##### Table of Contents





UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

WASHINGTON, D.C. 20549





FORM 10-K







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

For the year ended December 31, 2008

Or



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

For the transition period from              to

Commission File No. 333-131978-01





MEWBOURNE ENERGY PARTNERS
07-A, L.P.







|                                                        |  |                                       
|------------------------------------------------------- |  | --------------------------------------
|Delaware                                                |  | 20-8481823                            
|(State or jurisdiction ofincorporation or organization) |  | (I.R.S. EmployerIdentification Number)



|                                         |  |           
|---------------------------------------- |  | ----------
|3901 South Broadway, Tyler, Texas        |  | 75701     
|(Address of principal executive offices) |  | (Zip code)

Registrants Telephone Number, including area code: (903) 561-2900





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

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

Limited Partner Interests

(Title of class)

General Partner
Interests

(Title of class)





Indicate by check mark if the registrant is a
well-known seasoned issuer, as defined in Rule 405 of the Securities Act.    Yes   ̈    No  x

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  x

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  x    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.    x

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 |  | x

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

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.









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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                                                                     |  | 6 
|                                             |  |          | 
|                                             |  | Item 4.  |  | Submission of Matters to a Vote of Security Holders                                   |  | 6 
|                                             |  |         
|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. |  | Quantitive and Qualitative Disclosures about Market Risk                              |  | 13
|                                             |  |          | 
|                                             |  | Item 8.  |  | Financial Statements and Supplementary Data                                           |  | 13
|                                             |  |          | 
|                                             |  | Item 9.  |  | Changes in and Disagreements with Accountants on Accounting and Financial Disclosure  |  | 14
|                                             |  |          | 
|                                             |  | Item 9A. |  | Controls and Procedures                                                               |  | 14
|                                             |  |         
|Part III                                     |  |          |  | 15                                                                                   
|                                             |  |          | 
|                                             |  | Item 10. |  | Directors and Executive Officers of the Registrant                                    |  | 15
|                                             |  |          | 
|                                             |  | Item 11. |  | Executive Compensation                                                                |  | 16
|                                             |  |          | 
|                                             |  | Item 12. |  | Security Ownership of Certain Beneficial Owners and Management                        |  | 17
|                                             |  |          | 
|                                             |  | Item 13. |  | Certain Relationships and Related Transactions                                        |  | 17
|                                             |  |          | 
|                                             |  | Item 14. |  | Principal Accountant Fees and Services                                                |  | 17
|                                             |  |         
|Part IV                                      |  |          |  | 18                                                                                   
|                                             |  |          | 
|                                             |  | Item 15. |  | Exhibits, Financial Statements, Financial Statement Schedules and Reports on Form 8K  |  | 18
|                                             | 
|SIGNATURES                                   |  | 19      
|                                             | 
|INDEX TO EXHIBITS                            |  | 33      
|                                             | 
|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 |  |         



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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.

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
selected financial data in Item 6 and 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 will be sold to local distribution companies, 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 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 31, 2009, MOC employed 208
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.



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|ITEM 1A. | Risk Factors
|-------- | ------------

Oil and natural gas prices are volatile. A
decline in prices 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. In addition, cost ceiling write-downs may be necessary in the future if prices fall
significantly.

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 and capacity of natural gas pipelines and other transportation facilities;
| | - |  | ----------------------------------------------------------------------------------------



| |  |  | the price and level of foreign imports;
| | - |  | ---------------------------------------



| |  |  | domestic and foreign governmental regulations and taxes;
| | - |  | --------------------------------------------------------



| |  |  | the ability of the members of the Organization of Petroleum Exporting Countries to agree to and maintain oil price and production controls;
| | - |  | -------------------------------------------------------------------------------------------------------------------------------------------



| |  |  | political instability or armed conflict in oil-producing regions; and
| | - |  | ---------------------------------------------------------------------



| |  |  | overall domestic and global economic conditions.
| | - |  | ------------------------------------------------

These factors and the volatility of the energy markets make it extremely difficult to predict future oil and natural gas price movements with any certainty. Declines in oil and natural gas prices would not only reduce revenue, but could
reduce the amount of oil and natural gas that can be produced economically and, as a result, could have a material adverse effect on the Registrants financial condition, results of operations and reserves. Further, oil and natural gas prices
do not necessarily move in tandem. Because approximately 83% of the Registrants reserves at December 31, 2008 were natural gas reserves, the Registrant is more affected by movements in natural gas prices.

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

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



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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.

Future price declines
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 prices for oil and natural gas at that date. A significant decline in oil and natural gas prices from current levels, or 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 for the year ended December 31, 2008 indicated an impairment of oil and natural gas properties of approximately $18 million.

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.
| | - |  | ----------------------------------------------------------------



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

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



|ITEM 1B. | Unresolved Staff Comments
|-------- | -------------------------

None.



|ITEM 2. | Properties
|------- | ----------

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, 2008, the Registrant owned working interests in 113 producing wells. The
Registrant participated in the drilling of wells for the year ending December 31, 2008 and the period from March 1, 2007 (date of inception) through December 31, 2007 as shown in the following table:



|                          |  |       |  |        |  |       |  |      
|------------------------- |  | ----- |  | ------ |  | ----- |  | -----
|                          |  | 2008  |  | 2007  
|                          |  | Gross |  | Net    |  | Gross |  | Net  
|Development Wells         |  |       |  |        |  |       |  |      
|                          |  |       |  |       
|Oil and natural gas wells |  | 87    |  | 18.389 |  | 26    |  | 5.306
|                          |  |       |  |       
|Non-productive wells      |  |      |  |       |  | 2     |  | 0.470

Reserve estimates were prepared by Forrest A Garb & Associates, Inc., the Registrants independent
petroleum consultants, in accordance with guidelines established by the Securities and Exchange Commission.



|ITEM 3. | Legal Proceedings
|------- | -----------------

The Registrant is not aware of any pending legal
proceedings to which it is a party.



|ITEM 4. | Submission of Matters to a Vote of Security Holders
|------- | ---------------------------------------------------

No matter was
submitted to a vote of security holders during the period ended December 31, 2008 covered by this report.



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PART II



|ITEM 5. | Market for Registrants Common Equity and Related Stockholder Matters
|------- | ---------------------------------------------------------------------

At March 31, 2009, the Registrant had 14,000 outstanding limited and general partnership interests held of record by 1,778 subscribers. There is no established public or organized trading market for the limited and general partner
interests.

Revenues which, in the sole judgment of 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. Distributions made to limited and general partners during the year ended December 31, 2008 were $21,125,000. No distributions were
made to limited and general partners the period from March 1, 2007 (date of inception) through December 31, 2007.



|ITEM 6. | Selected Financial Data
|------- | -----------------------

The following table sets forth selected
financial data for the year ended December 31, 2008 and the period from March 1, 2007 (date of inception) through December 31, 2007:



|                                                                       |  |      |            |      |   |           
|---------------------------------------------------------------------- |  | ---- | ---------- | ---- | - | ----------
|Operating results                                                      |  | 2008 |            | 2007
|Oil and gas sales                                                      |  | $    | 28,978,643 |      | $ | 1,715,231 
|Net income                                                             |  | $    | 88,495     |      | $ | 2,220,241 
|Basic and diluted net income per partner interest (14,000 outstanding) |  | $    | 6.32       |      | $ | 158.59    
|                                                                       |  |      |            |      |   |           
|At year-end:                                                           |  |      |            |      |   |           
|Total Assets                                                           |  | $    | 45,658,724 |      | $ | 67,317,913
|                                                                       |  |      |            |      |   |           
|Cash distributions per partner interest (14,000 outstanding)           |  | $    | 1,508.93   |      | $ |          
|                                                                       |  |      |            |      |   |           



|ITEM 7. | Managements Discussion and Analysis of Financial Condition and Results of Operations
|------- | -------------------------------------------------------------------------------------

General

The Registrant was organized as a Delaware limited partnership on March 1, 2007. The offering of limited and
general partnership interests began May 1, 2007 as a part of an offering registered under the name Mewbourne Energy Partners 07 Drilling Program. The offering of limited and general partner interests in the Registrant concluded August 13,
2007, with total investor partner contributions of $70,000,000.

The Registrant was formed to engage primarily in the business of drilling development
wells, to produce and market crude oil and natural 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.



7



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Results of Operations

Year ended December 31, 2008 compared to the period from March 1, 2007 (date of inception) through December 31, 2007:



|                  |  |      |            |      |   |          
|----------------- |  | ---- | ---------- | ---- | - | ---------
|                  |  | 2008 |            | 2007
|Oil sales         |  | $    | 8,125,298  |      | $ | 356,652  
|                  |  |     
|Barrels produced  |  |      | 85,779     |      |   | 3,962    
|                  |  |     
|Average price/bbl |  | $    | 94.72      |      | $ | 90.02    
|                  |  |     
|Gas sales         |  | $    | 20,853,345 |      | $ | 1,358,579
|                  |  |     
|Mcf produced      |  |      | 2,561,709  |      |   | 188,534  
|                  |  |     
|Average price/mcf |  | $    | 8.14       |      | $ | 7.21     

Oil and gas revenues. As shown in the table above, total oil and gas sales rose by $27,263,412, a 1589.5%
increase, for the year ended December 31, 2008 as compared to the period from March 1, 2007 (date of inception) through December 31, 2007.

Of this increase, $7,750,003 and $19,318,602 were due to increases in the volumes of oil and gas sold, respectively. The volumes sold increased by 81,817 bbls and 2,373,175 mcf for the year ended December 31, 2008 as compared to the
period from March 1, 2007 (date of inception) through December 31, 2007 due to the greater number of wells in operation in 2008.

Also included
in this increase were $18,643 and $176,164 from increases in the average prices of oil and gas sold, respectively. Average prices rose to $94.72 from $90.02 per bbl and to $8.14 from $7.21 per mcf for the year ended December 31, 2008 as
compared to the period from March 1, 2007 (date of inception) through December 31, 2007.

Interest income. Interest income decreased to $629,007
for the year ended December 31, 2008 from $1,245,753 for the period from March 1, 2007 (date of inception) through December 31, 2007 as cash was utilized for the drilling and equipping of wells.

Lease operations. Lease operating expense for the year ended December 31, 2008 increased to $1,164,885 from $37,681 for the period from March 1, 2007 (date of
inception) through December 31, 2007 due to more wells being operated in 2008.

Production taxes. Production taxes during the year ended
December 31, 2008 increased to $1,673,527 from $119,158 for the period from March 1, 2007 (date of inception) through December 31, 2007 due to increased revenue.

Administrative and general expenses. Administrative and general expenses increased to $478,899 in 2008 from $4,833 for the period from March 1, 2007 (date of inception) through December 31, 2007 due to
increased administrative expenses allocable to the Partnership and greater legal and reporting costs.

Depreciation, depletion and amortization.
Depreciation, depletion and amortization rose to $7,864,277 for the year ended December 31, 2008 from $578,512 for the period from March 1, 2007 (date of inception) through December 31, 2007 due to production increases.

Cost ceiling write-down. There were cost ceiling write-downs totaling $18,323,915 at September 30, 2008 and December 31, 2008 due to lower oil and gas prices
on those dates. There were no write-downs during 2007.

Liquidity and capital resources

Cash decreased by $38,998,910 during the year ended December 31, 2008. Cash was utilized primarily for drilling and completion costs and 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 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.



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Critical Accounting Policies

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.

Significant 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 Registrant follows the full-cost method of accounting for its oil and gas activities.
Under the full-cost method, all productive and non-productive costs incurred in the acquisition, exploration and development of oil and gas properties are capitalized. Depreciation, depletion and amortization of oil and gas properties subject to
amortization is computed on the units-of-production method based on the proved reserves underlying the oil and gas properties. Oil and gas properties are subject to a quarterly ceiling test that limits such costs to the aggregate of the present
value of future net cash flows of proved reserves and the lower of cost or fair value of unproved properties. The present value of future net cash flows has been prepared assuming year-end selling prices, year-end development and production costs
and a 10 percent annual discount rate.

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

New Accounting Pronouncements

Modernization of Oil and Gas Reporting
- In January 2009, the Securities and Exchange Commission issued revisions to the oil and gas reporting disclosures, Modernization of Oil and Gas Reporting; Final Rule (the Final Rule). In addition to changing the definition
and disclosure requirements for oil and gas reserves, the Final Rule changes the requirements for determining quantities of oil and gas reserves. The Final Rule also changes certain accounting requirements under the full cost method of accounting
for oil and gas activities. The amendments are designed to modernize the requirements for the determination of oil and gas reserves, aligning them with current practices and updating them for changes in technology. The Final Rule is effective for
annual reports on Form10-K for fiscal years ending on or after December 31, 2009. The Partnership has not yet determined the impact, if any, on the financial statements.

The Hierarchy of Generally Accepted Accounting Principles -In May 2008, the FASB issued SFAS No. 162, The Hierarchy of Generally Accepted Accounting Principles (SFAS 162).
SFAS No.162 identifies the sources for accounting principles and the framework for selecting the principles to be used in preparing financial statements of nongovernmental entities that are presented in conformity with generally accepted accounting
principles in the United States. This Statement became effective in November 2008.



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Fair Value Measurements -In September 2006, the FASB issued SFAS No. 157, which defines fair value,
establishes a framework for measuring fair value, and expands disclosures about fair value measurements. Effective January 1, 2008, the Partnership adopted SFAS No. 157, which applies to other accounting pronouncements that require or
permit fair value measurements; however, it does not require any new fair value measurements.

SFAS No. 157 establishes a valuation hierarchy for
disclosure of the inputs to valuation used to measure fair value. This hierarchy prioritizes the inputs into three broad levels. Level 1 inputs are quoted prices (unadjusted) in active markets for identical assets or liabilities. All of the
Partnerships cash equivalents fall into Level 1 and consist of short-term, highly liquid investments, which have maturities of 90 days or less, including sweep investments and money market funds. The Partnership does not have any assets
or liabilities falling under Level 2 or 3.

Disclosures about Derivative Instruments and Hedging Activities - In March 2008, the Financial
Accounting Standards Board (FASB) issued Statements of Financial Accounting Standards (SFAS) SFAS No. 161, Disclosures about Derivative Instruments and Hedging Activities (SFAS No. 161). SFAS
No. 161 requires entities that utilize derivative instruments to provide qualitative disclosures about their objectives and strategies for using such instruments, as well as any details of credit-risk-related contingent features contained
within derivatives. The Partnership does not utilize derivative instruments; therefore, the Partnership does not expect this pronouncement to have any impact on the Partnerships results of operations, cash flows or financial position.

Non-controlling Interests in Consolidated Financial Statements - In December 2007, the FASB issued SFAS No. 160, Noncontrolling
Interests in Consolidated Financial Statements, an amendment of Accounting Research Bulletin No. 51 (SFAS No. 160), which improves the relevance, comparability and transparency of the financial information that a
reporting entity provides in its consolidated financial statements by establishing accounting and reporting standards for the noncontrolling interest in a subsidiary and for the deconsolidation of a subsidiary. The Partnership does not own any
subsidiaries and does not expect this pronouncement to have any impact on the Partnerships results of operations, cash flows or financial position.

Business Combinations - In December 2007, FASB issued SFAS No. 141 (revised 2007), Business Combinations (SFAS No. 141R), which replaces SFAS No. 141, Business Combinations
(SFAS No. 141). SFAS 141R retains the fundamental requirements in SFAS No. 141 that the acquisition method of accounting (which SFAS No. 141 called the purchase method) be used for all business combinations. The
Partnership has no business combinations in progress or, at this time, in future plans. The Partnership does not expect this pronouncement to have any impact on the Partnerships results of operations, cash flows or financial position.



10



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##### Table of Contents

Accounting Standard Fair Value for Financial Assets and Financial Liabilities- In February 2007, the FASB
issued SFAS No. 159, The Fair Value Option for Financial Assets and Financial Liabilities (SFAS No. 159). SFAS No. 159 allows entities the option to measure eligible financial instruments at fair value as
of specified dates. The Partnership did not elect fair value as an alternative as provided under SFAS No. 159 for any of its financial assets and liabilities that are not currently measured at fair value.

Asset Retirement Obligations

In accordance with Statement of Financial
Accounting Standard No. 143 (FAS 143), Accounting for Asset Retirement Obligations, the Partnership has recognized an estimated liability for future plugging and abandonment costs. This statement affects the financial
accounting and reporting obligations associated with the retirement and disposal of long-lived assets, including the Partnerships oil and gas properties, and the associated asset retirement costs.

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

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

A reconciliation of the Partnerships liability for well plugging and abandonment costs for the year ended
December 31, 2008 and the period beginning March 1, 2007 (date of inception) through December 31, 2007 is as follows:



|                             |  |      |         |   |      |   |       
|---------------------------- |  | ---- | ------- | - | ---- | - | ------
|                             |  | 2008 |         |   | 2007
|Balance, beginning of period |  | $    | 56,158  |   |      | $ |      
|                             |  |     
|Liabilities incurred         |  |      | 283,966 |   |      |   | 55,599
|                             |  |     
|Liabilities reduced          |  |      | (1,629  | ) |      |   |      
|                             |  |     
|Accretion expense            |  |      | 13,652  |   |      |   | 559   
|                             |  |      |         |   |      |   |       
|                             |  |     
|Balance, end of period       |  | $    | 352,147 |   |      | $ | 56,158
|                             |  |      |         |   |      |   |       



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Organization and Related Party Transactions

The Partnership was organized on March 1, 2007 in accordance 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. Mewbourne Oil Company (MOC) is operator of oil and gas properties owned by the Partnership. Mewbourne Holdings, Inc. is the parent of both MD and MOC. Substantially all transactions are with MD and MOC.

In the ordinary course of business, MOC will incur certain costs that will be passed on to well owners of the well 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. Reimbursement to MOC for operator charges totaled $2,498,108 for the year ended December 31, 2008 and $345,936 for the period
beginning March 1, 2007 (date of inception) through December 31, 2007. Operator charges are billed in accordance with the Program and Partnership Agreements.

In consideration for services rendered by MD in managing the business of the Partnership, the Partnership during each of the initial three years of the Partnership pays to MD a management fee in the amount equal to
7/10s of 1% of the subscriptions by the investor partners to the Partnership. Management fees can only be paid out of funds available for distributions. Under this arrangement, management fees of $490,000 were allocated to the Partnership for
the year ended December 31, 2008. Since there were not sufficient funds available for distribution, management fees were not allocated to the Partnership for the period beginning March 1, 2007 (date of inception) through December 31,
2007. The Partnership includes the management fee as part of the full cost pool pursuant to Rule 4-10(c)(2) of Regulation S-X.

In general, 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, $406,166 and $1,195 were allocated to the Partnership during the year ended December 31, 2008 and the period from March 1, 2007 (date of inception) through December 31, 2007,
respectively.

The Partnership participates in oil and gas activities through a Drilling Program Agreement (the Program). The Drilling Program
Agreement provides that MOC, in its capacity as manager of the Program, will have the exclusive power and authority to act on behalf of the Partnership with respect to the management, control and administration of the business and affairs of the
Program and the oil and gas properties subject to the Drilling Program Agreement. The Drilling Program Agreement sets out the rights, duties, and obligations of the program manager and the other participants in 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  |  
|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.
|--- | ------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------



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##### Table of Contents

|ITEM 7A. | Quantitative and Qualitative Disclosures about Market Risk
|-------- | ----------------------------------------------------------

Interest Rate Risk

The Partnership Agreement allows borrowings from banks or other financial sources of up to 20% of the total capital
contributions to the Partnership without investor approval. Should the Partnership elect to borrow monies for additional development activity on Partnership properties, it will be subject to the interest rate risk inherent in borrowing activities.
Changes in interest rates could significantly affect the Partnerships results of operations and the amount of net cash flow available for partner distributions. Also, to the extent that changes in interest rates affect general economic
conditions, the Partnership will be affected by such changes.

Commodity Price Risk

The Partnership does not expect to engage in commodity futures trading or hedging activities or enter into derivative financial instrument transactions for trading or other speculative purposes. The Partnership
currently expects to sell a significant amount of its production from successful oil and gas wells on a month-to-month basis at market prices. Accordingly, the Partnership is at risk for the volatility in commodity prices inherent in the oil and gas
industry, and the level of commodity prices will have a significant impact on the Partnerships results of operations. For the year ended December 31, 2008, a 10% change in the price received for natural gas production would have had an
approximate $2,085,000 impact on revenue.

Exchange Rate Risk

The Partnership currently has no income from foreign sources or operations in foreign countries that would subject it to currency exchange rate risk. The Partnership does not currently expect to purchase any prospects located outside of
either the United States or United States coastal waters in the Gulf of Mexico.



|ITEM 8. | Financial Statements and Supplementary Data
|------- | -------------------------------------------

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.



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##### Table of Contents

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

None.



|ITEM 9A. | Controls and Procedures
|-------- | -----------------------

(a) Evaluation of Disclosure Controls and
Procedures

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.

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

MDs management is responsible for establishing and maintaining adequate internal control over financial reporting, as such term is defined in Exchange Act Rules
13a-15(f). Under the supervision and with the participation of MDs management, including MDs principal executive officer and principal financial officer, MD conducted an evaluation of the effectiveness of the Partnerships internal
control over financial reporting based on the framework in Internal Control  Integrated Framework issued by the Committee of Sponsoring Organizations of the Treadway Commission. Based on MDs evaluation under the framework in Internal
Control  Integrated Framework, MDs management concluded that internal control over financial reporting was effective as of December 31, 2008. This annual report does not include an attestation report of the Registrants
registered public accounting firm regarding internal control over financial reporting. Managements report was not subject to attestation by the Registrants registered public accounting firm pursuant to temporary rules of the Securities
and Exchange Commission that permit the Registrant to provide only managements report in this annual report. There have been no changes in MDs internal controls for the quarter ended December 31, 2008 or in other factors which have
materially affected, or are reasonably likely to materially affect the internal controls over financial reporting.



14



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##### Table of Contents

PART III



|ITEM 10. | Directors and Executive Officers of the Registrant
|-------- | --------------------------------------------------

The Registrant
does not have any officers or directors. Under 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.

Set forth below are the names, ages and positions of the directors and executive
officers of MD, the 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.



|                    |  |                           |  |                                                     
|------------------- |  | ------------------------- |  | ----------------------------------------------------
|Name                |  | Age as ofDecember 31,2008 |  | Position                                            
|Curtis W. Mewbourne |  | 73                        |  | President and Director                              
|                    |  |                          
|J. Roe Buckley      |  | 46                        |  | Executive Vice President and Chief Financial Officer
|                    |  |                          
|Alan Clark          |  | 56                        |  | Treasurer and Controller                            
|                    |  |                          
|Michael F. Shepard  |  | 62                        |  | Secretary and General Counsel                       
|                    |  |                          
|Dorothy M. Cuenod   |  | 48                        |  | Assistant Secretary and Director                    
|                    |  |                          
|Ruth M. Buckley     |  | 47                        |  | Assistant Secretary and Director                    
|                    |  |                          
|Julie M. Greene     |  | 45                        |  | Assistant Secretary and Director                    

Curtis W. Mewbourne, age 73, formed Mewbourne Holdings, Inc. in 1965 and serves as Chairman
of the Board and President of Mewbourne Holdings, Inc., MD and MOC. He has operated as an independent oil and gas producer for the past 43 years. Mr. Mewbourne received a Bachelor of Science Degree in Petroleum Engineering from the University
of Oklahoma in 1957. Mr. Mewbourne is the father of Dorothy M. Cuenod, Ruth M. Buckley, and Julie M. Greene and the father-in-law of J. Roe Buckley.

J. Roe Buckley, age 46, joined Mewbourne Holdings, Inc. in July, 1990 and serves as Executive Vice President and Chief Financial Officer of both 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 the son-in-law of Curtis W. Mewbourne and is married to Ruth M. Buckley. He is also the brother-in-law
of Dorothy M. Cuenod and Julie M. Greene.



15



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##### Table of Contents

Alan Clark, age 56, 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.

Michael F.
Shepard, age 62, joined MOC in 1986 and serves as Secretary and General Counsel of MD. He has practiced law exclusively in the oil and gas industry since 1979 and formerly was counsel with Parker Drilling Company and its Perry Gas subsidiary for
seven years. Mr. Shepard holds the Juris Doctor degree from the University of Tulsa where he received the National Energy Law and Policy Institute award as the outstanding graduate in the Energy Law curriculum. He received a B.A. degree, magna
cum laude, from the University of Massachusetts in 1976. Mr. Shepard is a member of the bar in Texas and Oklahoma.

Dorothy M.
Cuenod, age 48 received a B.A. degree in Art History from The University of Texas and a Masters of Business Administration Degree from Southern Methodist University. Since 1984 she has served as a Director and Assistant Secretary of both MD and
MOC. Ms. Cuenod is the daughter of Curtis W. Mewbourne and is the sister of Ruth M. Buckley and Julie M. Greene. She is also the sister-in-law of J. Roe Buckley.

Ruth M. Buckley, age 47, received a Bachelor of Science Degree in both Engineering and Geology from Vanderbilt University. Since 1987 she has served as a Director and Assistant Secretary of both MD and MOC.
Ms. Buckley is the daughter of Curtis W. Mewbourne and is the sister of Dorothy M. Cuenod and Julie M. Greene. She is also the wife of J. Roe Buckley.

Julie M. Greene, age 45, received a B.A. 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 daughter of Curtis W. Mewbourne and is the sister of Dorothy M. Cuenod and Ruth M. 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.



|ITEM 11. | Executive Compensation
|-------- | ----------------------

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



16



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##### Table of Contents

|ITEM 12. | Security Ownership of Certain Beneficial Owners and Management
|-------- | --------------------------------------------------------------

(a)
Beneficial owners of more than five percent



|               |  |                        |  |                                     |  |               
|-------------- |  | ---------------------- |  | ----------------------------------- |  | --------------
|Title of Class |  | Name ofBeneficialOwner |  | Amount andNature ofBeneficial Owner |  | PercentofClass
|None           |  | None                   |  | N/A                                 |  | N/A           

(b) Security ownership of management

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



|ITEM 13. | Certain Relationships and Related Transactions
|-------- | ----------------------------------------------

Transactions with
MD and its affiliates

Pursuant to the Registrants Partnership Agreement, the Registrant had the following related party transactions with MD and its
affiliates during the year ended December 31, 2008 and the period beginning March 1, 2007 (date of inception) through December 31, 2007:



|                                                                                                                                                                                  |  |      |           |      |   |        
|--------------------------------------------------------------------------------------------------------------------------------------------------------------------------------- |  | ---- | --------- | ---- | - | -------
|                                                                                                                                                                                  |  | 2008 |           | 2007
|Administrative and general expense, management fees (if applicable) and payment of well charges and supervision charges in accordance with
standard industry operating agreements |  | $    | 3,394,274 |      | $ | 347,131
|                                                                                                                                                                                  |  |      |           |      |   |        

The 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.



|ITEM 14. | Principal Accountant Fees and Services
|-------- | --------------------------------------

The Partnership has
retained BDO Seidman, LLP as their independent registered public accounting firm to perform auditing services. BDO Seidman, LLPs fees for the year ended December 31, 2008 and the period beginning March 1, 2007 (date of inception)
through December 31, 2007 are set forth below:



|           |  |      |        |      |   |       
|---------- |  | ---- | ------ | ---- | - | ------
|           |  | 2008 |        | 2007
|Audit Fees |  | $    | 26,000 |      | $ | 12,000
|           |  |      |        |      |   |       



17



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##### Table of Contents

PART IV



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



|    |  |                     |  |                                                                                                                     |  |                                                                                                                                                                  |  |   
|--- |  | ------------------- |  | ------------------------------------------------------------------------------------------------------------------- |  | ---------------------------------------------------------------------------------------------------------------------------------------------------------------- |  | --
|(a) |  | 1.                  |  | Financial statements                                                                                                |  |                                                                                                                                                                 
|    |  |                     | 
|    |  |                     |  | The following are filed as part of this annual report:                                                              |  |                                                                                                                                                                 
|    |  |                     |  |                                                                                                                    
|    |  |                     |  |                                                                                                                     |  | Report of Independent Registered Accounting Firm                                                                                                                 |  | 21
|    |  |                     |  |                                                                                                                    
|    |  |                     |  |                                                                                                                     |  | Balance sheets as of December 31, 2008 and 2007                                                                                                                  |  | 22
|    |  |                     |  |                                                                                                                    
|    |  |                     |  |                                                                                                                     |  | Statements of operations for the year ended December 31, 2008 and the period from March 1, 2007 (date of inception) through December 31,
2007                    |  | 23
|    |  |                     |  |                                                                                                                    
|    |  |                     |  |                                                                                                                     |  | Statements of changes in partners capital for the year ended December 31, 2008 and the period from March 
1, 2007 (date of inception) through December 31, 2007 |  | 24
|    |  |                     |  |                                                                                                                    
|    |  |                     |  |                                                                                                                     |  | Statements of cash flows for the year ended December 31, 2008 and the period from March 1, 2007 (date of inception) through December 31,
2007                    |  | 25
|    |  |                     |  |                                                                                                                    
|    |  |                     |  |                                                                                                                     |  | Notes to financial statements                                                                                                                                    |  | 26
|    |  |                     | 
|    |  | 2.                  |  | Financial statement schedules                                                                                       |  |                                                                                                                                                                 
|    |  |                     | 
|    |  |                     |  | None.                                                                                                               |  |                                                                                                                                                                 
|    |  |                     | 
|    |  |                     |  | All required information is in the financial statements or the notes thereto, or is not applicable or required.     |  |                                                                                                                                                                 
|    |  |                     | 
|    |  | 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.                                                                                                               |  |                                                                                                                                                                 



18



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##### Table of Contents

SIGNATURES

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



Mewbourne Energy Partners 07-A, L.P.By:

Mewbourne Development CorporationManaging General PartnerBy:

/s/ Curtis W. MewbourneCurtis W. MewbournePresident and Director(Principal 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.



|                        |  |                          |  |               
|----------------------- |  | ------------------------ |  | --------------
|/s/ Curtis W. Mewbourne |  | President/Director       |  | March 31, 2009
|Curtis W. Mewbourne     |  |                          |  |               
|                        |  |                         
|/s/ J. Roe Buckley      |  | Executive Vice President |  | March 31, 2009
|J. Roe Buckley          |  | Chief Financial Officer  |  |               
|                        |  |                         
|/s/ Alan Clark          |  | Treasurer and Controller |  | March 31, 2009
|Alan Clark              |  |                          |  |               
|                        |  |                         
|/s/ Dorothy M. Cuenod   |  | Director                 |  | March 31, 2009
|Dorothy M. Cuenod       |  |                          |  |               
|                        |  |                         
|/s/ Ruth M. Buckley     |  | Director                 |  | March 31, 2009
|Ruth M. Buckley         |  |                          |  |               
|                        |  |                         
|/s/ Julie M. Greene     |  | Director                 |  | March 31, 2009
|Julie M. Greene         |  |                          |  |               

Supplemental 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

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



19



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##### Table of Contents

MEWBOURNE ENERGY PARTNERS 07-A, L.P.

FINANCIAL STATEMENTS

WITH REPORT OF INDEPENDENT REGISTERED ACCOUNTING FIRM

For the year ended December 31, 2008 and the period from March 1, 2007

(date of inception) through December 31, 2007



20



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##### Table of Contents

Report of Independent Registered Accounting Firm

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

We have audited the accompanying balance sheets of Mewbourne Energy Partners 07-A L.P. as of December 31, 2008 and 2007 and the related statements of operations,
changes in partners capital and cash flows for each of the two years in the period ended December 31, 2008. These financial statements are the responsibility of the Companys management. Our responsibility is to express an opinion on
these financial statements based on our audits.

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

In our opinion, the financial statements referred to above present fairly, in all material respects, the financial position of Mewbourne Energy
Partners 07-A L.P. at December 31, 2008 and 2007, and the results of its operations and its cash flows for each of the two years in the period ended December 31, 2008, in conformity with accounting principles generally accepted in the
United States of America.



|                    
|--------------------
|/s/ BDO Seidman, LLP
|                    
|Dallas, Texas       

March 31, 2009



21



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##### Table of Contents

MEWBOURNE ENERGY PARTNERS 07-A, L.P.

BALANCE SHEETS

December 31, 2008 and
2007



|                                                                      |  |      |             |   |      |   |            |  
|--------------------------------------------------------------------- |  | ---- | ----------- | - | ---- | - | ---------- | -
|                                                                      |  | 2008 |             |   | 2007 |  
|ASSETS                                                                |  |      |             |   |      |   |            |  
|                                                                      |  |     
|Cash and cash equivalents                                             |  | $    | 3,952,913   |   |      | $ | 42,951,823 |  
|Accounts receivable, affiliate                                        |  |      | 4,154,134   |   |      |   | 1,425,301  |  
|Accounts receivable, other                                            |  |      | 960         |   |      |   | 200,925    |  
|                                                                      |  |      |             |   |      |   |            |  
|Total current assets                                                  |  |      | 8,108,007   |   |      |   | 44,578,049 |  
|                                                                      |  |      |             |   |      |   |            |  
|                                                                      |  |     
|Prepaid well costs                                                    |  |      |            |   |      |   | 8,959,712  |  
|                                                                      |  |      |             |   |      |   |            |  
|                                                                      |  |     
|Oil and gas properties at cost, full-cost method                      |  |      | 64,317,421  |   |      |   | 14,358,664 |  
|Less accumulated depreciation, depletion, amortization and impairment |  |      | (26,766,704 | ) |      |   | (578,512   | )
|                                                                      |  |      |             |   |      |   |            |  
|                                                                      |  |      | 37,550,717  |   |      |   | 13,780,152 |  
|                                                                      |  |      |             |   |      |   |            |  
|Total assets                                                          |  | $    | 45,658,724  |   |      | $ | 67,317,913 |  
|                                                                      |  |      |             |   |      |   |            |  
|                                                                      |  |     
|LIABILITIES AND PARTNERS CAPITAL                                     |  |      |             |   |      |   |            |  
|                                                                      |  |     
|Accounts payable, affiliate                                           |  | $    | 72,841      |   |      | $ | 991,514    |  
|                                                                      |  |      |             |   |      |   |            |  
|Total current liabilities                                             |  |      | 72,841      |   |      |   | 991,514    |  
|                                                                      |  |      |             |   |      |   |            |  
|                                                                      |  |     
|Asset retirement obligation                                           |  |      | 352,147     |   |      |   | 56,158     |  
|                                                                      |  |     
|Partners capital                                                     |  |      |             |   |      |   |            |  
|General partners                                                      |  |      | 42,461,555  |   |      |   | 62,208,822 |  
|Limited partners                                                      |  |      | 2,772,181   |   |      |   | 4,061,419  |  
|                                                                      |  |      |             |   |      |   |            |  
|Total partners capital                                               |  |      | 45,233,736  |   |      |   | 66,270,241 |  
|                                                                      |  |      |             |   |      |   |            |  
|Total liabilities and partners capital                               |  | $    | 45,658,724  |   |      | $ | 67,317,913 |  
|                                                                      |  |      |             |   |      |   |            |  

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



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MEWBOURNE ENERGY PARTNERS 07-A, L.P.

STATEMENTS OF OPERATIONS

For the year ended
December 31, 2008 and the period from

March 1, 2007 (date of inception) through December 31, 2007



|                                                                                 |  |      |            |      |   |          
|-------------------------------------------------------------------------------- |  | ---- | ---------- | ---- | - | ---------
|                                                                                 |  | 2008 |            | 2007
|Revenues and other income:                                                       |  |      |            |      |   |          
|Oil sales                                                                        |  | $    | 8,125,298  |      | $ | 356,652  
|Gas sales                                                                        |  |      | 20,853,345 |      |   | 1,358,579
|Interest income                                                                  |  |      | 629,007    |      |   | 1,245,753
|                                                                                 |  |      |            |      |   |          
|Total revenues and other income                                                  |  |      | 29,607,650 |      |   | 2,960,984
|                                                                                 |  |      |            |      |   |          
|                                                                                 |  |     
|Expenses:                                                                        |  |      |            |      |   |          
|Lease operating expense                                                          |  |      | 1,164,885  |      |   | 37,681   
|Production taxes                                                                 |  |      | 1,673,527  |      |   | 119,158  
|Administrative and general expense                                               |  |      | 478,899    |      |   | 4,833    
|Depreciation, depletion, and amortization                                        |  |      | 7,864,277  |      |   | 578,512  
|Cost ceiling write-down                                                          |  |      | 18,323,915 |      |   |         
|Asset retirement obligation accretion                                            |  |      | 13,652     |      |   | 559      
|                                                                                 |  |      |            |      |   |          
|Total expenses                                                                   |  |      | 29,519,155 |      |   | 740,743  
|                                                                                 |  |      |            |      |   |          
|                                                                                 |  |     
|Net income                                                                       |  | $    | 88,495     |      | $ | 2,220,241
|                                                                                 |  |      |            |      |   |          
|Allocation of net income:                                                        |  |      |            |      |   |          
|General partners                                                                 |  | $    | 83,072     |      | $ | 2,084,172
|                                                                                 |  |      |            |      |   |          
|                                                                                 |  |     
|Limited partners                                                                 |  | $    | 5,423      |      | $ | 136,069  
|                                                                                 |  |      |            |      |   |          
|                                                                                 |  |     
|Basic and diluted net income per partner interest (14,000 interests outstanding) |  | $    | 6.32       |      | $ | 158.59   
|                                                                                 |  |      |            |      |   |          

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



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MEWBOURNE ENERGY PARTNERS 07-A, L.P.

STATEMENTS OF CHANGES IN PARTNERS CAPITAL

For the year ended December 31, 2008 and the period from

March 1, 2007 (date of inception) through December 31, 2007



|                                                                                                            |  |                 |             |   |                 |   |            |       |  |   |             |  
|----------------------------------------------------------------------------------------------------------- |  | --------------- | ----------- | - | --------------- | - | ---------- | ----- |  | - | ----------- | -
|                                                                                                            |  | GeneralPartners |             |   | LimitedPartners |   |            | Total | 
|Balance at December 31, 2006                                                                                |  | $               |            |   |                 | $ |           |       |  | $ |            |  
|Capital contributions, net of sales commissions and marketing fees of $5,585,350 and $364,650, respectively |  |                 | 60,124,650  |   |                 |   | 3,925,350  |       |  |   | 64,050,000  |  
|Net income                                                                                                  |  |                 | 2,084,172   |   |                 |   | 136,069    |       |  |   | 2,220,241   |  
|                                                                                                            |  |                 |             |   |                 |   |            |       |  |   |             |  
|                                                                                                            |  |                 |            
|Balance at December 31, 2007                                                                                |  |                 | 62,208,822  |   |                 |   | 4,061,419  |       |  |   | 66,270,241  |  
|                                                                                                            |  |                 |            
|Cash distributions                                                                                          |  |                 | (19,830,339 | ) |                 |   | (1,294,661 | )     |  |   | (21,125,000 | )
|Net income                                                                                                  |  |                 | 83,072      |   |                 |   | 5,423      |       |  |   | 88,495      |  
|                                                                                                            |  |                 |             |   |                 |   |            |       |  |   |             |  
|                                                                                                            |  |                 |            
|Balance at December 31, 2008                                                                                |  | $               | 42,461,555  |   |                 | $ | 2,772,181  |       |  | $ | 45,233,736  |  
|                                                                                                            |  |                 |             |   |                 |   |            |       |  |   |             |  
|                                                                                                            |  |                 |            
|Distribution amount per partnership unit for the year ended December 31, 2008                               |  | $               | 1,508.93    |   |                 | $ | 1,508.93   |       |  |   |             |  
|                                                                                                            |  |                 |             |   |                 |   |            |       |  |   |             |  

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



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MEWBOURNE ENERGY PARTNERS 07-A, L.P.

STATEMENTS OF CASH FLOWS

For the year ended
December 31, 2008 and the period from

March 1, 2007 (date of inception) through December 31, 2007



|                                                                                                                          |  |      |             |   |      |   |             |  
|------------------------------------------------------------------------------------------------------------------------- |  | ---- | ----------- | - | ---- | - | ----------- | -
|                                                                                                                          |  | 2008 |             |   | 2007 |  
|Cash flows from operating activities:                                                                                     |  |      |             |   |      |   |             |  
|Net income                                                                                                                |  | $    | 88,495      |   |      | $ | 2,220,241   |  
|Adjustments to reconcile net income to net cash provided by operating activities:                                         |  |      |             |   |      |   |             |  
|Depreciation, depletion, and amortization                                                                                 |  |      | 7,864,277   |   |      |   | 578,512     |  
|Cost ceiling write-down                                                                                                   |  |      | 18,323,915  |   |      |   |            |  
|Asset retirement obligation accretion                                                                                     |  |      | 13,652      |   |      |   | 559         |  
|Changes in operating assets and liabilities:                                                                              |  |      |             |   |      |   |             |  
|Accounts receivable, affiliate                                                                                            |  |      | (2,728,833  | ) |      |   | (1,425,301  | )
|Accounts receivable, other                                                                                                |  |      | 199,965     |   |      |   | (200,925    | )
|Accounts payable, affiliate                                                                                               |  |      | (918,673    | ) |      |   | 991,514     |  
|                                                                                                                          |  |      |             |   |      |   |             |  
|Net cash provided by operating activities                                                                                 |  |      | 22,842,798  |   |      |   | 2,164,600   |  
|                                                                                                                          |  |      |             |   |      |   |             |  
|                                                                                                                          |  |     
|Cash flows from investing activities:                                                                                     |  |      |             |   |      |   |             |  
|Purchase and development of oil and gas properties                                                                        |  |      | (49,676,420 | ) |      |   | (14,303,065 | )
|Prepaid well costs                                                                                                        |  |      | 8,959,712   |   |      |   | (8,959,712  | )
|                                                                                                                          |  |      |             |   |      |   |             |  
|Net cash used in investing activities                                                                                     |  |      | (40,716,708 | ) |      |   | (23,262,777 | )
|                                                                                                                          |  |      |             |   |      |   |             |  
|                                                                                                                          |  |     
|Cash flows from financing activities:                                                                                     |  |      |             |   |      |   |             |  
|Capital contributions from partners, net of sales commissions and marketing fees of $5,585,350 and $364,650, respectively |  |      |            |   |      |   | 64,050,000  |  
|Cash distributions to partners                                                                                            |  |      | (21,125,000 | ) |      |   |            |  
|                                                                                                                          |  |      |             |   |      |   |             |  
|Net cash provided by (used in) financing activities                                                                       |  |      | (21,125,000 | ) |      |   | 64,050,000  |  
|                                                                                                                          |  |      |             |   |      |   |             |  
|                                                                                                                          |  |     
|Net increase (decrease) in cash and cash equivalents                                                                      |  |      | (38,998,910 | ) |      |   | 42,951,823  |  
|Cash and cash equivalents, beginning of period                                                                            |  |      | 42,951,823  |   |      |   |            |  
|                                                                                                                          |  |      |             |   |      |   |             |  
|                                                                                                                          |  |     
|Cash and cash equivalents, end of period                                                                                  |  | $    | 3,952,913   |   |      | $ | 42,951,823  |  
|                                                                                                                          |  |      |             |   |      |   |             |  
|                                                                                                                          |  |     
|Supplemental Cash Flow Information:                                                                                       |  |      |             |   |      |   |             |  
|Non-cash changes to oil & gas properties related to asset retirement obligation liabilities                               |  | $    | 282,337     |   |      | $ | 55,599      |  
|                                                                                                                          |  |      |             |   |      |   |             |  

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



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Mewbourne Energy Partners 07-A, L.P.

NOTES TO FINANCIAL STATEMENTS

1. Significant Accounting
Policies:

Accounting for Oil and Gas Producing Activities

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 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. The managing general partner has no equity interest in the Partnership.

The Programs sole business is the development
and production of oil and gas with a concentration on gas. A substantial portion of the Program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 Programs oil and gas
are subject to influences such as global consumption and supply trends.

The Partnership follows the full-cost method of accounting for its oil and gas
activities. Under the full-cost method, all productive and non-productive costs incurred in the acquisition, exploration and development of oil and gas properties are capitalized. Depreciation, depletion and amortization of oil and gas properties
subject to amortization is computed on the units-of-production method based on the proved reserves underlying the oil and gas properties. At December 31, 2008 all capitalized costs were subject to amortization, while at December 31, 2007
approximately $353,000 of capitalized costs were excluded from amortization. Proceeds from the sale or other disposition of properties are credited to the full cost pool. Gains and losses are not recognized unless such adjustments would
significantly alter the relationship between capitalized costs and the proved oil and gas reserves. Capitalized costs are subject to a quarterly ceiling test that limits such costs to the aggregate of the present value of future net cash flows of
proved reserves and the lower of cost or fair value of unproved properties. There were cost ceiling write-downs totaling $18,323,915 at September 30, 2008 and December 31, 2008 due to lower oil and gas prices on those dates. There were no
write-downs during 2007.

Significant 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 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.



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New Accounting Pronouncements

Modernization of Oil and Gas ReportingIn January 2009, the Securities and Exchange Commission issued revisions to the oil and gas reporting disclosures, Modernization of Oil and Gas Reporting; Final Rule (the
Final Rule). In addition to changing the definition and disclosure requirements for oil and gas reserves, the Final Rule changes the requirements for determining quantities of oil and gas reserves. The Final Rule also changes certain
accounting requirements under the full cost method of accounting for oil and gas activities. The amendments are designed to modernize the requirements for the determination of oil and gas reserves, aligning them with current practices and updating
them for changes in technology. The Final Rule is effective for annual reports on Form10-K for fiscal years ending on or after December 31, 2009. The Partnership has not yet determined the impact, if any, on the financial statements.

The Hierarchy of Generally Accepted Accounting Principles In May 2008, the FASB issued SFAS No. 162, The Hierarchy of
Generally Accepted Accounting Principles (SFAS 162). SFAS No.162 identifies the sources for accounting principles and the framework for selecting the principles to be used in preparing financial statements of nongovernmental
entities that are presented in conformity with generally accepted accounting principles in the United States. This Statement became effective in November 2008.

Fair Value MeasurementsIn September 2006, the FASB issued SFAS No. 157, which defines fair value, establishes a framework for measuring fair value, and expands disclosures about fair value measurements. Effective
January 1, 2008, the Partnership adopted SFAS No. 157, which applies to other accounting pronouncements that require or permit fair value measurements; however, it does not require any new fair value measurements.

SFAS No. 157 establishes a valuation hierarchy for disclosure of the inputs to valuation used to measure fair value. This hierarchy prioritizes the inputs into
three broad levels. Level 1 inputs are quoted prices (unadjusted) in active markets for identical assets or liabilities. All of the Partnerships cash equivalents fall into Level 1 and consist of short-term, highly liquid investments, which
have maturities of 90 days or less, including sweep investments and money market funds. The Partnership does not have any assets or liabilities falling under Level 2 or 3.

Disclosures about Derivative Instruments and Hedging ActivitiesIn March 2008, the Financial Accounting Standards Board (FASB) issued Statements of Financial Accounting Standards
(SFAS) SFAS No. 161, Disclosures about Derivative Instruments and Hedging Activities (SFAS No. 161). SFAS No. 161 requires entities that utilize derivative instruments to provide qualitative
disclosures about their objectives and strategies for using such instruments, as well as any details of credit-risk-related contingent features contained within derivatives. The Partnership does not utilize derivative instruments; therefore, the
Partnership does not expect this pronouncement to have any impact on the Partnerships results of operations, cash flows or financial position.

Non-controlling Interests in Consolidated Financial Statements In December 2007, the FASB issued SFAS No. 160, Noncontrolling Interests in Consolidated Financial Statements, an amendment of Accounting Research
Bulletin No. 51 (SFAS No. 160), which improves the relevance, comparability and transparency of the financial information that a reporting entity provides in its consolidated financial statements by establishing
accounting and reporting standards for the noncontrolling interest in a subsidiary and for the deconsolidation of a subsidiary. The Partnership does not own any subsidiaries and does not expect this pronouncement to have any impact on the
Partnerships results of operations, cash flows or financial position.

Business CombinationsIn December 2007, FASB issued SFAS
No. 141 (revised 2007), Business Combinations (SFAS No. 141R), which replaces SFAS No. 141, Business Combinations (SFAS No. 141). SFAS 141R retains the fundamental requirements in
SFAS No. 141 that the acquisition method of accounting (which SFAS No. 141 called the purchase method) be used for all business combinations. The Partnership has no business combinations in progress or, at this time, in future plans. The
Partnership does not expect this pronouncement to have any impact on the Partnerships results of operations, cash flows or financial position.



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Accounting Standard Fair Value for Financial Assets and Financial LiabilitiesIn February 2007, the FASB
issued SFAS No. 159, The Fair Value Option for Financial Assets and Financial Liabilities (SFAS No. 159). SFAS No. 159 allows entities the option to measure eligible financial instruments at fair value as
of specified dates. The Partnership did not elect fair value as an alternative as provided under SFAS No. 159 for any of its financial assets and liabilities that are not currently measured at fair value.

Cash and Cash Equivalents

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

Asset Retirement Obligations

In accordance with FAS 143, the Partnership has recognized an estimated liability for future plugging and abandonment
costs. The estimated liability is based on historical experience and estimated well life. The liability is discounted using the credit-adjusted risk-free rate. Revisions to the liability could occur due to changes in well plugging and abandonment
costs or well useful lives, or if federal or state regulators enact new well restoration requirements. The Partnership recognizes accretion expense in connection with the discounted liability over the remaining life of the well.

A reconciliation of the Partnerships liability for well plugging and abandonment costs for the year ended December 31, 2008 and the period from March 1,
2007 (date of inception) through December 31, 2007 is as follows:



|                             |  |      |         |   |      |   |       
|---------------------------- |  | ---- | ------- | - | ---- | - | ------
|                             |  | 2008 |         |   | 2007
|Balance, beginning of period |  | $    | 56,158  |   |      | $ |      
|Liabilities incurred         |  |      | 283,966 |   |      |   | 55,599
|Liabilities reduced          |  |      | (1,629  | ) |      |   |      
|Accretion expense            |  |      | 13,652  |   |      |   | 559   
|                             |  |      |         |   |      |   |       
|                             |  |     
|Balance, end of period       |  | $    | 352,147 |   |      | $ | 56,158
|                             |  |      |         |   |      |   |       

Oil and Gas Sales

The Programs oil and condensate production is sold and revenue recognized at or near the Program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 Programs interest are recorded as revenue when the gas is metered and title transferred pursuant to the gas sales contracts covering the Program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, 2008 and
2007, no material gas imbalances between the Partnership and other working interest owners existed.

Income Taxes

The Partnership is treated as a partnership for income tax purposes and, as a result, income of the Partnership is reported on the tax returns of the partners and no
recognition is given to income taxes in the financial statements. The Partnerships financial reporting bases of its net assets exceeded the tax bases of its net assets by $32,919,185 and $19,230,348 at December 31, 2008 and 2007,
respectively.



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2. Organization and Related Party Transactions:

The Partnership was organized on March 1, 2007 in accordance 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. Mewbourne Oil Company (MOC) is operator of oil and gas properties owned by the Partnership. Mewbourne Holdings, Inc. is the parent of both MD and MOC. Substantially all transactions are with MD and MOC.

In the ordinary course of business, MOC will incur certain costs that will be passed on to well owners of the well on which the costs were incurred. The
Partnership will be charged their portion of these costs based upon their ownership in each well incurring the costs. These costs are referred to as Operator charges and are standard and customary in the oil and gas industry. Operator charges
include recovery of gas marketing costs, fixed rate overhead, supervision, pumping, and equipment furnished by the Operator. Reimbursement to MOC for operator charges totaled $2,498,108 and $345,936 for the year ended December 31, 2008 and the
period beginning March 1, 2007 (date of inception) through December 31, 2007, respectively. Operator charges are billed in accordance with the Program and Partnership Agreements.

In consideration for services rendered by MD in managing the business of the Partnership, the Partnership during each of the initial three years of the Partnership pays
to MD a management fee in the amount equal to 7/10s of 1% of the subscriptions by the investor partners to the Partnership. Management fees can only be paid out of funds available for distributions. Under this arrangement, management fees of
$490,000 were allocated to the Partnership for the year ended December 31, 2008. Since there were not sufficient funds available for distribution, management fees were not allocated to the Partnership for the period beginning March 1, 2007
(date of inception) through December 31, 2007. The Partnership includes the management fee as part of the full cost pool pursuant to Rule 4-10(c)(2) of Regulation S-X.

In general, 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, $406,166 and $1,195 were allocated to the Partnership during the year ended December 31, 2008 and the period beginning
March 1, 2007 (date of inception) through December 31, 2007, respectively.

The Partnership participates in oil and gas activities through a
Drilling Program Agreement (the Program). The Drilling Program Agreement provides that MOC, in its capacity as manager of the Program, will have the exclusive power and authority to act on behalf of the Partnership with respect to the
management, control and administration of the business and affairs of the Program and the oil and gas properties subject to the Drilling Program Agreement. The Drilling Program Agreement sets out the rights, duties, and obligations of the program
manager and the other participants in 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  |  
|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.
|--- | ------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------



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3. Quarterly Financial Data (unaudited):

Summarized unaudited quarterly financial data for 2008 is as follows:



|                                                                                        |  |                |           |              |   |                   |  |   |                  |       |  |   |            |      
|--------------------------------------------------------------------------------------- |  | -------------- | --------- | ------------ | - | ----------------- |  | - | ---------------- | ----- |  | - | ---------- | -----
|                                                                                        |  | Quarters Ended |          
|                                                                                        |  | March 31,2008  |           | June 30,2008 |   | September 30,2008 |  |   | December 31,2008 |      
|Total revenues                                                                          |  | $              | 4,311,719 |              | $ | 7,550,605         |  | $ | 10,710,838       |       |  | $ | 6,405,481  |      
|Gross profit (loss) (a)                                                                 |  |                | 2,842,428 |              |   | 4,955,218         |  |   | (1,547,464       | )     |  |   | (6,790,694 | )    
|Net income (loss)                                                                       |  |                | 3,170,529 |              |   | 5,172,633         |  |   | (1,476,840       | ) (b) |  |   | (6,777,827 | ) (c)
|Basic and diluted net income (loss) per partner interest (14,000 interests outstanding) |  | $              | 226.47    |              | $ | 369.47            |  | $ | (105.49          | )     |  | $ | (484.13    | )    
|                                                                                        |  |                |           |              |   |                   |  |   |                  |       |  |   |            |      

Summarized unaudited quarterly financial data for 2007 is as follows:



|                                                                                 |  |                |   |              |   |                   |  |                  |         |  |   |          
|-------------------------------------------------------------------------------- |  | -------------- | - | ------------ | - | ----------------- |  | ---------------- | ------- |  | - | ---------
|                                                                                 |  | Quarters Ended
|                                                                                 |  | March 31,2007  |   | June 30,2007 |   | September 30,2007 |  | December 31,2007
|Total revenues                                                                   |  | $              |  |              | $ |                  |  | $                | 34,604  |  | $ | 1,680,627
|Gross profit (a)                                                                 |  |                |  |              |   |                  |  |                  | 18,008  |  |   | 956,480  
|Net income                                                                       |  |                |  |              |   |                  |  |                  | 585,778 |  |   | 1,634,463
|Basic and diluted net income per partner interest (14,000 interests outstanding) |  | $              |  |              | $ |                  |  | $                | 41.84   |  | $ | 116.75   
|                                                                                 |  |                |   |              |   |                   |  |                  |         |  |   |          



|(a) | Total revenue less operating costs.
|--- | -----------------------------------

|(b) | Includes cost ceiling write-down of $8,077,590
|--- | ----------------------------------------------

|(c) | Includes cost ceiling write-down of $10,246,325
|--- | -----------------------------------------------



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##### Table of Contents

4. Supplemental Oil and Gas Information (unaudited):

The tables presented below provide supplemental information about oil and natural gas exploration and production activities as defined by SFAS No. 69, Disclosures about Oil and Gas Producing
Activities.

Costs Incurred and Capitalized Costs:

Costs incurred in oil and natural gas acquisition, exploration and development activities for the year ended December 31, 2008 and the period from March 1, 2007 (date of inception) through December 31, 2007 were:



|            |  |      |            |      |   |           
|----------- |  | ---- | ---------- | ---- | - | ----------
|            |  | 2008 |            | 2007
|Development |  | $    | 40,716,708 |      | $ | 23,262,777
|            |  |      |            |      |   |           

Capitalized costs related to oil and natural gas acquisition, exploration and development activities for the year
ended December 31, 2008 and the period from March 1, 2007 (date of inception) through December 31, 2007 were as follows:



|                                                                 |  |      |             |   |      |   |            |  
|---------------------------------------------------------------- |  | ---- | ----------- | - | ---- | - | ---------- | -
|                                                                 |  | 2008 |             |   | 2007 |  
|Cost of oil and natural gas properties at year-end:              |  |      |             |   |      |   |            |  
|Producing assetsProved properties                               |  | $    | 63,979,485  |   |      | $ | 13,949,740 |  
|Incomplete constructionUnproved properties                      |  |      |            |   |      |   | 353,325    |  
|Asset retirement obligation                                      |  |      | 337,936     |   |      |   | 55,599     |  
|                                                                 |  |      |             |   |      |   |            |  
|Total capitalized cost                                           |  |      | 64,317,421  |   |      |   | 14,358,664 |  
|Accumulated depreciation, depletion, amortization and impairment |  |      | (26,766,704 | ) |      |   | (578,512   | )
|                                                                 |  |      |             |   |      |   |            |  
|Net capitalized costs                                            |  | $    | 37,550,717  |   |      | $ | 13,780,152 |  
|                                                                 |  |      |             |   |      |   |            |  



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##### Table of Contents

Estimated Net Quantities of Proved Oil and Gas Reserves:

Reserve estimates as well as certain information regarding future production and discounted cash flows were determined by the Partnerships independent petroleum consultants and MOCs petroleum reservoir
engineers. The Partnership considers reserve estimates to be reasonable; however, due to inherent uncertainties and the limited nature of reservoir data, estimates of oil and gas reserves are imprecise and subject to change over time as additional
information becomes available.

There have been no favorable or adverse events that have caused a significant change in estimated proved reserves since
December 31, 2008 The Partnership has no long-term supply agreements or contracts with governments or authorities in which it acts as producer nor does it have any interest in oil and gas operations accounted for by the equity method. All
reserves are located onshore within the United States.



|                                            |  |                                                |   |  |                                   |  
|------------------------------------------- |  | ---------------------------------------------- | - |  | --------------------------------- | -
|                                            |  | Crude OilandCondensate(Thousandsof bbls ofOil) |   |  | NaturalGas(Thousandsof CubicFeet) |  
|Proved Reserves:                            |  |                                                |   |  |                                   |  
|                                            |  |                                               
|Balance at December 31, 2006                |  | 0                                              |   |  | 0                                 |  
|                                            |  |                                               
|Extensions, discoveries and other additions |  | 52                                             |   |  | 4,779                             |  
|Production                                  |  | (4                                             | ) |  | (188                              | )
|                                            |  |                                                |   |  |                                   |  
|                                            |  |                                               
|Balance at December 31, 2007 (1)            |  | 48                                             |   |  | 4,591                             |  
|                                            |  |                                               
|Revisions to previous estimates             |  | 96                                             |   |  | 2,298                             |  
|Extensions, discoveries and other additions |  | 364                                            |   |  | 13,322                            |  
|Production                                  |  | (86                                            | ) |  | (2,562                            | )
|                                            |  |                                                |   |  |                                   |  
|                                            |  |                                               
|Balance at December 31, 2008 (1)            |  | 422                                            |   |  | 17,649                            |  
|                                            |  |                                                |   |  |                                   |  



|(1) | All of these reserves are categorized as proved developed as of December 31, 2008 and 2007.
|--- | -------------------------------------------------------------------------------------------



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##### Table of Contents

MEWBOURNE ENERGY PARTNERS 07-A, L.P.

INDEX TO EXHIBITS

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



|              |  |                                                                                                                                                  
|------------- |  | -------------------------------------------------------------------------------------------------------------------------------------------------
|EXHIBITNUMBER |  | 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 2 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)                                       
|              | 
|10.4          |  | 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                                                                       



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