UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

WASHINGTON, D.C. 20549

FORM 10-Q

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

For the quarterly period ended June 30, 2012

OR

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

For the transition period from___________________ to ___________________

Commission File No. 000-53959

MEWBOURNE ENERGY PARTNERS 09-A, L.P.

Delaware	26-4280211
(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

 Not Applicable

(Former name, former address and former fiscal year, if changed since last report)

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 Noo

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

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

Large accelerated filer	¨	Accelerated filer	¨
Non-accelerated filer	¨	Smaller reporting company	x
Do not check if smaller reporting company

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

MEWBOURNE ENERGY PARTNERS 09-A, L.P.
INDEX
Part 1  -  Financial Information				Page No.
	Item 1.  Financial Statements
		Condensed Balance Sheets -
			June 30, 2012  (Unaudited) and December 31, 2011	3
		Condensed Statements of Operations (Unaudited) -
			For the three months ended June 30, 2012 and 2011
			and the six months months ended June 30, 2012 and 2011	4
		Condensed Statements of Cash Flows (Unaudited) -
			For the six months ended June 30, 2012 and 2011	5
		Condensed Statement of Changes In Partners' Capital (Unaudited) -
			For the six months ended June 30, 2012	6
		Notes to Condensed Financial Statements		7
	Item 2.  Management's Discussion and Analysis of Financial Condition and Results of Operations			9
	Item 3.  Quantitative and Qualitative Disclosures about Market Risk			12
	Item 4.  Disclosure Controls and Procedures			12
Part II  -  Other Information
	Item 1.  Legal Proceedings			13
	Item 6.  Exhibits and Reports on Form 8-K			13

2

MEWBOURNE ENERGY PARTNERS 09-A, L.P.
Part I - Financial Information
Item 1.  Financial Statements
CONDENSED BALANCE SHEETS
	June 30, 2012			December 31, 2011
	(Unaudited)
ASSETS
Cash and cash equivalents	$	85,985		$	111,036
Accounts receivable, affiliate		2,106,841			3,081,175
Prepaid state taxes		8,859			79,151
Total current assets		2,201,685			3,271,362
Oil and gas properties at cost, full-cost method		63,561,217			63,146,647
Less accumulated depreciation, depletion,
and amortization		(16,187,722	)		(13,887,728	)
		47,373,495			49,258,919
Total assets	$	49,575,180		$	52,530,281
LIABILITIES AND PARTNERS' CAPITAL
Accounts payable, affiliate	$	332,843		$	372,650
Total current liabilities		332,843			372,650
Asset retirement obligation		1,011,315			995,271
Partners' capital		48,231,022			51,162,360
Total liabilities and partners' capital	$	49,575,180		$	52,530,281

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

3

MEWBOURNE ENERGY PARTNERS 09-A, L.P.
CONDENSED STATEMENTS OF OPERATIONS
(Unaudited)
	For the				For the
	Three Months Ended				Six Months Ended
	June 30,				June 30,
	2012		2011		2012		2011
Revenues and other income:
Oil sales	$	2,124,027	$	5,130,560	$	5,554,337	$	10,699,909
Gas sales		936,385		2,797,366		2,167,396		5,663,066
Interest income		9		347		420		1,180
Total revenues and other income		3,060,421		7,928,273		7,722,153		16,364,155
Expenses:
Lease operating expense		349,692		345,567		765,732		805,585
Production taxes		152,511		415,461		418,910		924,434
Administrative and general expense		177,627		241,074		350,091		636,132
Depreciation, depletion, and amortization		1,060,293		1,913,150		2,299,994		4,088,224
Asset retirement obligation accretion		9,927		9,900		19,854		20,117
Total expenses		1,750,050		2,925,152		3,854,581		6,474,492
Net income	$	1,310,371	$	5,003,121	$	3,867,572	$	9,889,663
Allocation of net income:
General partners	$	-	$	4,695,574	$	-	$	9,281,735
Limited partners	$	1,310,371	$	307,547	$	3,867,572	$	607,928
Basic and diluted net income per
partner interest
(13,242 interests outstanding)	$	98.96	$	377.82	$	292.07	$	746.84

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

4

MEWBOURNE ENERGY PARTNERS 09-A, L.P.
CONDENSED STATEMENTS OF CASH FLOWS
(Unaudited)
	For the
	Six Months Ended
	June 30,
	2012			2011
Cash flows from operating activities:
Net income	$	3,867,572		$	9,889,663
Adjustments to reconcile net income to net cash
provided by operating activities:
Depreciation, depletion, and amortization		2,299,994			4,088,224
Asset retirement obligation accretion		19,854			20,117
Changes in operating assets and liabilities:
Accounts receivable, affiliate		974,334			1,900,339
Prepaid state taxes		70,292			(2,085	)
Accounts payable, affiliate		(39,807	)		(706,637	)
Net cash provided by operating activities		7,192,239			15,189,621
Cash flows from investing activities:
Purchase and development of oil and gas properties		(418,380	)		(2,141,508	)
Net cash used in investing activities		(418,380	)		(2,141,508	)
Cash flows from financing activities:
Cash distributions to partners		(6,798,910	)		(14,535,000	)
Net cash used in financing activities		(6,798,910	)		(14,535,000	)
Net decrease in cash		(25,051	)		(1,486,887	)
Cash and cash equivalents, beginning of period		111,036			2,733,763
Cash and cash equivalents, end of period	$	85,985		$	1,246,876
Supplemental Cash Flow Information:
Non-cash changes to net oil & gas properties related to
asset retirement obligation liabilities	$	(3,810	)	$	28,262

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

5

MEWBOURNE ENERGY PARTNERS 09-A, L.P.
CONDENSED STATEMENT OF CHANGES IN PARTNERS' CAPITAL
For the six months ended June 30, 2012
(Unaudited)
	Total
Balance at December 31, 2011	$	51,162,360
Cash distributions		(6,798,910	)
Net income		3,867,572
Balance at June 30, 2012	$	48,231,022

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

6

MEWBOURNE ENERGY PARTNERS 09-A, L.P.

NOTES TO CONDENSED FINANCIAL STATEMENTS

(Unaudited)

1.           Description of Business

Mewbourne Energy Partners 09-A, L.P., (the “Registrant” or the “Partnership”), a Delaware limited partnership engaged primarily in oil and gas development and production in Texas, Oklahoma, and New Mexico, was organized on February 26, 2009. The offering of limited and general partner interests began May 1, 2009 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 28, 2009, with total investor contributions of $66,210,000 originally being sold to accredited investors of which $62,140,000 were sold to accredited investors as general partner interests and $4,070,000 were sold to accredited investors as limited partner interests. During 2011, all general partner equity interests were converted to limited partner equity interests. In accordance with the laws of the State of Delaware, Mewbourne Development Corporation (“MD”), a Delaware Corporation, has been appointed as the Partnership’s managing general partner. MD has no significant equity interest in the Partnership.

2.           Summary of Significant Accounting Policies

Reference is hereby made to the Registrant’s Annual Report on Form 10-K for 2011, which contains a summary of significant accounting policies followed by the Partnership in the preparation of its financial statements.  These policies are also followed in preparing the quarterly report included herein.

In the opinion of management, the accompanying unaudited financial statements contain all adjustments of a normal recurring nature necessary to present fairly our financial position, results of operations, cash flows and partners’ capital for the periods presented.  The results of operations for the interim periods are not necessarily indicative of the final results expected for the full year.

3.           Accounting for Oil and Gas Producing Activities

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 June 30, 2012 and 2011, 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 on the sale or other disposition of properties 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 no cost ceiling write-downs for the six months ended June 30, 2012 or 2011.

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4.           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 six months ended June 30, 2012 and the year ended December 31, 2011 is as follows:

	June 30,			December 31,
	2012			2011
Balance, beginning of period	$	995,271		$	939,821
Liabilities incurred		-			28,262
Liabilities reduced due to revisions		(3,810	)		(12,064	)
Accretion expense		19,854			39,252
Balance, end of period	$	1,011,315		$	995,271

5.Related Party Transactions

In accordance with the laws of the State of Delaware, Mewbourne Development Corporation (“MD”), a Delaware Corporation, has been appointed as the Partnership’s managing general partner. MD has no significant equity interest in the Partnership. 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 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. Services and 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 will pay to MD a management fee in the amount equal to .75% of the subscriptions by the investor partners to the Partnership.  The Partnership will include the management fee as part of the full cost pool pursuant to 4-10(c)(2) of Regulation S-X.

In accordance with the Partnership agreement, during any particular calendar year the total amount of administrative expenses allocated to the Partnership by MOC shall not exceed the greater of (a) 3.5% of the Partnership’s gross revenue from the sale of oil and 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.

8

The Partnership participates in oil and gas activities through the Program. The Partnership and MD are the parties to the Program, and the costs and revenues are allocated between them as follows:

	Partnership			MD
Revenues:
Proceeds from disposition of depreciable and depletable properties		75	%		25	%
All other revenues		75	%		25	%
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		75	%		25	%

(1)   Pursuant to the Program, MD must contribute 100% of organization and offering costs and lease acquisition costs which should approximate 15% of total capital costs. To the extent that organization and offering costs and lease acquisition costs are less than 15% of total capital costs, MD is responsible for tangible drilling costs until its share of the Program’s total capital costs reaches approximately 15%. The Partnership’s financial statements reflect its respective proportionate interest in the Program.

Item 2.           Management’s Discussion and Analysis of Financial Condition and Results of Operations

Liquidity and Capital Resources

Mewbourne Energy Partners 09-A, L.P. (“the Partnership”) was formed February 26, 2009. The offering of limited and general partnership interests began May 1, 2009 and concluded August 28, 2009, with total investor contributions of $66,210,000. During 2011, all general partner equity interests were converted to limited partner equity interests.

Future capital requirements and operations will be conducted with available funds generated from oil and gas activities.  No bank borrowing is anticipated.  The Partnership had net working capital of $1,868,842 at June 30, 2012.

During the six months ended June 30, 2012, the Partnership made cash distributions to the investor partners in the amount of $6,798,910 as compared to $14,535,000 for the six months ended June 30, 2011.  The Partnership expects that cash distributions will continue during 2012 as additional oil and gas revenues are sufficient to produce cash flows from operations.

The sale of crude oil and natural gas produced by the Partnership will be affected by a number of factors that are beyond the Partnership’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 Partnership.

9

Results of Operations

For the three months ended June 30, 2012 as compared to the three months ended June 30, 2011:

	Three Months Ended June 30,
	2012		2011
Oil sales	$	2,124,027	$	5,130,560
Barrels produced		24,643		52,511
Average price/bbl	$	86.19	$	97.70
Gas sales	$	936,385	$	2,797,366
Mcf produced		235,034		413,389
Average price/mcf	$	3.98	$	6.77

Oil and gas revenues.  As shown in the above table, total oil and gas sales decreased by $4,867,514, a 61.4% decline, for the three months ended June 30, 2012 as compared to the three months ended June 30, 2011.

Of this decline, revenues decreased by $2,401,996 and $710,574 from the decreases in the volumes of oil and gas sold, respectively. Volumes fell by 27,868 barrels (bbls) and 178,355 thousand cubic feet (mcf) for the three months ended June 30, 2012 as compared to the three months ending June 30, 2011. The decreases in the volumes sold were primarily due to normal declines in production, which in some wells were substantial.

Lease operations.  Lease operating expense during the three month period ended June 30, 2012 increased to $349,692 from $345,567 for the three month period ended June 30, 2011 due to more well repairs and workovers.

In addition, $604,537 and $1,150,407 were due to decreases in the average prices of oil and gas sold, respectively. The average prices fell to $86.19 from $97.70 per bbl and to $3.98 from $6.77 per mcf for the three months ending June 30, 2012 as compared to the three months ending June 30, 2011.

Production taxes.  Production taxes during the three month period ended June 30, 2012 decreased to $152,511 from $415,461 for the three month period ended June 30, 2011 due to lower overall oil and gas revenue.

Administrative and general expense.  Administrative and general expense for the three month period ended June 30, 2012 decreased to $177,627 from $241,074 for the three month period ended June 30, 2011 due to decreased administrative expenses allocable to the Partnership and lower general expense for reporting and legal costs.

Depreciation, depletion and amortization.  Depreciation, depletion and amortization for the three month period ended June 30, 2012 decreased to $1,060,293 from $1,913,150 for the three month period ended June 30, 2011 due to the decreased production volumes for the three month period ended June 30, 2012.

10

Results of Operations

For the six months ended June 30, 2012 as compared to the six months ended June 30, 2011:

	Six Months Months Ended June 30,
	2012		2011
Oil sales	$	5,554,337	$	10,699,909
Barrels produced		59,456		114,550
Average price/bbl	$	93.42	$	93.41
Gas sales	$	2,167,396	$	5,663,066
Mcf produced		486,167		874,583
Average price/mcf	$	4.46	$	6.48

Oil and gas revenues.  As shown in the above table, total oil and gas sales decreased by $8,641,242, a 52.8% decline, for the six months ended June 30, 2012 as compared to the six months ended June 30, 2011.

Of this decline, $5,146,842 and $1,731,609 were due to decreases in the volumes of oil and gas sold, respectively. The volumes sold decreased by 55,094 barrels (bbls) and 388,416 thousand cubic feet (mcf) for the six months ended June 30, 2012 as compared to the six months ended June 30, 2011. The decreases in volumes of oil and gas sold were primarily due to normal declines in production, which in some wells were substantial.
 

Also contributing to the decrease in revenue was $1,764,061 due to a decrease in the average price of gas sold. The average price fell to $4.46 from $6.48 per mcf for the six months ended June 30, 2012 as compared to the six months ended June 30, 2011.

These declines were partially offset by $1,270 due to an increase in the average price of oil sold. The average price rose to $93.42 from $93.41 per bbl for the six months ended June 30, 2012 as compared to the six months ended June 30, 2011.

Lease operations.  Lease operating expense during the six month period ended June 30, 2012 decreased to $765,732 from $805,585 for the six months ended June 30, 2011 due to fewer well repairs and workovers.

Production taxes.  Production taxes during the six month period ended June 30, 2012 decreased to $418,910 from $924,434 for the six month period ended June 30, 2011 due to lower overall oil and gas revenue.

Administrative and general expense.  Administrative and general expense for the six month period ended June 30, 2012 decreased to $350,091 from $636,132 for the six month period ended June 30, 2011 due to decreased administrative expenses allocable to the Partnership and lower general expense for reporting and legal costs.

Depreciation, depletion and amortization.  Depreciation, depletion and amortization for the six month period ended June 30, 2012 decreased to $2,299,994 from $4,088,224 for the six month period ended June 30, 2011 due to the decreased production volumes for the six month period ended June 30, 2012.

11

Item 3.          Quantitative and Qualitative Disclosures about Market Risk

1.    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.

2.    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 six months ended June 30, 2012, a 10% change in the price received for oil and gas production would have had an approximate $772,000 impact on revenue.

 3.    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 4.           Disclosure Controls and Procedures

MD maintains a system of controls and procedures designed to provide reasonable assurance as to the reliability of the financial statements and other disclosures included in this report, as well as to safeguard assets from unauthorized use or disposition.  MD’s Chief Executive Officer and Chief Financial Officer have evaluated the effectiveness of the design and operation of its disclosure controls and procedures with the assistance and participation of other members of management.  Based upon that evaluation, MD’s Chief Executive Officer and Chief Financial Officer concluded that its disclosure controls and procedures are effective for gathering, analyzing and disclosing the information the Partnership is required to disclose in the reports it files under the Securities Exchange Act of 1934 within the time periods specified in the SEC’s rules and forms. Since MD’s December 31, 2011 annual report on internal control over financial reporting, and for the quarter ended June 30, 2012, there have been no changes in MD’s internal controls or in other factors which have materially affected, or are reasonably likely to materially affect, the internal controls over financial reporting.

12

Part II –         Other Information

Item 1.           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 6.	Exhibits and Reports on Form 8-K
		(a)	Exhibits filed herewith
			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.
			101	The following materials from the Partnership's Quarterly Report on Form 10-Q for the quarter ended June 30, 2012 formatted in Extensible Business Reporting Language (XBRL): (i) the Condensed Balance Sheets, (ii) the Condensed Statements of Operations, (iii) the Condensed Statements of Cash Flows, (iv) the Condensed Statement of Changes in Partners’ Capital and (v) related notes.
		(b)	Reports on Form 8-K
				None.

13

SIGNATURES

Pursuant to the requirements of the Securities Exchange Act of 1934, the Partnership has duly caused this report to be signed on its behalf by the undersigned thereto duly authorized.

Mewbourne Energy Partners 09-A, L.P.
By:	Mewbourne Development Corporation
	Managing General Partner

Date: August 14, 2012	By:	/s/Alan Clark
		Alan Clark, Treasurer and Controller

14

INDEX TO EXHIBITS

EXHIBIT NUMBER	DESCRIPTION
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.
101	The following materials from the Partnership's Quarterly Report on Form 10-Q for the quarter ended June 30, 2012 formatted in Extensible Business Reporting Language (XBRL): (i) the Condensed Balance Sheets, (ii) the Condensed Statements of Operations, (iii) the Condensed Statements of Cash Flows, (iv) the Condensed Statement of Changes in Partners’ Capital and (v) related notes.