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, 2016

For the year ended December 31, 2015

☐ TRANSITION REPORT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934 For the transition period from __________________________ to __________________________

For the transition period from _______________ to _________________

Commission File No. 000-53190

MEWBOURNE ENERGY PARTNERS 07-A, L.P.

Delaware		20-8481823
(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

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)

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 and general 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 $70,000,000.

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 Form 10.

MEWBOURNE ENERGY PARTNERS 07-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 07-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			7
	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			13
	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			16
	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 07-A, L.P. (the “Registrant” or the “Partnership”) is a limited partnership organized under the laws of the State of Delaware on March 1, 2007 (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.

Limited and general partner interests in the Registrant were offered at $5,000 each to accredited investors in a private placement pursuant to Section 4(2) of the Securities Act of 1933 and Regulation D promulgated thereunder, with a maximum offering amount of $70,000,000 (14,000 interests). On August 13, 2007, the offering of limited and general partnership interests in the Registrant was closed, with interests aggregating $70,000,000 originally being sold to accredited investors of which $65,710,000 were sold to accredited investors as general partner interests and $4,290,000 were sold to accredited investors as limited partner interests. During 2009 all general partner equity interests were converted to limited partner equity 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~~weather 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, a 10% change in the price received for oil and gas production would have had an approximate $184,000 impact on revenue.conditions;

•

the level of consumer demand;

•

the price and availability of alternative fuels;

•

the proximity, accessibility and capacity of 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 gas price movements with any certainty. Declines in oil and gas prices would not only reduce revenue, but could reduce the amount of oil and 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, 2016, a 10% change in the price received for oil and gas production would have had an approximate $172,000 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 Securities and Exchange Commission (“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 an impairment of oil and ~~natural~~ gas properties of $866,942 and $6,043,458 during the ~~year~~years 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~~• issevere ~~inherent~~damage ~~risk of incurring significant environmental costs and liabilities in exploration and production operations due~~ to ~~generation,~~or ~~handling,~~destruction ~~and disposal~~ of ~~materials~~property, ~~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~~resources ~~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.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 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 118 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 14,000~~ITEM ~~outstanding limited partnership interests held of record by 1,776 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 outcome of ~~$2,115,597~~these ~~and~~events ~~$3,117,425~~cannot ~~were~~be ~~made to~~predicted ~~partners~~with ~~during~~certainty, the ~~years~~Partnership ~~ended~~does ~~December~~not ~~31,~~expect ~~2015~~these ~~and~~matters ~~2014,~~to ~~respectively.~~have ~~Since~~a ~~inception,~~material effect ~~the~~on ~~Partnership~~its ~~has~~financial ~~made~~position ~~distributions of~~or ~~$62,467,247,~~results ~~inclusive~~ 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 partnership on~~ March 131, ~~2007.~~2017, ~~The~~the ~~offering~~Registrant ofhad ~~limited~~14,000 ~~and~~outstanding ~~general~~limited partnership interests ~~began~~held ~~May 1, 2007 as a part~~ of an ~~offering~~record ~~registered~~by ~~under~~1,776 ~~the name Mewbourne Energy Partners 07 Drilling Program~~subscribers. ~~The offering of limited and general partner~~There ~~interests~~is inno ~~the~~established ~~Registrant~~public ~~concluded~~or ~~August~~organized ~~13,~~trading ~~2007,~~market ~~with~~for ~~total~~the ~~investor~~ partner ~~contributions of $70,000,000~~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, to~~quarterly ~~distribute~~in ~~any~~accordance ~~net~~with ~~proceeds~~the ~~from~~Registrant’s ~~operations~~Partnership toAgreement. ~~the~~Distributions made ~~general~~to partners and ~~limited~~state ~~partners~~tax ~~and~~payments tofor the ~~extent~~benefit ~~necessary,~~of ~~acquire~~investor ~~leases which~~partners ~~contain~~during ~~drilling~~the ~~prospects.~~years ~~The~~ended ~~economic~~December ~~life~~31, of2016 ~~the~~and ~~Registrant~~2015 were ~~depends~~$734,089 onand ~~the~~$2,115,597, ~~period~~respectively. ~~over~~Since ~~which~~inception, the ~~Registrant’s oil~~Partnership ~~and~~has ~~gas~~made ~~reserves~~distributions ~~are~~of ~~economically~~$63,201,335, ~~recoverable~~inclusive of state tax 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~~ITEM ~~of the results of operations for the periods indicated~~7. ItManagement’s ~~should~~Discussion ~~be read in conjunction with the financial statements~~ and ~~the related~~Analysis ~~notes to the financial statements, which begin on page 20. As a result~~ of ~~declines in prices for commodities, the results~~ ofFinancial ~~our~~Condition ~~operations~~and ~~for~~Results ~~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	$	593,698	$	1,524,108
Barrels produced		13,294		17,445
Average price/bbl	$	44.66	$	87.37
Gas sales	$	1,248,847	$	2,884,337
Mcf produced		484,620		548,432
Average price/mcf	$	2.58	$	5.26

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 $2,565,900, a 58.2% decline, for the year ended December 31, 2015 as compared to the year ended December 31, 2014.7

~~Of this decline, $745,030 and $1,471,049 were~~Results ~~due to decreases in the average prices~~ of oil and gas sold, respectively. The average price fell to $44.66 from $87.37 per barrel (bbl) and to $2.58 from $5.26 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 ~~$185,380~~with the financial statements and ~~$164,441~~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 ~~4,151~~of ~~bbls~~operations ~~and~~for ~~63,812~~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 ~~$917,826 from $987,154 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 $97,585 from $245,483 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	$	616,508	$	593,698
Barrels produced		15,789		13,294
Average price/bbl	$	39.05	$	44.66

Gas sales	$	1,098,819	$	1,248,847
Mcf produced		454,609		484,620
Average price/mcf	$	2.42	$	2.58

~~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 $~~121~~127,~~407~~218, ~~from~~a ~~$212~~6.9% decline,~~311~~ 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~~$74,611 and ~~amortization. Depreciation~~$77, ~~depletion~~489 ~~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 $~~736,043~~39.05 from $~~844,046~~44.66 per barrel (bbl) and to $2.42 from $2.58 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~~was ~~totaling~~ $672,~~043,458~~539 ~~for the year ended December 31, 2015. These were~~ due to a lower ~~average~~volume ~~oil~~of ~~and~~ gas ~~prices~~sold ~~for~~by ~~the twelve months preceding the write-downs. There were no cost ceiling write-downs for the year ended December 31~~30,011 ~~2014~~mcf.

8Partially offsetting these decreases was an increase of $97,421 due to a higher volume of oil sold by 2,495 bbls.

~~Absent~~Lease operations. ~~significant~~Lease ~~price~~operating ~~increases,~~expense during the ~~sustained lower~~year ~~oil~~ended ~~prices~~December ~~experienced~~31, in2016 ~~2015~~decreased ~~will continue~~ to ~~impact~~$840,238 ~~our~~from ~~proved~~$917,826 ~~reserves adversely as the prices used~~ for ~~such estimates under SEC rules are based on~~ the ~~trailing~~year ~~12-month unweighted average prices, which were substantially higher at~~ ended December 31, ~~2014 than~~2015 ~~current oil prices. Lower prices used in estimating proved reserves may result in a reduction in volumes~~ due to ~~economic~~fewer ~~limits, which~~well inrepairs ~~turn,~~and ~~may~~workovers ~~make~~as itwell ~~more~~as ~~likely~~lower ~~that~~pumping weexpenses ~~will~~and ~~in the future incur impairment charges under full cost accounting~~overhead.

~~Liquidity~~Production taxes. Production taxes during the year ended December 31, 2016 decreased to $88,512 from $97,585 for the year ended December 31, 2015. This was due to lower overall oil and ~~Capital~~gas ~~Resources~~revenue for the year ended December 31, 2016.

~~Cash increased by $18,923 during the year ended~~Administrative ~~December~~and ~~31,~~general ~~2015~~expense. ~~Cash~~Administrative ~~flows from operating activities~~ and ~~proceeds~~general ~~from~~expense ~~asset sales were utilized primarily~~ for ~~cash~~the ~~distributions to~~year ~~partners.~~ended ~~All~~December ~~wells~~31, ~~for~~2016 ~~which~~fell ~~funds~~to ~~have~~$102,410 ~~been~~from ~~committed have been drilled. Any incidental future capital expenditures incurred will be paid with current available cash and revenues generated through oil and gas sales. Revenues which~~$121,407 ~~in the sole judgment~~for of the ~~managing~~year ~~general~~ended ~~partner~~December 31, ~~are~~2015 ~~not~~due ~~required~~ to ~~meet~~decreased ~~the~~administrative ~~Registrant’s~~expenses ~~obligations~~allocable ~~will be distributed~~ to the ~~partners at least quarterly in accordance with the Registrant’s~~ Partnership ~~Agreement~~.

~~The~~Depreciation, depletion ~~Partnership~~and ~~had~~amortization. ~~reduced~~Depreciation, ~~cash~~depletion ~~flows~~and ~~from operations~~amortization infor ~~2015~~the ~~due~~year toended ~~the~~December ~~steep~~31, ~~decline~~2016 indecreased ~~oil~~to ~~and~~$388,496 from ~~gas~~$736,043 ~~prices~~for ~~during~~ the year ended December 31, 2015. ~~Considering~~This ~~these~~was due to cost ceiling write-downs that reduced ~~operating~~ ~~cashflows,~~the balance of the ~~Partnership~~full cost ~~anticipates~~pool ~~smaller~~subject ~~distributions~~to ~~until~~amortization ~~prices~~as ~~improve~~well as an overall decrease in oil and gas production.

~~Critical~~Cost ceiling ~~Accounting~~write-down. ~~Policies~~There were cost ceiling write-downs totaling $866,942 and $6,043,458 for the years ended December 31, 2016 and 2015, respectively. These were due to lower average oil and gas prices for the twelve months preceding the write-downs.

The preparation of 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.8

~~Significant~~Absent significant ~~estimates~~price ~~inherent~~increases, in the ~~Registrant’s financial~~sustained ~~statements~~lower ~~include~~oil ~~the~~prices ~~estimate~~experienced ofin ~~oil~~2016 ~~and~~will ~~gas~~continue to impact proved reserves ~~and~~adversely as ~~future~~the ~~abandonment~~prices ~~costs.~~used ~~Changes~~for insuch ~~oil~~estimates ~~and~~under ~~gas~~SEC ~~prices~~rules ~~and~~ are based on the ~~changes~~trailing in12-month ~~production~~unweighted ~~estimates~~average ~~could~~prices. ~~have~~Lower aprices used ~~significant~~in ~~effect~~estimating onproved ~~reserve~~reserves ~~estimates.~~may ~~The~~result ~~reserve~~in ~~estimates~~a ~~directly~~reduction ~~impact the~~in ~~computation~~volumes ofdue ~~depreciation,~~to ~~depletion~~economic limits, ~~and~~which ~~amortization~~in turn, ~~asset~~may ~~retirement~~make ~~obligation,~~it ~~and~~more likely ~~the~~that ~~ceiling~~we ~~test~~will ~~for~~in the ~~Registrant’s oil~~future ~~and~~incur ~~gas~~impairment ~~properties~~charges under full cost accounting.

~~All financing activities of the Registrant~~Liquidity 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~~Capital ~~non-producing properties as discussed below.~~Resources

~~Full~~Cash decreased ~~Cost~~by ~~Method~~$64,481 during the year ended December 31, 2016. Cash flows from operating activities and proceeds from asset sales were utilized primarily for cash distributions to partners. All wells for which funds have been committed have been drilled. Any incidental future capital expenditures incurred will be paid with current available cash and revenues generated through oil and gas sales. Revenues which, in the sole judgment of ~~Accounting~~the managing general partner, are not required to meet the Registrant’s obligations will be distributed to the partners at least quarterly in accordance with the Registrant’s Partnership Agreement.

The ~~Registrant follows the full-cost method~~ ofPartnership ~~accounting~~had ~~for~~reduced ~~its~~cash ~~oil~~flows ~~and~~from ~~gas~~operations ~~activities. Under the full-cost method, all productive and non-productive costs incurred~~ in ~~the acquisition,~~2016 ~~exploration~~due ~~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~~steep ~~method~~decline ~~based~~in ~~on the proved reserves underlying the~~ oil and gas ~~properties~~prices. ~~Oil~~Considering ~~and~~these ~~gas properties are subject to a quarterly ceiling test that limits such costs to the aggregate~~reduced ofoperating ~~the~~cashflows, ~~present value of future net cash flows of proved reserves and~~ the ~~lower~~Partnership ofanticipates ~~cost~~smaller ordistributions ~~fair~~to ~~value~~partners ofuntil ~~unproved~~prices ~~properties~~improve. The Partnership’s ~~present~~revenue ~~value~~and ~~of future net~~ cash ~~flows~~flow ~~has~~from ~~been~~operating ~~prepared~~activities byare ~~using~~highly ~~the~~dependent ~~oil~~on ~~and~~commodity ~~gas pricing guidelines established by the Securities and Exchange Commission, projected development and production costs and a 10 percent annual discount rate~~prices.

~~Asset~~Critical Accounting ~~Retirement Obligations~~Policies

The preparation ~~Partnership~~of ~~has~~financial ~~recognized~~statements anin ~~estimated~~conformity ~~liability~~with ~~for~~generally ~~future~~accepted ~~plugging~~accounting ~~and~~principles ~~abandonment~~requires ~~costs.~~management Ato ~~liability~~make estimates ~~for~~and ~~the~~assumptions ~~estimated~~that ~~fair~~affect ~~value~~the ofreported ~~the~~amounts ~~future~~of ~~plugging~~assets and ~~abandonment~~liabilities ~~costs~~and isdisclosure ~~recorded~~of ~~with~~contingent aassets ~~corresponding~~and ~~increase in the full~~liabilities ~~cost pool~~ at the ~~time~~date aof ~~new~~the ~~well~~financial isstatements ~~drilled.~~and ~~Depreciation~~the ~~expense~~reported ~~associated~~amounts ~~with~~of ~~estimated~~revenues ~~plugging~~ and ~~abandonment~~expenses ~~costs~~during ~~is recognized~~the inreporting ~~accordance~~period. ~~with~~Actual results ~~the~~could ~~full~~differ ~~cost~~from ~~methodology~~those estimates.

9Significant estimates inherent in the Registrant’s 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.

~~The Partnership estimates a liability for plugging~~All ~~and~~financing ~~abandonment~~activities ~~costs~~of ~~based~~the onRegistrant ~~historical~~are ~~experience~~reported ~~and~~in ~~estimated~~the ~~well~~financial ~~life~~statements. The ~~liability~~Registrant isdoes ~~discounted~~not ~~using~~engage ~~the~~in ~~credit~~any off-~~adjusted~~balance ~~risk-free~~sheet ~~rate~~financing arrangements. ~~Revisions~~Additionally, to the ~~liability~~Registrant ~~could~~has ~~occur~~no ~~due~~contractual toobligations ~~changes~~but inhas ~~well~~a ~~plugging~~financial ~~and~~obligation ~~abandonment~~to ~~costs or well useful lives,~~plug orand ifabandon ~~federal~~non-producing orproperties ~~state~~as ~~regulators~~discussed ~~enact new well restoration requirements~~below. ~~The Partnership recognizes accretion expense in connection with the discounted liability over the remaining life of the well.~~

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

	2015			2014
Balance, beginning of period	$	534,688		$	500,468
Liabilities incurred		665			—
Liabilities reduced due to sales of property		(12,560	)		—
Accretion expense		36,178			34,220
Balance, end of period	$	558,971		$	534,688

In May 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 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.

~~Organization and Related Party Transactions~~9

~~The Partnership was organized on March 1, 2007~~Full inCost ~~accordance~~Method ~~with the laws~~ of the state of Delaware. 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 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.Accounting

InThe Registrant follows the ~~ordinary~~full-cost ~~course~~method of ~~business,~~accounting ~~MOC~~for ~~will incur~~its ~~certain~~oil ~~costs~~and ~~that~~gas ~~will~~activities. beUnder ~~passed~~the onfull-cost tomethod, ~~well~~all ~~owners~~productive and ofnon-productive ~~the~~costs ~~well~~incurred ~~for~~in ~~which~~ the ~~costs~~acquisition, ~~were~~exploration ~~incurred.~~and ~~The~~development ~~Partnership~~of ~~will~~oil ~~receive their~~and ~~portion~~gas ofproperties ~~these~~are ~~costs~~capitalized. ~~based~~Depreciation, depletion ~~upon~~and ~~their~~amortization ~~ownership~~of inoil ~~each~~and ~~well~~gas ~~incurring~~properties ~~the~~subject ~~costs.~~to ~~These~~amortization ~~costs~~is ~~are~~computed ~~referred~~on tothe asunits-of-production ~~operator~~method based ~~charges~~on ~~and~~the ~~are~~proved ~~standard~~reserves ~~and~~underlying ~~customary in~~ the oil and gas ~~industry~~properties. ~~Operator~~Oil ~~charges~~and ~~include~~gas ~~recovery~~properties ofare ~~gas~~subject ~~marketing~~to ~~costs,~~a ~~fixed rate~~quarterly ~~overhead,~~ceiling ~~supervision,~~test ~~pumping,~~that limits ~~and~~such ~~equipment~~costs ~~furnished~~to bythe aggregate of the ~~operator,~~present ~~some~~value of ~~which~~future ~~will~~net becash ~~included~~flows inof ~~the~~proved ~~full~~reserves ~~cost~~and ~~pool pursuant~~the tolower ~~Rule~~of ~~4-10(c)(2)~~cost or fair value of ~~Regulation~~unproved ~~S-X~~properties. ~~Amounts~~The ~~accrued~~present ~~for~~value ~~and~~of ~~paid~~future tonet ~~MOC~~cash ~~for~~flows ~~operator~~has ~~charges~~been ~~totaled~~prepared ~~$575,837~~by ~~and~~using ~~$556,777 for~~ the ~~years~~oil ~~ended~~and ~~December~~gas ~~31,~~pricing ~~2015~~guidelines established ~~and~~by ~~2014~~the SEC, ~~respectively.~~projected ~~Operator~~development ~~charges~~and ~~are~~production ~~billed~~costs inand ~~accordance~~a ~~with~~10 ~~the~~percent ~~Program~~annual ~~and~~discount ~~Partnership Agreements~~rate.

~~In accordance with the Partnership agreement,~~Asset ~~during~~Retirement 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 natural 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, $80,704 and $168,634 were allocated to the Partnership during the years ended December 31, 2015 and 2014, respectively.Obligations

10The 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 ~~participates~~estimates ina ~~oil~~liability for plugging and ~~gas activities~~abandonment ~~through~~costs abased ~~Drilling~~on ~~Program~~historical ~~Agreement~~experience ~~(the~~and ~~“Program”)~~estimated well life. The liability ~~Partnership~~is ~~and~~discounted MDusing ~~are~~the ~~parties~~credit-adjusted risk-free rate. Revisions to the ~~Program~~liability could occur due to changes in well ~~Agreement.~~plugging ~~The~~and abandonment costs ~~and~~or ~~revenues~~well ofuseful ~~the~~lives, ~~Program~~or ~~are~~if ~~allocated~~federal toor MDstate ~~and~~regulators ~~the~~enact new well restoration requirements. The Partnership asrecognizes ~~follows:~~accretion expense in connection with the discounted liability over the remaining life of the well.

	Partnership			MD (1)
Revenues:
Proceeds from disposition of depreciable and depletable properties		70	%		30	%
All other revenues		70	%		30	%
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		70	%		30	%

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:

(1) As noted above, pursuant to the Program, MD must contribute 100% of organization and offering costs and lease acquisition costs which should approximate 20% of total capital costs. To the extent that organization and offering costs and lease acquisition costs are less than 20% of total capital costs, MD is responsible for tangible drilling costs until its share of the Program's total capital costs reaches approximately 20%. The Partnership's financial statements reflect its respective proportionate interest in the Program.

	2016		2015
Balance, beginning of period	$	558,971	$	534,688
Liabilities incurred		—		665
Liabilities reduced due to sales of property		—		(12,560	)
Accretion expense		38,204		36,178
Balance, end of period	$	597,175	$	558,971

~~ITEM~~Organization ~~7A. Quantitative~~ and ~~Qualitative~~Related ~~Disclosures about Market Risk~~Party Transactions

~~Not~~The Partnership ~~required~~was ~~under~~organized ~~Regulation~~on ~~S-K~~March 1, ~~Item~~2007 ~~305~~in ~~for~~accordance ~~smaller~~with ~~reporting~~the laws of the state of Delaware. MD, a Delaware Corporation, has ~~companies~~been appointed as the Registrant’s managing general partner. MD has no significant equity interest in the Registrant. 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.

~~ITEM~~In the 8ordinary 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. ~~Financial~~The ~~Statements~~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 ~~Supplementary~~are ~~Data~~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 $507,553 and $575,837 for the years ended December 31, 2016 and 2015, respectively. Operator charges are billed in accordance with the Program and Partnership Agreements.

The required financial statements of the Registrant are contained in a separate section of this report following the signature attestation. See “Item 15. Exhibits, Financial Statements, Financial Statement Schedules and Reports on Form 8-K”.10

11In 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, $55,610 and $80,704 were allocated to the Partnership during the years ended December 31, 2016 and 2015, respectively.

~~ITEM~~The Partnership 9participates in oil and gas activities through a Drilling Program Agreement (the “Program”). ~~Changes~~The inPartnership and MD are parties to the Program Agreement. The costs and ~~Disagreements~~revenues ~~with~~of ~~Accountants~~the onProgram ~~Accounting~~are allocated to MD and ~~Financial~~the ~~Disclosure~~Partnership as follows:

None.

	Partnership			MD (1)
Revenues:
Proceeds from disposition of depreciable and depletable properties		70	%		30	%
All other revenues		70	%		30	%
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		70	%		30	%

~~ITEM~~(1) 9AAs noted above, pursuant to the Program, MD must contribute 100% of organization and offering costs and lease acquisition costs which should approximate 20% of total capital costs. ~~Controls~~To the extent that organization and ~~Procedures~~offering costs and lease acquisition costs are less than 20% of total capital costs, MD is responsible for tangible drilling costs until its share of the Program’s total capital costs reaches approximately 20%. The Partnership’s financial statements reflect its respective proportionate interest in the Program.

~~(a)~~ITEM 7A. ~~Evaluation~~Quantitative ofand ~~Disclosure~~Qualitative ~~Controls and~~Disclosures ~~Procedures~~about Market Risk

~~As of the end of the period covered by~~Not ~~this~~required ~~report, MD’s management conducted an evaluation,~~ under ~~the~~Regulation ~~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~~S-~~15(e) and 15d-15(e) under the Exchange Act). Based on this evaluation~~K, ~~MD's~~Item ~~principal~~305 ~~executive~~for ~~officer~~smaller ~~and~~reporting ~~principal financial officer concluded that, as of the end of the period covered by this report, the Registrant’s disclosure controls and procedures are effective~~companies. 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.

~~(b) MD Management’s Annual Report~~ITEM on8. ~~Internal~~Financial ~~Control~~Statements ~~Over~~and ~~Financial~~Supplementary ~~Reporting~~Data

~~MD’s management is responsible for establishing~~The ~~and~~required ~~maintaining adequate internal control over~~ financial ~~reporting,~~statements ~~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~~Registrant ofare ~~the~~contained ~~Partnership’s internal control over financial reporting based on the framework~~ in ~~“Internal~~a ~~Control~~separate —section ~~Integrated Framework” (1992) issued by the Committee~~ of ~~Sponsoring Organizations~~this 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~~following ~~not include an attestation report of~~ the ~~Registrant’s~~signature ~~independent registered public accounting firm regarding internal control over financial reporting. Management’s report was not subject to~~ attestation by. ~~the~~See ~~Registrant’s~~“Item ~~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~~15. ~~There have been no changes in MD’s internal controls for the quarter ended December 31~~Exhibits, ~~2015~~Financial ~~or in other factors which have materially affected~~Statements, orFinancial ~~are~~Statement ~~reasonably likely~~Schedules toand ~~materially~~Reports ~~affect~~on ~~the~~Form ~~internal controls over financial reporting~~8-K”.

1211

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

~~ITEM 10~~None. ~~Directors and Executive Officers of the Registrant~~

~~The Registrant does not have any officers or~~ITEM ~~directors~~9A. ~~Under~~Controls ~~the Registrant’s 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 forth below are the names, ages and positions~~(a) ofEvaluation ~~the directors and executive officers~~ of ~~MD,~~Disclosure ~~the~~Controls ~~Registrant’s managing general partner. Directors of MD are elected to serve until the next annual meeting of stockholders or until their successors are elected~~ and ~~qualified.~~Procedures

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

As of the end of the period covered by 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). Based on this evaluation, MD’s principal executive officer and principal financial 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.

~~J. Roe Buckley, age 53, joined Mewbourne~~(b) ~~Holdings,~~MD ~~Inc.~~Management’s inAnnual ~~July,~~Report ~~1990~~on ~~and~~Internal ~~serves~~Control asOver ~~Chairman of the Board and Chief~~ Financial Officer of Mewbourne Holdings, Inc., MD and MOC. Mr. Buckley was employed by Mbank Dallas from 1985 to 1990 where he served as a commercial loan officer. He received a Bachelor of Arts in Economics 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.Reporting

~~Kenneth~~MD’s management S.is ~~Waits~~responsible for establishing and maintaining adequate internal control over financial reporting, ~~age~~as such term is ~~55,~~defined ~~Chief~~in ~~Executive~~Exchange ~~Officer~~Act Rules 13a-15(f). Under the supervision and with the participation of ~~Mewbourne~~MD’s ~~Holdings~~management, ~~Inc.,~~ including MD’s principal executive officer and ~~MOC~~principal financial officer, ~~has~~MD ~~been~~conducted ~~with~~an ~~MOC~~evaluation ~~since~~of ~~February~~the ~~1984.~~effectiveness Heof ~~joined~~the Partnership’s internal control over financial reporting based on the ~~company~~framework in “Internal Control — Integrated ~~following~~Framework” ~~his~~(1992) ~~graduation~~issued ~~from~~by the ~~University~~Committee of ~~Oklahoma~~Sponsoring ~~where~~Organizations heof ~~received~~the aTreadway ~~Bachelor~~Commission. ofBased ~~Science~~on inMD’s ~~Petroleum~~evaluation under ~~Engineering~~the framework in ~~December~~“Internal Control — Integrated Framework”, MD’s management concluded that internal ~~1983~~control over financial reporting was effective as of December 31, 2016. HeThis ~~currently~~annual ~~manages~~report ~~all~~does not include an attestation report of ~~MOC~~the Registrant’s ~~exploration~~independent ~~efforts~~registered public accounting firm regarding internal control over financial reporting. HeManagement’s report ~~has~~was ~~also~~not ~~served~~subject asto ~~Exploration~~attestation ~~Manager~~by ~~for~~the ~~Western~~Registrant’s ~~Oklahoma.~~independent registered public accounting firm pursuant to rules ~~Previously~~of atthe ~~MOC,~~SEC hethat ~~held~~permit ~~positions~~the Registrant to provide only management’s report in ~~Operations~~this ~~and~~annual report. There have been no changes in ~~Reservoir/Evaluations~~MD’s internal controls for the quarter ended December 31, 2016 or in other factors which have materially affected, or are reasonably likely to materially affect the internal controls over financial reporting.

1312

~~Alan Clark, age~~PART 63, 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.III

~~Dorothy M. Cuenod,~~ITEM ~~age 55, 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~~10. ~~Since~~Directors ~~1984 she has served as a Director~~ and ~~Assistant~~Executive ~~Secretary~~Officers of ~~both MD and MOC. Ms. Cuenod is~~ the ~~sister of Ruth M. Buckley and Julie M. Greene. She is also the sister-in-law of J. Roe Buckley.~~Registrant

~~Ruth M. Buckley,~~The ~~age~~Registrant ~~54,~~does ~~received~~not ahave ~~Bachelor~~any ofofficers ~~Science~~or ~~Degree~~directors. inUnder ~~both~~the ~~Engineering~~Registrant’s ~~and~~Partnership ~~Geology~~Agreement, ~~from~~the ~~Vanderbilt~~Registrant’s managing ~~University.~~partner, ~~Since~~MD, ~~1987~~is ~~she~~granted ~~has~~the ~~served as~~exclusive aright ~~Director~~ and ~~Assistant~~full ~~Secretary~~authority ofto ~~both~~manage, MDcontrol and ~~MOC.~~administer ~~Ms. Buckley is~~ the ~~sister of Dorothy M~~Registrant’s business. ~~Cuenod~~MD ~~and Julie M. Greene. She~~ is ~~also~~a ~~the~~wholly ~~wife~~owned subsidiary of J.Mewbourne ~~Roe~~Holdings, ~~Buckley~~Inc.

~~Julie~~Set forth M.below ~~Greene, age~~are 52the names, ~~received~~ages aand ~~Bachelor~~positions of ~~Arts~~the ~~degree~~directors inand ~~Business~~executive ~~Administration~~officers ~~from The University~~ of ~~Oklahoma.~~MD, ~~Since~~the ~~1988~~Registrant’s ~~she~~managing ~~has served~~general aspartner. aDirectors ~~Director and Assistant Secretary~~ of ~~both~~ MD ~~and~~are ~~MOC.~~elected ~~Prior~~ to ~~that~~serve ~~time~~until ~~she~~the ~~was~~next ~~employed~~annual bymeeting ~~Rauscher,~~of ~~Pierce,~~stockholders ~~Refsnes,~~or ~~Inc. Ms.~~until ~~Greene~~their issuccessors ~~the~~are ~~sister of Dorothy M. Cuenod~~ elected and ~~Ruth M~~qualified. ~~Buckley. She is also the sister-in-law of J. Roe Buckley.~~

The organizational structure of the Partnership does not provide for an audit committee and therefore the Partnership does not have an audit committee or financial expert serving in such capacity.

	Age as of
	December 31,
Name	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

~~ITEM~~J. Roe 11Buckley, age 54, joined Mewbourne Holdings, Inc. ~~Executive~~ ~~Compensation~~in July, 1990 and serves as Chairman of the Board and Chief Financial Officer of Mewbourne Holdings, Inc., MD and MOC. Mr. Buckley was employed by Mbank Dallas from 1985 to 1990 where he served as a commercial loan officer. He received a Bachelor of Arts in Economics 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.

~~The Registrant does not have any officers~~Kenneth ~~or directors~~S. ~~Management~~Waits, ofage ~~the~~56, ~~Registrant~~Chief isExecutive ~~vested~~Officer inof ~~the~~Mewbourne ~~managing~~Holdings, ~~general partner~~Inc., ~~None~~MD ofand ~~the~~MOC, ~~officers~~has orbeen ~~directors~~with ~~of MD or~~ MOC ~~will~~since ~~receive~~February ~~remuneration~~1984. ~~directly~~He ~~from~~ joined the ~~Registrant,~~company ~~but~~following ~~will~~his ~~continue~~graduation tofrom bethe ~~compensated~~University byof ~~their~~Oklahoma ~~present~~where ~~employers. The~~he ~~Registrant~~received ~~will~~a ~~reimburse~~Bachelor ~~MD and MOC and affiliates thereof for certain costs~~ of ~~overhead~~Science ~~falling~~in ~~within~~Petroleum ~~the definition of~~Engineering ~~Administrative~~in ~~Costs~~December, ~~including~~1983. ~~without~~He ~~limitation,~~currently ~~salaries~~manages ofall ~~the officers and employees~~ of ~~MD and~~ MOC;’s ~~provided~~exploration ~~that~~efforts. noHe ~~portion of~~has ~~the~~also ~~salaries~~served ofas ~~the~~Exploration ~~directors~~Manager orfor Western ofOklahoma. ~~the~~Previously ~~executive~~at ~~officer of~~ MOC, orhe MDheld ~~may~~positions bein ~~reimbursed~~Operations asand ~~Administrative~~in ~~Costs~~Reservoir/Evaluations.

1413

~~ITEM~~Alan Clark, ~~12. Security~~age ~~Ownership~~64, joined MOC in 1979 and serves as Treasurer and Controller of ~~Certain~~both MD and MOC. Prior to joining MOC, Mr. Clark ~~Beneficial~~was ~~Owners~~employed by Texas Oil and ~~Management~~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.

(Dorothy M. Cuenod, age 56, received a) ~~Beneficial~~Bachelor ~~owners~~of Arts degree in Art History from The University of ~~more~~Texas ~~than~~and ~~five~~a ~~percent~~Masters of Business atAdministration ~~March~~Degree ~~30,~~from ~~2016~~Southern Methodist University. Since 1984 she has served as a Director and Assistant Secretary of both MD and MOC. Ms. Cuenod is the sister of Ruth M. Buckley and Julie M. Greene. She is also the sister-in-law of J. Roe Buckley.

~~Class~~Ruth M. Buckley, age 55, received a Bachelor of ~~Name~~Science Degree in both Engineering and ~~Address~~Geology offrom ~~Amount~~Vanderbilt University. Since 1987 she has served as a Director and ~~Nature~~Assistant Secretary of ~~Percent~~both MD and MOC. Ms. Buckley is the sister of ~~Limited~~Dorothy ~~Ownership~~M. ~~Beneficial~~Cuenod ~~Owner~~and Julie ~~Beneficial~~M. ~~Owner~~Greene. ~~Partnership~~She ~~Interests~~is ~~N/A~~also ~~N/A~~the ~~N/A~~wife ~~N/A~~of J. Roe Buckley.

~~(b)~~Julie M. ~~Security~~Greene, ~~ownership~~age 53, received a Bachelor of ~~management~~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.

The ~~Registrant does not have any officers~~ ororganizational ~~directors.~~structure ~~The managing general partner~~ of the ~~Registrant,~~Partnership ~~MD,~~does ~~has~~not ~~the~~provide ~~exclusive~~for ~~right~~an toaudit ~~manage~~committee and ~~administer~~therefore the ~~Registrant’s business. Under the Registrant’s~~ Partnership ~~Agreement,~~does ~~limited~~not ~~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.~~an ~~The~~audit ~~Registrant~~committee ~~is not aware of any current arrangement~~ or ~~activity~~financial ~~that~~expert ~~may~~serving ~~lead~~in to such ~~removal~~capacity.

ITEM 13 11. ~~Certain~~ ~~Relationships~~Executive ~~and Related Transactions~~Compensation

~~Transactions~~The Registrant ~~with~~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 ~~its~~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.

~~Pursuant to the Registrant’s Partnership Agreement, the Registrant~~ITEM ~~had~~12. ~~the~~Security ~~following~~Ownership ~~related~~of ~~party~~Certain ~~transactions~~Beneficial ~~with~~Owners MD and ~~its affiliates for the years ended December 31, 2015 and 2014:~~Management

	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	$	656,541	$	725,411

(a) Beneficial owners of more than five percent at March 31, 2017

~~The~~Class ~~Registrant participates in oil and gas activities through a drilling Program created by the Program. Pursuant to the Program, MD pays approximately 20%~~ of ~~the~~Name ~~Program’s capital expenditures~~ and ~~approximately~~Address ~~30%~~ of ~~its~~Amount ~~operating~~ and ~~general~~Nature ~~and administrative expenses. The Registrant pays the remainder~~ of ~~the~~Percent ~~costs and expenses~~ of ~~the~~Limited ~~Program.~~Ownership InBeneficial ~~return,~~Owner MDBeneficial isOwner ~~allocated~~Partnership ~~approximately~~Interests ~~30%~~N/A ofN/A ~~the~~N/A ~~Program’s revenues.~~N/A

~~ITEM~~(b) Security ~~14. Principal~~ownership ~~Accountant~~of ~~Fees and Services~~management

The Registrant ~~Partnership~~does ~~has~~not ~~retained~~have ~~BDO~~any ~~USA,~~officers ~~LLP as~~or ~~their~~directors. ~~independent~~The ~~registered~~managing ~~public~~general ~~accounting~~partner ~~firm~~of the Registrant, MD, has the exclusive right to ~~perform~~manage ~~auditing~~and ~~services~~administer the Registrant’s business. ~~BDO~~Under ~~USA,~~the ~~LLP~~Registrant’s ~~fees~~Partnership ~~for~~Agreement, ~~the~~limited ~~years~~and ~~ended~~general ~~December~~partners ~~31,~~holding ~~2015~~a majority of the outstanding limited and ~~2014~~general ~~are~~partnership ~~set~~interests ~~forth~~have ~~below:~~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.

		2015				2014
Audit Fees		$	26,667			$	27,585

15ITEM 13. Certain Relationships and Related Transactions

~~PART~~Transactions with IV MD and its affiliates

~~ITEM 15. Exhibits,~~Pursuant ~~Financial~~to ~~Statements~~the Registrant’s Partnership Agreement, ~~Financial~~the ~~Statement~~Registrant ~~Schedules~~had the following related party transactions with MD and ~~Reports~~its onaffiliates for ~~Form~~the ~~8-K~~years ended December 31, 2016 and 2015:

(a)	1.	Financial statements
		2016		2015
		The following are filed as part of this annual report:
Administrative and general expense, management fees (if applicable) and payment of well charges and supervision charges in accordance with standard industry operating agreements		$	563,163	$	656,541
			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.

16The Registrant participates in oil and gas activities through a drilling Program created by the Program. Pursuant to the Program, MD pays approximately 20% of the Program’s capital expenditures and approximately 30% 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 30% of the Program’s revenues.

~~SIGNATURES~~ITEM 14. Principal Accountant Fees and Services

~~Pursuant~~The Partnership tohas ~~the~~retained ~~requirements~~BDO ofUSA, ~~Section~~LLP 13as ~~or 15(d)~~their ofindependent ~~the~~registered ~~Securities~~public ~~Exchange~~accounting ~~Act~~firm ofto ~~1934,~~perform ~~the~~auditing ~~Registrant~~services. ~~has~~BDO USA, ~~duly~~LLP’s ~~caused~~fees ~~this~~for ~~report~~the toyears beended ~~signed~~December on31, ~~its~~2016 ~~behalf~~and by2015 ~~the~~are ~~undersigned, thereto~~set ~~duly~~forth ~~authorized.~~below:

	Mewbourne Energy Partners 07-A, L.P.
		2016		2015
	By:	Mewbourne Development Corporation
Audit Fees		$	27,737	$	26,667
		Managing General Partner
	By:	/s/ Kenneth S. Waits
		Kenneth S. Waits
		Chief Executive Officer

Pursuant to the requirements of the Securities 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.15

/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

PART IV

~~Supplemental Information~~ITEM ~~to be Furnished With Reports Filed Pursuant to Section~~ 15~~(d)~~. ofExhibits, ~~the~~Financial ~~Act~~Statements, byFinancial ~~Registrants~~Statement ~~Which~~Schedules ~~Have~~and ~~Not~~Reports ~~Registered~~on ~~Securities~~Form ~~Pursuant to Section 12 of the Act~~8-K

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


(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, 2016 and 2015

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

			Statements of changes in partners’ capital for the years ended December 31, 2016 and 2015

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

			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.

17ITEM 16. Form 10-K Summary

~~MEWBOURNE ENERGY PARTNERS 07-A, L~~None.P.

~~FINANCIAL STATEMENTS~~16

~~WITH REPORT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM~~SIGNATURES

AsPursuant to the requirements of ~~and~~Section ~~for~~13 or 15(d) of the ~~years~~Securities ~~ended~~Exchange ~~December~~Act 31of 1934, the Registrant has duly caused this report ~~2015~~to ~~and~~be ~~2014~~signed on its behalf by the undersigned, thereto duly authorized.

	Mewbourne Energy Partners 07-A, L.P.

	By:	Mewbourne Development Corporation
		Managing General Partner


	By:	/s/ Kenneth S. Waits
		Kenneth S. Waits
		Chief Executive Officer

~~Report~~Pursuant to the requirements of ~~Independent~~the ~~Registered~~Securities Exchange Act of 1934, this report has been signed below by the following persons on behalf ~~Public~~of ~~Accounting~~the ~~Firm~~Registrant and in the capacities and on the date indicated.

To the Partners of Mewbourne Energy Partners 07-A, L.P. and to the Board of Directors of Mewbourne Development Corporation

/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

~~Tyler,~~Supplemental ~~Texas~~Information to be Furnished With Reports Filed Pursuant to Section 15(d) of the Act by Registrants Which Have Not Registered Securities Pursuant to Section 12 of the Act

WeNo ~~have~~annual ~~audited~~report ~~the~~or ~~accompanying~~proxy ~~balance~~material ~~sheets~~has ofbeen ~~Mewbourne~~sent ~~Energy~~to ~~Partners 07-A, L.P. (Partnership) as of December 31, 2015 and 2014 and~~ the ~~related statements of operations, changes in partners~~Registrant’ ~~capital and cash flows for the years then ended. These financial statements are the responsibility of the Partnership’~~s ~~management.~~security ~~Our responsibility is to express an opinion on these financial statements based on our audits~~holders.

We conducted our audits in accordance with the standards of the Public Company Accounting Oversight Board (United States). Those standards require that we plan and perform the audit to obtain reasonable assurance about whether the financial statements are free of material misstatement. The Partnership is not required to have, nor were we engaged to perform, an audit of its internal control over financial reporting. Our audits included consideration of internal 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.17

InMEWBOURNE ~~our~~ENERGY ~~opinion,~~PARTNERS ~~the financial statements referred to above present fairly~~07-A, 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 AmericaL.P.

~~/s/BDO~~FINANCIAL ~~USA, LLP~~STATEMENTS

~~Dallas,~~WITH ~~Texas~~REPORT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM

~~March~~As 30of and for the years ended December 31, 2016 and 2015

1918

~~MEWBOURNE~~Report of ~~ENERGY~~Independent ~~PARTNERS~~Registered ~~07-A,~~Public ~~L.P.~~Accounting Firm

~~BALANCE~~To the ~~SHEETS~~Partners of Mewbourne Energy Partners 07-A, L.P. and to the Board of Directors of Mewbourne Development Corporation

	December 31, 2015			December 31, 2014
ASSETS
Cash	$	77,310		$	58,387
Accounts receivable, affiliate		221,914			524,098
Prepaid state taxes		5,344			4,161
Total current assets		304,568			586,646
Oil and gas properties at cost, full-cost method		66,184,314			66,172,805
Less accumulated depreciation, depletion,
amortization and impairment		(61,191,872	)		(53,218,816	)
		4,992,442			12,953,989
Total assets	$	5,297,010		$	13,540,635
LIABILITIES AND PARTNERS' CAPITAL
Accounts payable, affiliate	$	82,461		$	124,820
Total current liabilities		82,461			124,820
Asset retirement obligation		558,971			534,688
Partners' capital		4,655,578			12,881,127
Total liabilities and partners' capital	$	5,297,010		$	13,540,635

Tyler, Texas

~~The~~We have audited the accompanying ~~notes~~balance ~~are~~sheets anof ~~integral~~Mewbourne ~~part~~Energy Partners 07-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.

20We conducted our audits in accordance with the standards of the Public Company Accounting Oversight Board (United States). Those standards require that we plan and perform the audit to obtain reasonable assurance about whether the financial statements are free of material misstatement. The Partnership is not required to have, nor were we engaged to perform, an audit of its internal control over financial reporting. Our audits included consideration of internal 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.

~~MEWBOURNE~~In our ~~ENERGY~~opinion, ~~PARTNERS~~the ~~07-A~~financial statements referred to above present fairly, Lin 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.P.

~~STATEMENTS~~/s/BDO OFUSA, ~~OPERATIONS~~LLP

	For the Years Ended
	December 31,
	2015			2014
Revenues and other income:
Oil sales	$	593,698		$	1,524,108
Gas sales		1,248,847			2,884,337
Interest income		—			16
Total revenues and other income		1,842,545			4,408,461
Expenses:
Lease operating expense		917,826			987,154
Production taxes		97,585			245,483
Administrative and general expense		121,407			212,311
Depreciation, depletion, and amortization		736,043			844,046
Cost ceiling write-down		6,043,458			—
Asset retirement obligation accretion		36,178			34,220
Total expenses		7,952,497			2,323,214
Net (loss) income	$	(6,109,952	)	$	2,085,247

Dallas, Texas

~~The accompanying notes are an~~March ~~integral~~31, ~~part of the financial statements.~~2017

2119

MEWBOURNE ENERGY PARTNERS 07-A, L.P.

~~STATEMENTS~~BALANCE ~~OF CHANGES IN PARTNERS’ CAPITAL~~SHEETS

For the years ended December 31, 2015 and 2014

	December 31, 2016			December 31, 2015

ASSETS

Cash	$	12,829		$	77,310
Accounts receivable, affiliate		316,454			221,914
Prepaid state taxes		417			5,344
Total current assets		329,700			304,568

Oil and gas properties at cost, full-cost method		66,147,353			66,184,314
Less accumulated depreciation, depletion, amortization
and cost ceiling write-downs		(62,473,736	)		(61,191,872	)
		3,673,617			4,992,442

Total assets	$	4,003,317		$	5,297,010

LIABILITIES AND PARTNERS’ CAPITAL

Accounts payable, affiliate	$	94,128		$	82,461
Total current liabilities		94,128			82,461

Asset retirement obligation		597,175			558,971

Partners’ capital		3,312,014			4,655,578

Total liabilities and partners’ capital	$	4,003,317		$	5,297,010

	Partners'
	Capital
Balance at December 31, 2013	$	13,913,305
Cash distributions		(3,117,425	)
Net income		2,085,247
Balance at December 31, 2014		12,881,127
Cash distributions		(2,115,597	)
Net loss		(6,109,952	)
Balance at December 31, 2015	$	4,655,578

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

~~The accompanying notes are an integral part of the financial statements.~~20

22MEWBOURNE ENERGY PARTNERS 07-A, L.P.

~~MEWBOURNE~~STATEMENTS OF ~~ENERGY PARTNERS 07-A, L.P.~~OPERATIONS

STATEMENTS OF CASH FLOWS


	For the Years Ended
	December 31,
	2016			2015
Revenues:
Oil sales	$	616,508		$	593,698
Gas sales		1,098,819			1,248,847
Total revenues		1,715,327			1,842,545

Expenses:
Lease operating expense		840,238			917,826
Production taxes		88,512			97,585
Administrative and general expense		102,410			121,407
Depreciation, depletion, and amortization		388,496			736,043
Cost ceiling write-down		866,942			6,043,458
Asset retirement obligation accretion		38,204			36,178
Total expenses		2,324,802			7,952,497

Net loss	$	(609,475	)	$	(6,109,952	)

	For the Years Ended
	December 31,
	2015			2014
Cash flows from operating activities:
Net (loss) income	$	(6,109,952	)	$	2,085,247
Adjustments to reconcile net (loss) income to net cash
provided by operating activities:
Depreciation, depletion, and amortization		736,043			844,046
Cost ceiling write-down		6,043,458			—
Asset retirement obligation accretion		36,178			34,220
Changes in operating assets and liabilities:
Accounts receivable, affiliate		302,184			309,149
Prepaid state taxes		(1,183	)		—
Accounts payable, affiliate		(42,481	)		(72,699	)
Net cash provided by operating activities		964,247			3,199,963
Cash flows from investing activities:
Proceeds from sale of oil and gas properties		1,228,456			—
Purchase and development of oil and gas properties		(58,183	)		(24,474	)
Net cash provided by (used in) investing activities		1,170,273			(24,474	)
Cash flows from financing activities:
Cash distributions to partners		(2,115,597	)		(3,117,425	)
Net cash used in financing activities		(2,115,597	)		(3,117,425	)
Net increase in cash		18,923			58,064
Cash, beginning of period		58,387			323
Cash, end of period	$	77,310		$	58,387
Supplemental Cash Flow Information:
Change to net oil & gas properties related to asset retirement
obligation liabilities	$	(11,895	)	$	—
Change to property, plant and equipment related to accrual of
leaseholds	$	122		$	—

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

~~The accompanying notes are an integral part of the financial statements.~~21

MEWBOURNE ENERGY PARTNERS 07-A, L.P.

STATEMENTS OF CHANGES IN PARTNERS’ CAPITAL
For the years ended December 31, 2016 and 2015


	Partners’
	Capital

Balance at December 31, 2014	$	12,881,127

Cash distributions		(2,115,597	)
Net loss		(6,109,952	)

Balance at December 31, 2015		4,655,578

Cash distributions		(734,089	)
Net loss		(609,475	)

Balance at December 31, 2016	$	3,312,014

~~Mewbourne~~The ~~Energy~~accompanying ~~Partners~~notes ~~07-A,~~are Lan integral part of the financial statements.P.

~~NOTES TO FINANCIAL STATEMENTS~~22

1. Description of Business

MEWBOURNE ENERGY PARTNERS 07-A, L.P.

STATEMENTS OF CASH FLOWS

	For the Years Ended
	December 31,
	2016			2015
Cash flows from operating activities:
Net loss	$	(609,475	)	$	(6,109,952	)
Adjustments to reconcile net loss to net cash provided by operating activities:
Depreciation, depletion, and amortization		388,496			736,043
Cost ceiling write-down		866,942			6,043,458
Asset retirement obligation accretion		38,204			36,178
Changes in operating assets and liabilities:
Accounts receivable, affiliate		(94,540	)		302,184
Prepaid state taxes		4,927			(1,183	)
Accounts payable, affiliate		11,667			(42,481	)
Net cash provided by operating activities		606,221			964,247

Cash flows from investing activities:
Proceeds from sale of oil and gas properties and expense reimbursement on defective pipe		64,574			1,228,456
Purchase and development of oil and gas properties		(1,187	)		(58,183	)
Net cash provided by investing activities		63,387			1,170,273

Cash flows from financing activities:
Cash distributions to partners		(734,089	)		(2,115,597	)
Net cash used in financing activities		(734,089	)		(2,115,597	)

Net (decrease) increase in cash		(64,481	)		18,923
Cash, beginning of period		77,310			58,387

Cash, end of period	$	12,829		$	77,310

Supplemental Cash Flow Information:
Change to net oil & gas properties related to asset retirement obligation liabilities	$	—		$	(11,895	)

Change to property, plant and equipment related to accrual of leaseholds	$	—		$	122

Mewbourne Energy Partners 07-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 March 1, 2007. The ~~offering~~accompanying ofnotes ~~limited and~~are ~~general~~an ~~partner~~integral ~~interests began May 1, 2007 as a~~ part of ~~a private placement pursuant to Section 4(2) of~~ the ~~Securities~~financial Act of 1933 and Regulation D promulgated thereunder, and concluded August 13, 2007, with total investor contributions of $70,000,000 originally being sold to accredited investors of which $65,710,000 were sold to accredited investors as general partner interests and $4,290,000 were sold to accredited investors as limited partner interestsstatements. ~~During 2009 all general partner equity interests were converted to limited partner equity interests. The managing general partner has no significant equity interest in the Partnership.~~

The 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.23

~~2. Summary~~Mewbourne ofEnergy ~~Significant~~Partners ~~Accounting~~07-A, ~~Policies~~L.P.

~~The~~NOTES ~~preparation~~TO ofFINANCIAL 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.STATEMENTS

~~Significant estimates inherent in the Registrant’s financial statements include the estimate of oil and gas reserves and future abandonment costs~~1. Description ~~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.~~Business

~~Full~~Mewbourne ~~Cost~~Energy ~~Accounting~~Partners 07-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 March 1, 2007. The offering of limited and general partner interests began May 1, 2007 as a part of a private placement pursuant to Section 4(2) of the Securities Act of 1933 and Regulation D promulgated thereunder, and concluded August 13, 2007, with total investor contributions of $70,000,000 originally being sold to accredited investors of which $65,710,000 were sold to accredited investors as general partner interests and $4,290,000 were sold to accredited investors as limited partner interests. During 2009 all general partner equity interests were converted to limited partner equity interests. The managing general partner has no significant equity interest in the Partnership.

The Partnership’s ~~follows~~sole ~~the~~business ~~full-cost method~~is ~~of accounting for its oil and gas activities. Under~~ the ~~full-cost~~development ~~method, all productive~~ and ~~non-productive~~production ~~costs incurred in the acquisition, exploration and development~~ of oil and gas ~~properties are capitalized~~. ~~Depreciation,~~A ~~depletion~~substantial ~~and~~portion ~~amortization~~ of ~~oil~~the ~~and~~Partnership’s gas ~~properties~~production ~~subject to amortization~~ is ~~computed~~being onsold regionally in the ~~units-of-production~~spot ~~method~~market. ~~based~~Due onto the ~~proved~~highly ~~reserves~~competitive ~~underlying the~~nature ~~oil~~of ~~and~~the ~~gas~~spot ~~properties. At December 31~~market, ~~2015~~prices ~~and~~are ~~2014 all capitalized costs were~~ subject to ~~amortization.~~seasonal ~~Proceeds~~and ~~from~~regional ~~the~~pricing ~~sale~~fluctuations. orIn ~~other~~addition, ~~disposition~~such ofspot ~~properties~~market sales are ~~credited~~generally toshort-term ~~the~~in ~~full~~nature ~~cost pool. Gains~~ and ~~losses~~ are ~~not~~dependent ~~recognized~~upon ~~unless~~obtaining ~~such adjustments~~transportation ~~would~~services ~~significantly~~provided ~~alter~~by ~~the~~pipelines. ~~relationship~~The ~~between~~prices ~~capitalized~~received ~~costs~~for ~~and~~ the ~~proved~~Partnership’s oil and gas ~~reserves. Capitalized costs~~ are subject to ainfluences ~~quarterly ceiling test that limits~~ such ~~costs~~as ~~to the aggregate of the present value of estimated future net cash~~global ~~flows~~consumption ~~of proved reserves, computed using the 12-month unweighted average of first-day-of the-month oil~~ and ~~natural~~supply ~~gas prices, discounted at 10%, and the lower of cost or fair value of unproved properties~~trends. 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 $6,043,458 for the year ended December 31, 2015. There were no cost ceiling write-downs for the year ended December 31, 2014.

242. Summary of Significant Accounting Policies

~~Cash~~The preparation of 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~~Significant ~~Partnership~~estimates ~~maintains~~inherent ~~all~~in ~~its~~the ~~cash~~Registrant’s financial statements include the estimate of oil and gas reserves and future abandonment costs. Changes in ~~one~~oil and gas prices and ~~financial~~the ~~institution~~changes in production estimates could have a significant effect on reserve estimates. AtThe ~~various~~reserve ~~times~~estimates ~~throughout~~directly impact the ~~year,~~computation ~~the~~of ~~cash~~depreciation, ~~amount~~depletion, ~~may~~and beamortization, inasset ~~excess~~retirement ofobligation, and the ~~amount~~ceiling ~~insured~~test byfor the ~~Federal~~Registrant’s ~~Deposit~~oil ~~Insurance~~and ~~Corporation~~gas properties.

~~Fair~~Full ~~Value~~Cost ~~of Financial Instruments~~Accounting

The ~~Financial~~Partnership ~~Accounting~~follows ~~Standards~~the ~~Board~~full-cost ~~(“FASB”)~~method ~~has~~of ~~issued~~accounting ~~guidance~~for onits ~~determining~~oil ~~the~~and ~~estimated~~gas ~~fair~~activities. ~~value~~Under ~~for~~the ~~financial~~full-cost ~~instruments.~~method, ~~This~~all ~~disclosure~~productive ~~states~~and ~~that~~non-productive ~~the~~costs ~~fair~~incurred ~~value~~in the acquisition, exploration and development of ~~financial~~oil ~~instruments~~and isgas ~~determined~~properties atare ~~discrete~~capitalized. ~~points~~Depreciation, indepletion ~~time~~and amortization of oil and gas properties subject to amortization is computed on the units-of-production method based on ~~relevant~~the ~~market~~proved ~~information~~reserves underlying the oil and gas properties. ~~Such~~At ~~estimates~~December ~~involve~~31, 2016 and 2015 all capitalized costs were subject to amortization. Proceeds from the ~~uncertainties~~sale or other disposition of properties are credited to the full cost pool. Gains and ~~cannot~~losses beare ~~determined~~not ~~with~~recognized ~~precision~~unless such adjustments would significantly alter the relationship between capitalized costs and the proved oil and gas reserves. ~~The~~ ~~estimated~~Capitalized ~~fair~~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, ~~accounts~~computed ~~receivable~~using the 12-month unweighted average of first-day-of the-month oil and ~~accounts~~gas prices, discounted at ~~payable~~10%, ~~approximates~~and ~~their~~the ~~carrying~~lower of cost or fair value ~~due~~of unproved properties. If unamortized costs capitalized exceed the ceiling, the excess is charged to ~~their~~expense ~~short~~in the period the excess occurs. There were cost ceiling write-~~term~~downs ~~nature~~totaling $866,942 and $6,043,458 for the years ended December 31, 2016 and 2015, respectively.

~~Asset Retirement Obligations~~ 24

~~The~~Subsequent 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.Events

The Partnership ~~estimates~~has aevaluated ~~liability~~events ~~for plugging~~ and ~~abandonment costs based on historical experience and estimated well life. The liability is discounted using the credit-adjusted~~ ~~risk-free~~transactions ~~rate.~~for ~~Revisions~~potential torecognition ~~the liability could occur due to changes in well plugging and abandonment costs~~ or ~~well~~disclosure ~~useful~~through ~~lives, or if federal or state regulators enact new well restoration requirements. The Partnership recognizes accretion expense in connection with~~ the ~~discounted~~date ~~liability over~~ the ~~remaining~~financial ~~life~~statements ofwere ~~the well~~issued.

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

	2015			2014
Balance, beginning of period	$	534,688		$	500,468
Liabilities incurred		665			—
Liabilities reduced due to sales of property		(12,560	)		—
Accretion expense		36,178			34,220
Balance, end of period	$	558,971		$	534,688

25Cash

~~Oil~~The ~~and~~Partnership ~~Gas~~maintains ~~Sales~~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.

~~The~~Fair ~~Partnership’s~~Value 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~~Financial 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, 2015 and 2014, no material gas imbalances between the Partnership and other working interest owners existed.Instruments

~~Substantially~~The ~~all~~FASB has ofissued ~~the~~guidance ~~Partnership’s accounts~~on ~~receivable~~determining ~~result~~the ~~from~~estimated ~~oil~~fair ~~and~~value ~~natural~~for ~~gas~~financial ~~sales~~instruments. toThis ~~third~~disclosure ~~parties~~states inthat the ~~oil~~fair ~~and natural gas industry. This concentration~~value of ~~customers~~financial ~~may~~instruments ~~impact~~is ~~the~~determined ~~Partnership’s~~at ~~overall~~discrete ~~credit~~points ~~risk~~ in ~~that~~time ~~these~~based ~~entities~~on ~~may~~relevant bemarket ~~similarly~~information. ~~affected~~Such byestimates ~~changes~~involve inuncertainties ~~economic~~ and ~~other~~cannot ~~conditions.~~be ~~Historically,~~determined ~~the~~with ~~Partnership~~precision. ~~has~~The ~~not~~estimated ~~experienced~~fair ~~significant~~value ~~credit~~of ~~losses~~cash, onaccounts ~~such~~receivable, ~~receivables.~~affiliate Noand ~~bad~~accounts ~~debt~~payable, ~~expense~~affiliate ~~was~~approximates ~~recorded~~their incarrying value ~~2015~~due orto ~~2014.~~their ~~The~~short-term ~~Partnership cannot ensure that such losses will not be realized in the future~~nature.

~~Comprehensive~~Asset ~~Income~~Retirement Obligations

~~Comprehensive~~The ~~income~~Partnership ishas ~~defined~~recognized asan ~~a change~~estimated inliability ~~equity~~for offuture aplugging ~~business~~and ~~enterprise~~abandonment ~~during~~costs. aA ~~period~~liability ~~from~~for ~~transactions~~the ~~and~~estimated ~~other~~fair ~~events~~value ~~and~~of ~~circumstances~~the ~~from~~future ~~non-partner~~plugging ~~sources~~ and ~~includes~~abandonment costs ~~all~~is ~~changes~~recorded inwith ~~equity~~a ~~during~~corresponding aincrease ~~period~~in ~~except~~the ~~those~~full ~~resulting~~cost ~~from~~pool ~~investments~~at bythe ~~partners~~time ~~and~~a ~~distributions~~new towell ~~partners~~is drilled. ~~The~~ ~~Partnership~~Depreciation ~~has~~expense noassociated with ~~items~~estimated ofplugging ~~comprehensive~~and ~~income,~~abandonment ~~other~~costs ~~than~~is ~~net~~recognized ~~income,~~ in ~~any~~accordance ~~period~~with ~~presented. Therefore, net income as presented in~~ the ~~statements~~full ofcost ~~operations equals comprehensive income~~methodology.

~~Income~~The ~~Taxes~~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 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 $4,861,256 and $12,620,880 at December 31, 2015 and 2014, respectively. 25

~~The~~A ~~Partnership~~reconciliation ~~accounts~~of ~~for uncertainty in income taxes in accordance with applicable accounting guidance and recognizes~~ the ~~effects~~Partnership’s ofliability ~~those~~for ~~positions only if they are more~~well ~~likely~~plugging ~~than~~and ~~not~~abandonment ofcosts ~~being~~for ~~sustained.~~the Asyears noended ~~liability~~December ~~had~~31, ~~been~~2016 ~~recognized~~and ~~as of~~ December 31, 2015 oris ~~2014,~~as ~~the Partnership did not accrue for any interest or penalties.~~follows:

3. Organization and Related Party Transactions:

	2016		2015
Balance, beginning of period	$	558,971	$	534,688
Liabilities incurred		—		665
Liabilities reduced due to sales of property		—		(12,560	)
Accretion expense		38,204		36,178
Balance, end of period	$	597,175	$	558,971

The Partnership was organized on March 1, 2007 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~~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.~~Sales

26The 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.

InSubstantially ~~the~~all ~~ordinary 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~~’s ~~their~~accounts ~~portion~~receivable ofresult ~~these~~from ~~costs~~oil ~~based~~and ~~upon~~gas ~~their~~sales ~~ownership in each well incurring the costs. These costs are referred~~ to asthird ~~operator charges~~parties ~~and are standard and customary~~ in the oil and gas industry. ~~Operator~~This ~~charges~~concentration ~~include recovery~~ of ~~gas marketing costs, fixed~~customers ~~rate~~may ~~overhead,~~impact ~~supervision,~~the ~~pumping,~~Partnership’s ~~and~~overall ~~equipment~~credit ~~furnished~~risk byin ~~the~~that ~~operator,~~these ~~some~~entities ofmay ~~which will~~ be ~~included~~similarly inaffected ~~the~~by ~~full~~changes ~~cost~~in ~~pool~~economic ~~pursuant~~and toother ~~Rule 4-10(c)(2) of Regulation S-X~~conditions. ~~Amounts~~Historically, ~~accrued~~the ~~for~~Partnership ~~and~~has ~~paid~~not toexperienced ~~MOC~~significant ~~for~~credit ~~operator~~losses ~~charges~~on ~~totaled~~such ~~$575,837~~receivables. ~~and~~No ~~$556,777~~bad debt ~~for~~expense ~~the~~was ~~years~~recorded ~~ended~~in ~~December~~2016 ~~31,~~or 2015. ~~and~~The ~~2014,~~Partnership ~~respectively.~~cannot ~~Operator~~ensure ~~charges~~that ~~are~~such ~~billed~~losses inwill ~~accordance~~not ~~with~~be ~~the~~realized ~~Program and~~in ~~Partnership~~the ~~Agreements~~future.

InComprehensive 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 natural 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, $80,704 and $168,634 were allocated to the Partnership during the years ended December 31, 2015 and 2014, respectively.Income

~~The~~Comprehensive ~~Partnership~~income ~~participates~~is indefined ~~oil~~as ~~and~~a ~~gas~~change ~~activities~~in ~~through~~equity of a ~~Drilling~~business ~~Program~~enterprise ~~Agreement~~during ~~(the~~a ~~“Program”).~~period ~~The~~from ~~Partnership~~transactions and MDother ~~are~~events ~~parties~~and tocircumstances ~~the~~from ~~Program~~non-partner sources ~~Agreement.~~and ~~The~~includes ~~costs~~all ~~and~~changes ~~revenues~~in ofequity ~~the~~during ~~Program~~a ~~are~~period ~~allocated~~except tothose MDresulting from investments by partners and ~~the~~distributions to partners. The Partnership has no items of comprehensive income, other than net income, in any period presented. Therefore, net income as presented ~~follows:~~in the statements of operations equals comprehensive income.

	Partnership			MD (1)
Revenues:
Proceeds from disposition of depreciable and depletable properties		70	%		30	%
All other revenues		70	%		30	%
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		70	%		30	%

Income Taxes

~~(1)~~The AsPartnership ~~noted~~is ~~above,~~treated ~~pursuant~~as toa ~~the~~partnership for ~~Program,~~income MDtax ~~must~~purposes ~~contribute~~and, ~~100%~~as ofa ~~organization~~result, ~~and~~income ~~offering~~of ~~costs~~the ~~and~~Partnership ~~lease~~is ~~acquisition~~reported ~~costs~~on ~~which~~the ~~should~~tax ~~approximate~~returns ~~20%~~ of ~~total capital costs. To~~ the ~~extent~~partners ~~that organization~~ and ~~offering~~no ~~costs~~recognition is ~~and~~given ~~lease~~to ~~acquisition~~income ~~costs~~taxes ~~are~~in ~~less~~the ~~than~~financial ~~20%~~statements. ofThe ~~total~~Partnership’s ~~capital~~financial ~~costs,~~reporting MDbasis isof ~~responsible for tangible drilling costs until~~ its ~~share~~net ofassets exceeded the ~~Program’s~~tax ~~total~~basis ~~capital~~of ~~costs~~its ~~reaches~~net ~~approximately~~assets ~~20%.~~by ~~The~~$3,596,924 ~~Partnership’s~~and ~~financial~~$4,861,256 ~~statements~~at ~~reflect~~December ~~its~~31, ~~respective~~2016 ~~proportionate~~and ~~interest~~2015, ~~in the Program~~respectively.

27The 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.

~~MEWBOURNE ENERGY PARTNERS 07-A, L.P.~~ 26

~~INDEX~~3. Organization TOand Related ~~EXHIBITS~~Party Transactions:

The ~~following~~Partnership ~~documents~~was ~~are~~organized ~~incorporated~~on ~~by reference~~March 1, 2007 in ~~response~~accordance towith ~~Item~~the 15laws 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)3 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.

EXHIBIT
NUMBER		DESCRIPTION
3.1		Form of Certificate of Limited Partnership (filed as Exhibit 3.1 to Form 10 and incorporated herein by reference)
3.2		Form of Certificate of Amendment of the Certificate of Limited Partnership (filed as Exhibit 3.2 to Form 10 and incorporated herein by reference)
4.1		Form of Agreement of Partnership (filed as Exhibit 4.1 to Form 10 and incorporated herein by reference)
10.1		Form of Drilling Program Agreement (filed as Exhibit 10.1 to Form 10 and incorporated herein by reference)
10.2		Form of Operating Agreement (filed as Exhibit 10.2 to Form 10 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.

In the ordinary 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-X. Amounts accrued for and paid to MOC for operator charges totaled $507,553 and $575,837 for the years ended December 31, 2016 and 2015, respectively. Operator charges are billed in accordance with the Program and Partnership Agreements.

28In 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, $55,610 and $80,704 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		70	%		30	%
All other revenues		70	%		30	%
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		70	%		30	%

(1)

As noted above, pursuant to the Program, MD must contribute 100% of organization and offering costs and lease acquisition costs which should approximate 20% of total capital costs. To the extent that organization and offering costs and lease acquisition costs are less than 20% of total capital costs, MD is responsible for tangible drilling costs until its share of the Program’s total capital costs reaches approximately 20%. The Partnership’s financial statements reflect its respective proportionate interest in the Program.

MEWBOURNE ENERGY PARTNERS 07-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 Form 10 and incorporated herein by reference)

3.2		Form of Certificate of Amendment of the Certificate of Limited Partnership (filed as Exhibit 3.2 to Form 10 and incorporated herein by reference)

4.1		Form of Agreement of Partnership (filed as Exhibit 4.1 to Form 10 and incorporated herein by reference)

10.1		Form of Drilling Program Agreement (filed as Exhibit 10.1 to Form 10 and incorporated herein by reference)

10.2		Form of Operating Agreement (filed as Exhibit 10.2 to Form 10 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 07-A, L.P.