based upon their ownership in each well incurring the costs. These costs are referred to as Operator charges and are standard and customary in the oil and gas industry. Operator charges include recovery of gas marketing costs, fixed rate overhead, supervision, pumping, and equipment furnished by the operator, some of which will be included in the full cost pool pursuant to Rule 4-10(c)(2) of Regulation S-X. Amounts accrued for and paid to MOC for operator charges totaled $218,799 and $209,182 for the years ended December 31, 2015 and 2014, respectively. Operator charges are billed in accordance with the Program and Partnership Agreements.Policies

~~In accordance with the Partnership agreement,~~The ~~during~~preparation ~~any~~of ~~particular~~financial ~~calendar~~statements ~~year,~~in ~~the~~conformity ~~total~~with ~~amount~~generally ofaccepted ~~administrative~~accounting ~~expenses~~principles ~~allocated~~requires management to ~~the~~make ~~Partnership by MOC shall not~~estimates ~~exceed~~and ~~the~~assumptions ~~greater~~that ofaffect ~~(a) 3.5% of~~ the ~~Partnership’s~~reported ~~gross~~amounts ~~revenue from the sale~~ of ~~oil~~assets and ~~natural~~liabilities ~~gas~~and ~~production~~disclosure ~~during each~~of ~~year~~contingent ~~(calculated~~assets ~~without any deduction for operating costs or other costs~~ and ~~expenses)~~liabilities at ~~or (b)~~ the ~~sum~~date of ~~$50,000 plus .25% of~~ the ~~capital~~financial ~~contributions~~statements ~~of limited~~ and ~~general~~the ~~partners.~~reported ~~Administrative~~amounts ~~expenses can only be paid out~~ of ~~funds~~revenues ~~available for distributions. Under this arrangement, $13,514~~ and ~~$25,629~~expenses ~~were allocated to the Partnership~~ during the ~~years~~reporting ~~ended~~period. ~~December 31,~~Actual ~~2015~~results ~~and~~could ~~2014,~~differ ~~respectively~~from those estimates.

~~The~~Significant estimates ~~Partnership~~inherent ~~participates~~ in the Registrant’s financial statements include the estimate of oil and gas reserves and future abandonment ~~activities~~costs. ~~through~~Changes ain ~~Drilling~~oil ~~Program~~and ~~Agreement~~gas (prices and the ~~“Program”).~~changes ~~The~~in ~~Partnership~~production ~~and~~estimates MDcould ~~are~~have ~~parties~~a tosignificant ~~the~~effect ~~Program Agreement.~~on reserve estimates. The ~~costs~~reserve ~~and~~estimates ~~revenues~~directly ofimpact the ~~Program~~computation ~~are~~of ~~allocated~~depreciation, todepletion, MDand amortization, asset retirement obligation, and the ~~Partnership~~ceiling astest ~~follows:~~for the Registrant’s oil and gas properties.

	Partnership:		MD (1)
Revenue:
Proceeds from disposition of depreciable and depletable properties	60	%	40	%
All other revenues	60	%	40	%
Costs and expenses:
Organization and offering costs (1)	0	%	100	%
Lease acquisition costs (1)	0	%	100	%
Tangible and intangible drilling costs (1)	100	%	0	%
Operating costs, reporting and legal expenses, general and
administrative expenses and all other costs	60	%	40	%

Full Cost Accounting

~~(1)~~The Partnership Asfollows ~~noted~~the ~~above,~~full-cost ~~pursuant~~method toof accounting for its oil and gas activities. Under the ~~Program~~full-cost method, MDall ~~must~~productive and ~~contribute~~non-productive ~~100%~~costs incurred in the acquisition, exploration and development of ~~organization~~oil and ~~offering~~gas ~~costs~~properties are capitalized. Depreciation, depletion and ~~lease~~amortization ~~acquisition~~of ~~costs~~oil ~~which~~and ~~should~~gas ~~approximate~~properties ~~30%~~subject to amortization is computed on the units-of-production ~~total~~method ~~capital~~based on the proved reserves underlying the oil and gas properties. At December 31, 2016 and 2015, all capitalized costs were subject to amortization. ToProceeds from the ~~extent~~sale ~~that~~or ~~organization~~other disposition of properties are credited to the full cost pool. Gains and ~~offering~~losses are not recognized unless such adjustments would significantly alter the relationship between capitalized costs and ~~lease~~the ~~acquisition~~proved oil and gas reserves. Capitalized costs are ~~less~~subject ~~than~~to ~~30%~~a ofquarterly ~~total~~ceiling ~~capital~~test that limits such costs, MDto isthe ~~responsible~~aggregate ~~for~~of ~~tangible~~the present ~~drilling~~value ~~costs~~of ~~until~~estimated ~~its~~future ~~share~~net cash flows of proved reserves, computed using the ~~Program’s~~12-month ~~total~~unweighted ~~capital~~average ~~costs~~of ~~reaches~~first-day-of the-month ~~approximately~~oil 30and gas prices, discounted at 10%, and the lower of cost or fair value of unproved properties. ~~The~~If ~~Partnership’s~~unamortized ~~financial~~costs capitalized ~~statements~~exceed ~~reflect~~the ~~its~~ceiling, ~~respective~~the ~~proportionate~~excess ~~interest~~is charged to expense in the ~~Program~~period the excess occurs. There were cost ceiling write-downs totaling $164,474 and $775,067 for the years ended December 31, 2016 and 2015, respectively.

~~4. Liquidity and Capital Resources~~24

~~Cash decreased by $5,255 during the year ended~~Subsequent December 31, 2015. The Partnership had no cash flows from operations in 2015 due to the steep decline in oil and gas prices during the year ended December 31, 2015. Distributions were made out of proceeds from asset sales (not from operating cashflows). In addition, considering these negative operating cashflows, the Partnership does not anticipate resuming distributions until prices improve. Also, the Partnership’s revenue and cashflow could be enhanced by the reversion of farmouts during the course of the calendar year ending December 31, 2016. The Partnership’s revenue and cash flow from operating activities are highly dependent on commodity prices. MOC has informed the Partnership that if such cash flows are insufficient to fund its operating costs, MOC will not demand immediate payment of amounts owed to it.Events

27The Partnership has evaluated events and transactions for potential recognition or disclosure through the date the financial statements were issued.

~~MEWBOURNE~~Recent Accounting ~~ENERGY PARTNERS 03-A, L.P.~~Developments

~~INDEX~~In May TO2014, ~~EXHIBITS~~the Financial Accounting Standards Board (“FASB”) issued Accounting Standards Update (“ASU”) 2014-09, Revenue from Contracts with Customers, concerning revenue recognition. The standard is effective for annual periods beginning after December 15, 2016, and interim periods therein. In April 2015, the FASB proposed to delay the effective date one year, beginning in fiscal year 2018 and such proposal was subsequently adopted by the FASB in August 2015. The Partnership is currently determining the impacts of the new revenue recognition standard on its contracts. The Partnership’s approach include evaluating its key revenue contracts representative of its revenue and comparing historical accounting policies and practices to the new standard. The Partnership’s revenue contracts are primarily normal purchase/normal sale contracts with index pricing that settle monthly and as such, the Partnership does not expect that the new revenue recognition standard will have a material impact on its financial statements upon adoption. The new revenue recognition standard will require new disclosure related to revenue. The Partnership intends to apply the new standard utilizing a modified retrospective basis that could result in a cumulative effect adjustment as of January 1, 2018.

~~The following documents are incorporated by reference in response to Item 15(a)3.~~Cash

EXHIBIT
NUMBER		DESCRIPTION
3.1		Form of Certificate of Limited Partnership (filed as Exhibit 3.1 to Registration Statement on Form S-1, File No. 333-85994-01 and incorporated herein by reference)
3.2		Form of Certificate of Amendment of the Certificate of Limited Partnership (filed as Exhibit 3.2 to Registration Statement on Form S-1, File No. 333-85994-01 and incorporated herein by reference)
4.1		Form of Agreement of Partnership (filed as Exhibit 4.1 to Registration Statement on Form S-1, File No. 333-85994-01 and incorporated herein by reference)
10.1		Form of Drilling Program Agreement (filed as Exhibit 10.1 to Registration Statement on Form S-1, File No. 333-85994-01 and incorporated herein by reference)
10.4		Form of Operating Agreement (filed as Exhibit 10.4 to Registration Statement on Form S-1, File No. 333-85994-01 and incorporated herein by reference)
31.1		Certification of CEO Pursuant to Section 302 of Sarbanes-Oxley Act of 2002.
31.2		Certification of CFO Pursuant to Section 302 of Sarbanes-Oxley Act of 2002.
32.1		Certification of CEO Pursuant to Section 906 of Sarbanes-Oxley Act of 2002.
32.2		Certification of CFO Pursuant to Section 906 of Sarbanes-Oxley Act of 2002.
99.1		Report of Forrest A. Garb & Associates, Inc.
101		The following materials from the Partnership's Annual Report on Form 10-K for the year ended December 31, 2015 formatted in Extensible Business Reporting Language (XBRL): (i) the Balance Sheets, (ii) the Statements of Operations, (iii) the Statements of Cash Flows, (iv) the Statement of Changes in Partners’ Capital and (v) related notes.

The Partnership maintains all its cash in one financial institution. At various times throughout the year, the cash amount may be in excess of the amount insured by the Federal Deposit Insurance Corporation.

28Fair Value of Financial Instruments

The FASB has issued guidance on determining the estimated fair value for financial instruments. This disclosure states that the fair value of financial instruments is determined at discrete points in time based on relevant market information. Such estimates involve uncertainties and cannot be determined with precision. The estimated fair value of cash, accounts receivable, affiliate and accounts payable, affiliate approximates their carrying value due to their short-term nature.

Asset Retirement Obligations

The Partnership has recognized an estimated liability for future plugging and abandonment costs. A liability for the estimated fair value of the future plugging and abandonment costs is recorded with a corresponding increase in the full cost pool at the time a new well is drilled. Depreciation expense associated with estimated plugging and abandonment costs is recognized in accordance with the full cost methodology.

The Partnership estimates a liability for plugging and abandonment costs based on historical experience and estimated well life. The liability is discounted using the credit-adjusted risk-free rate. Revisions to the liability could occur due to changes in well plugging and abandonment costs or well useful lives, or if federal or state regulators enact new well restoration requirements. The Partnership recognizes accretion expense in connection with the discounted liability over the remaining life of the well.

A reconciliation of the Partnership’s liability for well plugging and abandonment costs for the years ended December 31, 2016 and December 31, 2015 is as follows:

	2016		2015
Balance, beginning of period	$	525,390	$	513,303
Liabilities reduced due to plugging and abandonments		—		(5,260	)
Accretion expense		17,788		17,347
Balance, end of period	$	543,178	$	525,390

Oil and Gas Sales

The Partnership’s oil and condensate production is sold and revenue recognized at or near the Partnership’s wells under short-term purchase contracts at prevailing prices in accordance with arrangements which are customary in the oil industry. Sales of gas applicable to the Partnership’s interest are recorded as revenue when the gas is metered and title transferred pursuant to the gas sales contracts covering the Partnership’s interest in gas reserves. The Partnership uses the sales method to recognize oil and gas revenue whereby revenue is recognized for the amount of production taken regardless of the amount for which the Partnership is entitled based on its working interest ownership. As of December 31, 2016 and 2015, no material gas imbalances between the Partnership and other working interest owners existed.

Substantially all of the Partnership’s accounts receivable result from oil and gas sales to third parties in the oil and gas industry. This concentration of customers may impact the Partnership’s overall credit risk in that these entities may be similarly affected by changes in economic and other conditions. Historically, the Partnership has not experienced significant credit losses on such receivables. No bad debt expense was recorded in 2016 or 2015. The Partnership cannot ensure that such losses will not be realized in the future.

Comprehensive Income

Comprehensive income is defined as a change in equity of a business enterprise during a period from transactions and other events and circumstances from non-partner sources and includes all changes in equity during a period except those resulting from investments by partners and distributions to partners. The Partnership has no items of comprehensive income, other than net income, in any period presented. Therefore, net income as presented in the statements of operations equals comprehensive income.

Income Taxes

The Partnership is treated as a partnership for income tax purposes and, as a result, income of the Partnership is reported on the tax returns of the partners and no recognition is given to income taxes in the financial statements. The Partnership’s financial reporting basis of its net assets exceeded the tax basis of its net assets by $663,600 and $873,082 at December 31, 2016 and 2015, respectively.

The Partnership accounts for uncertainty in income taxes in accordance with applicable accounting guidance and recognizes the effects of those positions only if they are more likely than not of being sustained. As no liability had been recognized as of December 31, 2016 or 2015, the Partnership did not accrue for any interest or penalties.

3. Organization and Related Party Transactions:

The Partnership was organized on February 19, 2003 in accordance with the laws of the state of Delaware. Mewbourne Development Corporation (“MD”), a Delaware Corporation, has been appointed as the Registrant’s managing general partner. MD has no significant equity interest in the Registrant. Mewbourne Oil Company (MOC) is operator of oil and gas properties owned by the Partnership. Mewbourne Holdings, Inc. is the parent of both MD and MOC. Substantially all transactions are with MD and MOC.

In the ordinary course of business, MOC will incur certain costs that will be passed on to well owners of the well on which the costs were incurred. The Partnership will be charged their portion of these costs based upon their ownership in each well incurring the costs. These costs are referred to as Operator charges and are standard and customary in the oil and gas industry. Operator charges include recovery of gas marketing costs, fixed rate overhead, supervision, pumping, and equipment furnished by the operator, some of which will be included in the full cost pool pursuant to Rule 4-10(c)(2) of Regulation S-X. Amounts accrued for and paid to MOC for operator charges totaled $133,640 and $218,799 for the years ended December 31, 2016 and 2015, respectively. Operator charges are billed in accordance with the Program and Partnership Agreements.

In accordance with the Partnership agreement, during any particular calendar year, the total amount of administrative expenses allocated to the Partnership by MOC shall not exceed the greater of (a) 3.5% of the Partnership’s gross revenue from the sale of oil and gas production during each year (calculated without any deduction for operating costs or other costs and expenses) or (b) the sum of $50,000 plus .25% of the capital contributions of limited and general partners. Administrative expenses can only be paid out of funds available for distributions. Under this arrangement, $8,700 and $13,514 were allocated to the Partnership during the years ended December 31, 2016 and 2015, respectively.

The Partnership participates in oil and gas activities through a Drilling Program Agreement (the “Program”). The Partnership and MD are parties to the Program Agreement. The costs and revenues of the Program are allocated to MD and the Partnership as follows:

	Partnership			MD (1)
Revenues:
Proceeds from disposition of depreciable and depletable properties		60	%		40	%
All other revenues		60	%		40	%
Costs and expenses:
Organization and offering costs (1)		0	%		100	%
Lease acquisition costs (1)		0	%		100	%
Tangible and intangible drilling costs (1)		100	%		0	%
Operating costs, reporting and legal expenses, general and administrative expenses and all other costs		60	%		40	%

(1)

As noted above, pursuant to the Program, MD must contribute 100% of organization and offering costs and lease acquisition costs which should approximate 30% of total capital costs. To the extent that organization and offering costs and lease acquisition costs are less than 30% of total capital costs, MD is responsible for tangible drilling costs until its share of the Program’s total capital costs reaches approximately 30%. The Partnership’s financial statements reflect its respective proportionate interest in the Program.

4. Liquidity and Capital Resources

The Partnership had negative cash flows from operations of $692 and a decrease in cash of $4,017 for the year ended December 31, 2016. At December 31, 2016, it had negative working capital of $1,843. Management has evaluated the significance of these conditions in relation to the company’s ability to meet its obligations and has implemented a plan for alleviation. Included in this plan are temporarily halting distributions to partners, reducing pumping and overhead expenses, and obtaining an agreement with MOC to not demand immediate payment from the Partnership if the Partnership’s cash flows are insufficient to fund its operating costs. Management believes this plan alleviates the conditions of going concern.

MEWBOURNE ENERGY PARTNERS 03-A, L.P.

INDEX TO EXHIBITS

The following documents are incorporated by reference in response to Item 15(a)3.

EXHIBIT NUMBER		DESCRIPTION

3.1		Form of Certificate of Limited Partnership (filed as Exhibit 3.1 to Registration Statement on Form S-1, File No. 333-85994-01 and incorporated herein by reference)

3.2		Form of Certificate of Amendment of the Certificate of Limited Partnership (filed as Exhibit 3.2 to Registration Statement on Form S-1, File No. 333-85994-01 and incorporated herein by reference)

4.1		Form of Agreement of Partnership (filed as Exhibit 4.1 to Registration Statement on Form S-1, File No. 333-85994-01 and incorporated herein by reference)

10.1		Form of Drilling Program Agreement (filed as Exhibit 10.1 to Registration Statement on Form S-1, File No. 333-85994-01 and incorporated herein by reference)

10.4		Form of Operating Agreement (filed as Exhibit 10.4 to Registration Statement on Form S-1, File No. 333-85994-01 and incorporated herein by reference)

31.1		Certification of CEO Pursuant to Section 302 of Sarbanes-Oxley Act of 2002.

31.2		Certification of CFO Pursuant to Section 302 of Sarbanes-Oxley Act of 2002.

32.1		Certification of CEO Pursuant to Section 906 of Sarbanes-Oxley Act of 2002.

32.2		Certification of CFO Pursuant to Section 906 of Sarbanes-Oxley Act of 2002.

99.1		Report of Forrest A. Garb & Associates, Inc.

101		The following materials from the Partnership’s Annual Report on Form 10-K for the year ended December 31, 2016 formatted in Extensible Business Reporting Language (XBRL): (i) the Balance Sheets, (ii) the Statements of Operations, (iii) the Statements of Cash Flows, (iv) the Statement of Changes in Partners’ Capital and (v) related notes.

Filing Compare · MEWBOURNE ENERGY PARTNERS 03-A LP