Mewbourne Energy Partners 07-A, L.P. - FORM 10-K

Mewbourne Energy Partners 07-A, L.P. - FORM 10-K - March 31, 2010

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file	filename
EX-31.2 - SECTION 302 CERT. - CFO - Mewbourne Energy Partners 07-A, L.P.	dex312.htm
EX-99.1 - REPORT OF FORREST A. GARB & ASSOCIATES - Mewbourne Energy Partners 07-A, L.P.	dex991.htm
EX-32.1 - SECTION 906 CERT. - CEO - Mewbourne Energy Partners 07-A, L.P.	dex321.htm
EX-32.2 - SECTION 906 CERT. - CFO - Mewbourne Energy Partners 07-A, L.P.	dex322.htm
EX-31.1 - SECTION 302 CERT. - CEO - Mewbourne Energy Partners 07-A, L.P.	dex311.htm

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, 2009

¨	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 of incorporation or organization)		(I.R.S. Employer Identification Number)

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

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

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

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

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.

MEWBOURNE ENERGY PARTNERS 07-A, L.P.

INDEX


Part I			3

	Item 1.	Business	3

	Item 1A.	Risk Factors	4

	Item 1B.	Unresolved Staff Comments	6

	Item 2.	Properties	6

	Item 3.	Legal Proceedings	7

	Item 4.	Reserved for Future Use	7

Part II			8

	Item 5.	Market for Registrant’s Common Equity and Related Stockholder Matters	8

	Item 6.	Selected Financial Data	8

	Item 7.	Management’s Discussion and Analysis of Financial Condition and Results of Operations	8

	Item 7A.	Quantitative 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	13

	Item 9A.	Controls and Procedures	13

Part III			14

	Item 10.	Directors and Executive Officers of the Registrant	14

	Item 11.	Executive Compensation	15

	Item 12.	Security Ownership of Certain Beneficial Owners and Management	15

	Item 13.	Certain Relationships and Related Transactions	16

	Item 14.	Principal Accountant Fees and Services	16

Part IV			17

	Item 15.	Exhibits, Financial Statements, Financial Statement Schedules and Reports on Form 8K	17

SIGNATURES			18

INDEX TO EXHIBITS			31

Certification of CEO Pursuant to Section 302

Certification of CFO Pursuant to Section 302

Certification of CEO Pursuant to Section 906

Certification of CFO Pursuant to Section 906

Report of Forrest A. Garb & Associates, Inc.

PART I

ITEM 1.

Business

Mewbourne Energy Partners 07-A, L.P. (the “Registrant” or the “Partnership”) is a limited partnership organized under the laws of the State of Delaware on March 1, 2007 (date of inception). Mewbourne Development Corporation (“MD”), a Delaware Corporation, has been appointed as the Registrant’s managing general partner. MD has no significant equity interest in the Registrant.

Limited and general partner interests in the Registrant were offered at $5,000 each to accredited investors in a private placement pursuant to Section 4(2) of the Securities Act of 1933 and Regulation D promulgated thereunder, with a maximum offering amount of $70,000,000 (14,000 interests). On August 13, 2007, the offering of limited and general partnership interests in the Registrant was closed, with interests aggregating $70,000,000 originally being sold to accredited investors of which $65,710,000 were sold to accredited investors as general partner interests and $4,290,000 were sold to accredited investors as limited partner interests.

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

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

The market for crude oil is such that the Registrant anticipates it will be able to sell all the crude oil it can produce. Natural gas 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, 2010, MOC employed 231 persons, many of whom dedicated a part of their time to the conduct of the Registrant’s business during the period for which this report is filed.

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

ITEM 1A.

Risk Factors

Oil and natural gas prices are volatile. 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 75% of the Registrant’s reserves at December 31, 2009 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.

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

The December 31, 2009 proved reserves estimates presented in this report have been prepared using new SEC disclosure rules that differ in a number of respects from prior rules. As a result of changes in the reporting rules, reserve estimates beginning with December 31, 2009 will not be directly comparable to the Partnership’s previously reported reserves. Under the prior SEC rules, reserve valuation at December 31, 2009 would be 385,234 barrels of oil and 17,109,756 mcf of gas, as compared to 371,642 barrels and 15,940,653 mcf under the new rules.

The SEC has not reviewed any reporting entity’s reserve estimates under the new rules and has released only limited interpretive guidance regarding reporting of reserve estimates under the new rules. Accordingly, while the estimates of proved reserves at December 31, 2009 included in this report have been prepared based on what the Partnership and the Partnership’s independent reserve engineers believe to be reasonable interpretations of the new SEC rules, those estimates could differ materially from any estimates we might prepare applying more specific SEC interpretive guidance.

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 oil and gas pricing guidelines established by the Securities and Exchange Commission. 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 during the year ended December 31, 2009 indicated an impairment of oil and natural gas properties of approximately $13.6 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.

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

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

ITEM 1B.

Unresolved Staff Comments

None.

ITEM 2.

Properties

Property Interests

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

Fractional working interests in developmental oil and gas prospects, located primarily in the Anadarko Basin of Western Oklahoma, the Texas Panhandle, and the Permian Basin of New Mexico and West Texas, were acquired by the Registrant, resulting in the Registrant’s participation in the drilling of oil and gas wells. At December 31, 2009, the Registrant owned working interests in 113 producing wells. The Registrant participated in the drilling of wells for the years ended December 31, 2009 and 2008, as shown in the following table:


	2009		2008
	Gross	Net	Gross	Net
Development Wells
Oil and natural gas wells	—	—	87	18.389

Third Party Review of Reserves Estimate

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

•

Over 25 years of practical experience in petroleum engineering

•

Registered professional engineer in the state of Texas

•

Bachelor of Science Degree in Petroleum Engineering

•

Master of Business Administration

Internal Controls Over Reserves Estimate

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

•

No employee’s compensation is tied to the amount of reserves booked.

•

Comprehensive SEC-compliant internal policies are followed to determine and report proved reserves.

•

Reserves estimate is made by experienced reservoir engineers or under their direct supervision.

•

The reservoir engineers review all the Partnership’s reported proved reserves at the close of each quarter.

ITEM 3.

Legal Proceedings

From time to time, the Registrant may be a party to certain legal actions and claims arising in the ordinary course of business. While the outcome of these events cannot be predicted with certainty, the Partnership does not expect these matters to have a material effect on its financial position or results of operations.

ITEM 4.

Reserved for Future Use

PART II

ITEM 5.

Market for Registrant’s Common Equity and Related Stockholder Matters

At March 31, 2010, 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 of $15,449,999 and $21,125,000 were made to limited and general partners during the years ended December 31, 2009 and 2008, respectively.

ITEM 6.

Selected Financial Data

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

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.

Results of Operations

Year ended December 31, 2009 compared to the year ended December 31, 2008:


	2009		2008
Oil sales	$	3,513,731	$	8,125,298
Barrels produced		65,159		85,779
Average price/bbl	$	53.93	$	94.72

Gas sales	$	9,652,557	$	20,853,345
Mcf produced		2,154,892		2,561,709
Average price/mcf	$	4.48	$	8.14

Oil and gas revenues. As shown in the above table, total oil and gas sales decreased by $15,812,355, a 54.6% decline, for the year ended December 31, 2009 as compared to year ended December 31, 2008.

Of this decrease, $3,499,623 and $9,378,504 were due to decreases in the average prices of oil and gas sold, respectively. Average prices fell to $53.93 from $94.72 per bbl and to $4.48 from $8.14 per mcf for the year ended December 31, 2009 as compared to the year ended December 31, 2008. In addition, $1,111,944 and $1,822,284 were due to decreases in the volumes of oil and gas sold by 20,620 bbls of oil and 406,817 mcf of gas. The decrease in volumes sold was primarily due to normal declines in production.

Interest income. Interest income decreased to $1,426 for the year ended December 31, 2009 from $629,007 for the year ended December 31, 2008 as cash was utilized for the drilling and equipping of wells and distributions to partners.

Lease operations. Lease operating expense during the year ended December 31, 2009 was $1,281,041, which was comparable to $1,164,885 during the year ended December 31, 2008.

Production taxes. Production taxes during the year ended December 31, 2009 decreased to $739,205 from $1,673,527 for the year ended December 31, 2008 due to decreased revenue.

Administrative and general expenses. Administrative and general expenses were $471,183 in 2009, which was comparable to $478,899 in 2008.

Depreciation, depletion and amortization. Depreciation, depletion and amortization decreased to $3,784,362 in 2009 from $7,864,277 in 2008. The decrease was primarily due to the lower amortizable base as a result of the $13,601,516 cost ceiling writedown in 2009 as well as the carryover effect of cost ceiling writedowns totaling $18,323,915 in 2008.

Cost ceiling write-down. There was a cost ceiling write-down of $13,601,516 at March 31, 2009 due to lower oil and gas prices on that date. There were cost ceiling write-downs of $8,077,590 and $10,246,325 at September 30, 2008 and December 31, 2008, respectively, due to lower oil and gas prices on those dates.

Liquidity and Capital Resources

Cash decreased by $3,670,354 during the year ended December 31, 2009. Cash was utilized primarily for drilling and completion costs and cash distributions to partners. Capital requirements in the future are expected to be paid with remaining cash on hand. Management of MD believes that funds are sufficient to complete the wells for which funds have been committed. Specifically, it is anticipated that the Partnership will have completed drilling all of its wells by June 30, 2010. 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.

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 using the oil and gas pricing guidelines established by the Securities and Exchange Commission, year-end development and production costs and a 10 percent annual discount rate.

In December 2008, the SEC issued its final rule for Modernization of Oil and Gas Reporting. Pursuant to this rule the SEC adopted revisions to its oil and gas reporting disclosures effective for annual reports on Form 10-K for fiscal years ending on or after December 31, 2009. The revisions are intended to provide investors with a more meaningful and comprehensive understanding of oil and gas reserves, which should help investors evaluate the relative value of oil and gas entities. In the three decades that have passed since the original adoption of oil and gas disclosure items, there have been significant changes in the oil and gas industry. These revisions are designed to modernize and update the oil and gas disclosure requirements to align them with current practices and changes in technology.

The new rules include provisions that permit the use of new technologies to determine proved reserves. The requirements require entities to report any third party that is relied upon to prepare or audit reserve estimates. In addition, the new rules require that oil and gas reserves be reported and the full cost ceiling value calculated using average first-of-the-month natural gas and oil prices during the twelve month period ending in the reporting period, compared to prices at period end under prior SEC rules. Under the prior SEC rules, DD&A expense for the year ended December 31, 2009 would have been $3,746,293, with a corresponding net loss of $6,695,622 as compared to $3,784,362 DD&A expense and a net loss of $6,733,691 under the new rules. There would be no cost ceiling write-down differences, as no write-downs occurred after the rule change effective date. Under the prior SEC rules, reserve valuation at December 31, 2009 would be 385,234 barrels of oil and 17,109,756 mcf of gas, as compared to 371,642 barrels and 15,940,653 mcf under the new rules.

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 Natural Gas and Oil Reporting. In January 2009, the SEC issued revisions to the natural gas and oil reporting disclosures, “Modernization of Oil and Gas Reporting, Final Rule” (the “Final Rule”). In January 2010, the FASB updated its oil and gas estimation and disclosure requirements to align its requirements with the SEC’s modernized oil and gas reporting rules, which are described above. The update amends the definition of proved reserves to use the average of first-day-of-the-month prices during the twelve months preceding the end of the reporting period, adds definitions used in estimating and disclosing proved oil and natural gas quantities and expands the disclosures required for equity-method investments. The update must be applied prospectively as a change in accounting principle that is inseparable from a change in accounting estimate and is effective for entities with annual reporting periods ending on or after December 31, 2009. The Partnership adopted the new standards effective December 31, 2009. See the notes to the financial statements for disclosures regarding natural gas and oil reserves.

FASB Accounting Standards Codification and the Hierarchy of Generally Accepted Accounting Principles. In June 2009, the Financial Accounting Standards Board (“FASB”) issued guidance on the accounting standards codification and the hierarchy of generally accepted accounting principles. The accounting standards codification is intended to be the source of authoritative US GAAP and reporting standards as issued by the FASB. Its primary purpose is to improve clarity and use of existing standards by grouping authoritative literature under common topics. The accounting standards codification is effective for financial statements issued for interim and annual periods ending after September 15, 2009. The Partnership now describes the authoritative guidance used within the footnotes but no longer uses numerical references. The accounting standards codification does not change or alter existing US GAAP, and there has been no expected impact on the Partnership’s financial position, results of operations or cash flows.

Asset Retirement Obligations

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

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

A reconciliation of the Partnership’s liability for well plugging and abandonment costs for the years ended December 31, 2009 and December 31, 2008 is as follows:


	2009			2008
Balance, beginning of period	$	352,147		$	56,158
Liabilities incurred		—			283,966
Liabilities reduced		(2,007	)		(1,629	)
Accretion expense		24,098			13,652


Balance, end of period	$	374,238		$	352,147

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, some of which will be included in the full cost pool pursuant to Rule 4-10(c)(2) of Regulation S-X. Reimbursement to MOC for operator charges totaled $626,521 and $2,498,108 for the years ended December 31, 2009 and 2008, 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 of $490,000 were allocated to the Partnership for each of the years ended December 31, 2009 and December 31, 2008. 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, $397,830 and $406,166 were allocated to the Partnership during the years ended December 31, 2009 and 2008, 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.

ITEM 7A.

Quantitative and Qualitative Disclosures about Market Risk

Not required under Regulation S-K, Item 305 for smaller reporting companies.

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”.

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, 2009. 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, 2009 or in other factors which have materially affected, or are reasonably likely to materially affect the internal controls over financial reporting.

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 of December 31, 2009	Position
Curtis W. Mewbourne	74	President and Director

J. Roe Buckley	47	Executive Vice President and Chief Financial Officer

Alan Clark	57	Treasurer and Controller

Michael F. Shepard	63	Secretary and General Counsel

Dorothy M. Cuenod	49	Assistant Secretary and Director

Ruth M. Buckley	48	Assistant Secretary and Director

Julie M. Greene	46	Assistant Secretary and Director

Curtis W. Mewbourne, age 74, 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 44 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 47, 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.

Alan Clark, age 57, 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 63, 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 49 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 48, 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 46, 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.

ITEM 12.

Security Ownership of Certain Beneficial Owners and Management

(a) Beneficial owners of more than five percent


Title of Class	Name of Beneficial Owner	Amount and Nature of Beneficial Owner	Percent of Class
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 years ended December 31, 2009 and 2008:

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 2009 and 2008 are set forth below:

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	20

		Balance sheets as of December 31, 2009 and 2008	21

		Statements of operations for the years ended December 31, 2009 and 2008	22

		Statements of changes in partners’ capital for the years ended December 31, 2009 and 2008	23

		Statements of cash flows for the years ended December 31, 2009 and 2008	24

		Notes to financial statements	25

	2.	Financial statement schedules

		Not required for smaller reporting companies

	3.	Exhibits

		The exhibits listed on the accompanying index are filed or incorporated by reference as part of this annual report.

(b)	Reports on Form 8-K

		None.

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 Corporation
		Managing General Partner

By:		/s/ Curtis W. Mewbourne
		Curtis W. Mewbourne
		President 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, 2010
Curtis W. Mewbourne

/s/ J. Roe Buckley	Executive Vice President	March 31, 2010
J. Roe Buckley	Chief Financial Officer

/s/ Alan Clark	Treasurer and Controller	March 31, 2010
Alan Clark

/s/ Dorothy M. Cuenod	Director	March 31, 2010
Dorothy M. Cuenod

/s/ Ruth M. Buckley	Director	March 31, 2010
Ruth M. Buckley

/s/ Julie M. Greene	Director	March 31, 2010
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.

MEWBOURNE ENERGY PARTNERS 07-A, L.P.

FINANCIAL STATEMENTS

WITH REPORT OF INDEPENDENT REGISTERED ACCOUNTING FIRM

For the years ended December 31, 2009 and 2008

Report of Independent Registered Public 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, 2009 and 2008 and the related consolidated statements of operations, changes in partners’ capital and cash flows for each of the two years in the period ended December 31, 2009. 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 audits included consideration of internal control over financial reporting as a basis for designing audit procedures that are appropriate in the circumstances, but not for the purpose of expressing an opinion on the effectiveness of the 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, 2009 and 2008, and the results of its operations and its cash flows for each of the two years in the period ended December 31, 2009, in conformity with accounting principles generally accepted in the United States of America.

As discussed in Note 1 to the financial statements, during 2009 the Partnership changed its reserve estimates and related disclosures as a result of adopting new oil and natural gas reserve estimation and disclosure requirements.

/s/ BDO Seidman, LLP

Dallas, Texas

March 31, 2010

MEWBOURNE ENERGY PARTNERS 07-A, L.P.

BALANCE SHEETS

December 31, 2009 and 2008


	2009			2008
ASSETS

Cash and cash equivalents	$	282,559		$	3,952,913
Accounts receivable, affiliate		2,170,941			4,154,134
Accounts receivable, other		—			960

Total current assets		2,453,500			8,108,007


Oil and gas properties at cost, full-cost method		65,414,636			64,317,421
Less accumulated depreciation, depletion, amortization and impairment		(44,152,582	)		(26,766,704	)

		21,262,054			37,550,717


Total assets	$	23,715,554		$	45,658,724


LIABILITIES AND PARTNERS’ CAPITAL

Accounts payable, affiliate	$	291,270		$	72,841

Total current liabilities		291,270			72,841


Asset retirement obligation		374,238			352,147

Partners’ capital
General partners		—			42,461,555
Limited partners		23,050,046			2,772,181


Total partners’ capital		23,050,046			45,233,736


Total liabilities and partners’ capital	$	23,715,554		$	45,658,724

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

MEWBOURNE ENERGY PARTNERS 07-A, L.P.

STATEMENTS OF OPERATIONS

For the years ended December 31, 2009 and 2008


	2009			2008
Revenues and other income:
Oil sales	$	3,513,731		$	8,125,298
Gas sales		9,652,557			20,853,345
Interest income		1,426			629,007

Total revenues and other income		13,167,714			29,607,650


Expenses:
Lease operating expense		1,281,041			1,164,885
Production taxes		739,205			1,673,527
Administrative and general expense		471,183			478,899
Depreciation, depletion, and amortization		3,784,362			7,864,277
Cost ceiling write-down		13,601,516			18,323,915
Asset retirement obligation accretion		24,098			13,652

Total expenses		19,901,405			29,519,155


Net income (loss)	$	(6,733,691	)	$	88,495


Allocation of net income (loss):
General partners	$	(10,992,279	)	$	83,071


Limited partners	$	4,258,588		$	5,423


Basic and diluted net income (loss) per partner interest (14,000 interests outstanding)	$	(480.98	)	$	6.32

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

MEWBOURNE ENERGY PARTNERS 07-A, L.P.

STATEMENTS OF CHANGES IN PARTNERS’ CAPITAL

For the years ended December 31, 2009 and 2008


	General Partners			Limited Partners			Total
Balance at December 31, 2007	$	62,208,822		$	4,061,419		$	66,270,241

Cash distributions		(19,830,338	)		(1,294,662	)		(21,125,000	)
Net income		83,071			5,424			88,495


Balance at December 31, 2008		42,461,555			2,772,181			45,233,736

Cash distributions		(4,717,039	)		(10,732,960	)		(15,449,999	)
Net income (loss)		(10,992,279	)		4,258,588			(6,733,691	)
Conversion of general partner interests to limited partner interests		(26,752,237	)		26,752,237			—


Balance at December 31, 2009	$	—		$	23,050,046		$	23,050,046


Distribution amount per partnership unit for the year ended December 31, 2008							$	1,508.93


Distribution amount per partnership unit for the year ended December 31, 2009							$	1,103.57

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

MEWBOURNE ENERGY PARTNERS 07-A, L.P.

STATEMENTS OF CASH FLOWS

For the years ended December 31, 2009 and 2008


	2009			2008
Cash flows from operating activities:
Net income (loss)	$	(6,733,691	)	$	88,495
Adjustments to reconcile net income (loss) to net cash provided by operating activities:
Depreciation, depletion, and amortization		3,784,362			7,864,277
Cost ceiling write-down		13,601,516			18,323,915
Asset retirement obligation accretion		24,098			13,652
Changes in operating assets and liabilities:
Accounts receivable, affiliate		1,983,193			(2,728,833	)
Accounts receivable, other		960			199,965
Accounts payable, affiliate		218,429			(918,673	)

Net cash provided by operating activities		12,878,867			22,842,798


Cash flows from investing activities:
Purchase and development of oil and gas properties		(1,099,222	)		(49,676,420	)
Prepaid well costs		—			8,959,712

Net cash used in investing activities		(1,099,222	)		(40,716,708	)


Cash flows from financing activities:
Cash distributions to partners		(15,449,999	)		(21,125,000	)

Net cash used in financing activities		(15,449,999	)		(21,125,000	)


Net decrease in cash and cash equivalents		(3,670,354	)		(38,998,910	)
Cash and cash equivalents, beginning of period		3,952,913			42,951,823


Cash and cash equivalents, end of period	$	282,559		$	3,952,913


Supplemental Cash Flow Information:
Non-cash changes to oil & gas properties related to asset retirement obligation liabilities	$	(2,007	)	$	282,337

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

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. During 2009 all general partner equity interests were converted to limited partner equity 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, 2009 all capitalized costs were subject to amortization. Proceeds from the sale or other disposition of properties are credited to the full cost pool. Gains and losses are not recognized unless such adjustments would significantly alter the relationship between capitalized costs and the proved oil and gas reserves. Capitalized costs are subject to a quarterly ceiling test that limits such costs to the aggregate of the present value of future net cash flows of proved reserves and the lower of cost or fair value of unproved properties. There was a cost ceiling write-down of $13,601,516 at March 31, 2009 due to lower oil and gas prices on that date. There were cost ceiling write-downs of $8,077,590 and $10,246,325 at September 30, 2008 and December 31, 2008, respectively, due to lower oil and gas prices on those dates.

The new rules include provisions that permit the use of new technologies to determine proved reserves. The requirements require entities to report any third party that is relied upon to prepare or audit reserve estimates. In addition, the new rules require that oil and gas reserves be reported and the full cost ceiling value calculated using average first-of-the-month natural gas and oil prices during the twelve month period ending in the reporting period, compared to prices at period end under prior SEC rules. These revisions and requirements affect the comparability between reporting periods for reserve volume and value estimates, full cost pool write-down calculations and the calculation of depreciation, depletion and amortization of oil and gas assets.

Under the prior SEC rules, DD&A expense for the year ended December 31, 2009 would have been $3,746,293, with a corresponding net loss of $6,695,622 as compared to $3,784,362 DD&A expense and a net loss of $6,733,691 under the new rules. There would be no cost ceiling write-down differences, as no write-downs occurred after the rule change effective date. Adopting the new rules also had an effect on the net proved oil and gas reserves presented in Note 3.

New Accounting Pronouncements

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.

Fair Value of Financial Instruments

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

Asset Retirement Obligations

The Partnership has recognized an estimated liability for future plugging and abandonment costs. 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 years ended December 31, 2009 and December 31, 2008 is as follows:


	2009			2008
Balance, beginning of period	$	352,147		$	56,158
Liabilities incurred		—			283,966
Liabilities reduced		(2,007	)		(1,629	)
Accretion expense		24,098			13,652


Balance, end of period	$	374,238		$	352,147

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, 2009 and 2008, no material gas imbalances between the Partnership and other working interest owners existed.

Substantially all of the Partnership’s accounts receivable result from oil and natural gas sales to third parties in the oil and natural gas industry. This concentration of customers may impact the Partnership’s overall credit risk in that these entities may be similarly affected by changes in economic and other conditions. Historically, the Partnership has not experienced significant credit losses on such receivables. No bad debt expense was recorded in 2009 or 2008. The Partnership cannot ensure that such losses will not be realized in the future.

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 $17,691,987 and $32,919,185 at December 31, 2009 and 2008, respectively.

2. Organization and Related Party Transactions:

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. Management fees of $490,000 were allocated to the Partnership for each of the years ended December 31, 2009 and December 31, 2008. The Partnership includes the management fee as part of the full cost pool pursuant to Rule 4-10(c)(2) of Regulation S-X.


	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)

3. Supplemental Oil and Gas Information (unaudited):

The tables presented below provide supplemental information about oil and natural gas exploration and production activities.

Costs Incurred and Capitalized Costs:

Costs incurred in oil and natural gas acquisition, exploration and development activities for the years ended December 31, 2009 and 2008 were:

Capitalized costs related to oil and natural gas acquisition, exploration and development activities for the years ended December 31, 2009 and 2008 were as follows:


	2009			2008
Cost of oil and natural gas properties at year-end:
Producing assets - Proved properties	$	65,078,707		$	63,979,485
Asset retirement obligation		335,929			337,936

Total capitalized cost		65,414,636			64,317,421
Accumulated depreciation, depletion, amortization and impairment		(44,152,582	)		(26,766,704	)

Net capitalized costs	$	21,262,054		$	37,550,717

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, Forrest A. Garb & Associates Inc., in accordance with guidelines established by the Securities and Exchange Commission and the FASB’s accounting standard. 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.

These reserve estimates have been prepared based on year-end prices and costs as of December 31, 2008 and the average first-of-the-month natural gas and oil prices for the twelve months ended December 31, 2009 and the year-end costs as of December 31, 2009. The prior rules required that reserve estimates be calculated using last-day-of –the-year pricing. Under those prior rules, reserve valuation at December 31, 2009 would be 385,234 barrels of oil and 17,109,756 mcf of gas, as compared to 371,642 barrels and 15,940,653 mcf under the new rules.

There have been no favorable or adverse events that have caused a significant change in estimated proved reserves since December 31, 2009. 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. All proved reserves are developed; therefore, the Partnership has no proved undeveloped properties for the years ended December 31, 2009 and 2008.


	Crude Oil and Condensate (MBbl)		Natural Gas (MMcf)
Proved Reserves:
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

Revisions to previous estimates	11		172
Extensions, discoveries and other additions	4		275
Production	(65	)	(2,155	)


Balance at December 31, 2009 (1)	372		15,941

(1)	All of these reserves are categorized as proved developed.

Technologies Used in Reserves Estimation

Proved reserves are those quantities of oil and natural gas, which, by analysis of geoscience and engineering data, can be estimated with reasonable certainty to be economically producible from a given date forward, from known reservoirs, and under existing economic conditions, operating methods, and government regulations. The term “reasonable certainty” implies a high degree of confidence that the quantities of oil technologies that an entity can use to establish reserves. The SEC now allows use of techniques that have been proved effective by actual production from projects in the same reservoir or an analogous reservoir or by other evidence using reliable technology that establishes reasonable certainty. Reliable technology is a grouping of one or more technologies (including computational methods) that have been field tested and has been demonstrated to provide reasonably certain results with consistency and repeatability in the formation being evaluated or in an analogous formation. To achieve reasonable certainty, our technical team employs technologies that have been demonstrated to yield results with consistency and repeatability. The technologies and economic data used in the estimation of our proved reserves may include, but are not limited to, empirical evidence through drilling results and well performance, well logs, geologic maps and available downhole and production data, seismic data, well test data and reservoir simulation modeling.

MEWBOURNE ENERGY PARTNERS 07-A, L.P.

INDEX TO EXHIBITS

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


EXHIBIT NUMBER		DESCRIPTION
3.1		Form of Certificate of Limited Partnership (filed as Exhibit 3.1 to Form 10 and incorporated herein by reference)

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

4.1		Form of Agreement of Partnership (filed as Exhibit 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

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

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