Mewbourne Energy Partners 04-a 10-Q 2008 Q2 Quarterly report

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, 2008

OR

¨ 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. 333-113340

MEWBOURNE ENERGY PARTNERS 04-A, L.P.

Delaware	20-0718858
(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    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 in Rule 12b-2 of the Exchange Act. (Check one):

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

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

MEWBOURNE ENERGY PARTNERS 04-A, L.P.

INDEX

	Page No.
Part 1 - Financial Information
Item 1.Financial Statements
Condensed Balance Sheets - June 30, 2008 (Unaudited) and December 31, 2007	3
Condensed Statements of Operations (Unaudited) - For the three months ended June  30, 2008 and 2007 and the six months ended June 30, 2008 and 2007	4
Condensed Statements of Cash Flows (Unaudited) - For the six months ended June 30, 2008 and 2007	5
Condensed Statement of Changes In Partners’ Capital (Unaudited) - For the six months ended June 30, 2008	6
Notes to Condensed Financial Statements	7
Item 2.Management’s Discussion and Analysis of Financial Condition and Results of Operations	10
Item 3.Quantitative and Qualitative Disclosures about Market Risk	13
Item 4.Disclosure Controls and Procedures	13
Part II - Other Information
Item 1.Legal Proceedings	14
Item 6.Exhibits and Reports on Form 8-K	14

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MEWBOURNE ENERGY PARTNERS 04-A, L.P.

Part I - Financial Information

Item 1. Financial Statements

CONDENSED BALANCE SHEETS

JUNE 30, 2008 AND DECEMBER 31, 2007

	June 30, 2008			December 31, 2007
	(Unaudited)
ASSETS
Cash	$	161,634		$	2,022
Accounts receivable, affiliate		1,236,667			966,131
Total current assets		1,398,301			968,153
Oil and gas properties at cost, full-cost method		29,902,512			29,910,652
Less accumulated depreciation, depletion, amortization and impairment		(18,299,469	)		(17,798,283	)
		11,603,043			12,112,369
Total assets	$	13,001,344		$	13,080,522
LIABILITIES AND PARTNERS’ CAPITAL
Accounts payable, affiliate	$	153,647		$	426,388
Total current liabilities		153,647			426,388
Asset retirement obligation		400,799			405,682
Partners’ capital		12,446,898			12,248,452
Total liabilities and partners’ capital	$	13,001,344		$	13,080,522

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

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MEWBOURNE ENERGY PARTNERS 04-A, L.P.

CONDENSED STATEMENTS OF OPERATIONS

For the three months ended June 30, 2008 and 2007 and

the six months ended June 30, 2008 and 2007

(Unaudited)

	Three Months Ended June 30,				Six Months Ended June 30,
	2008		2007		2008		2007
Revenues and other income
Oil and gas sales	$	1,840,618	$	2,005,231	$	3,542,683	$	3,847,938
Interest income		473		902		755		2,387
Total revenues and other income		1,841,091		2,006,133		3,543,438		3,850,325
Expenses
Lease operating expense		131,710		134,473		298,549		249,048
Production taxes		69,280		160,240		205,252		306,844
Administrative and general expense		93,049		75,872		150,478		133,479
Depreciation, depletion, and amortization		230,108		385,935		501,186		760,525
Asset retirement obligation accretion		3,297		3,668		7,151		7,335
Total expenses		527,444		760,188		1,162,616		1,457,231
Net income	$	1,313,647	$	1,245,945	$	2,380,822	$	2,393,094
Basic and diluted net income per limited partner interest (30,000 interests outstanding)	$	43.79	$	41.53	$	79.36	$	79.77

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

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MEWBOURNE ENERGY PARTNERS 04-A, L.P.

CONDENSED STATEMENTS OF CASH FLOWS

For the six months ended June 30, 2008 and 2007

(Unaudited)

	Six Months Ended
	June 30,
	2008			2007
Cash flows from operating activities:
Net income	$	2,380,822		$	2,393,094
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation, depletion, and amortization		501,186			760,525
Asset retirement obligation accretion		7,151			7,335
Changes in operating assets and liabilities:
Accounts receivable, affiliate		(270,536	)		1,493
Accounts payable, affiliate		(272,741	)		218,279
Net cash provided by operating activities		2,345,882			3,380,726
Cash flows from investing activities:
Purchase and development of oil and gas properties		(3,894	)		(216,692	)
Net cash used in investing activities		(3,894	)		(216,692	)
Cash flows from financing activites:
Cash distributions to partners		(2,182,376	)		(3,168,730	)
Net cash used in financing activities		(2,182,376	)		(3,168,730	)
Net increase (decrease) in cash		159,612			(4,696	)
Cash, beginning of period		2,022			5,361
Cash, end of period	$	161,634		$	665
Supplemental Cash Flow Information:
Non-cash changes to oil & gas properties related to asset retirement obligation liabilities	$	(12,034	)

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

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MEWBOURNE ENERGY PARTNERS 04-A, L.P.

CONDENSED STATEMENT OF CHANGES IN PARTNERS’ CAPITAL

For the six months ended June 30, 2008

(Unaudited)

	Partners’ Capital
Balance at December 31, 2007	$	12,248,452
Cash distributions		(2,182,376	)
Net income		2,380,822
Balance at June 30, 2008	$	12,446,898

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

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MEWBOURNE ENERGY PARTNERS 04-A, L.P.

NOTES TO CONDENSED FINANCIAL STATEMENTS

(Unaudited)

1. Accounting Policies

Reference is hereby made to the Registrant’s Annual Report on Form 10-K for 2007, 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.

We adopted the provisions of Statement of Financial Accounting Standards No. 157, “Fair Value Measurements” on January 1, 2008. SFAS No. 157 defines fair value, establishes a market-based framework or hierarchy for measuring fair value, and expands disclosures about fair value measurements. SFAS No. 157 is applicable whenever another accounting pronouncement requires or permits assets and liabilities to be measured at fair value. SFAS No. 157 does not expand or require any new fair value measures. However, the application of this statement may change current practice. In February 2008, the FASB decided that an entity need not apply this standard to non-financial assets and liabilities that are recognized or disclosed at fair value in the financial statements on a nonrecurring basis until 2009. Accordingly, our adoption of this standard in 2008 was limited to financial assets and liabilities. The adoption of SFAS No. 157 did not impact our financial position, results of operations, or cash flows. We are still in the process of evaluating this standard with respect to its effect on non-financial assets and liabilities and therefore have not yet determined the impact that it will have on our financial statements upon full adoption in 2009. Non-financial assets and liabilities for which we have

not applied the provisions of SFAS No. 157 include those measured at fair value in impairment testing.

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2. Accounting for Oil and Gas Producing Activities

Mewbourne Energy Partners 04-A, L.P. (the “Registrant” or the “Partnership”), a Delaware limited partnership, is engaged primarily in oil and gas development and production in Texas, Oklahoma, and New Mexico, and was organized on January 27, 2004. The offering of limited and general partnership interests began June 10, 2004 as a part of an offering registered under the name Mewbourne Energy Partners 04-05 Drilling Program, (the “Program”), and concluded August 20, 2004, with total investor contributions of $30,000,000 originally being sold to 1,118 subscribers of which $27,235,000 were sold to 1,022 subscribers as general partner interests and $2,765,000 were sold to 96 subscribers as limited partner interests. During 2006, 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.

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, 2008 and 2007, 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.

3. 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 six months ended June 30, 2008 and the year ended December 31, 2007 is as follows:

	June 30, 2008			December 31, 2007
Balance, beginning of period	$	405,682		$	391,163
Liabilities reduced		(12,034	)		—
Accretion expense		7,151			14,519
Balance, end of period	$	400,799		$	405,682

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4. 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. 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 .7% of the subscriptions by the investor partners to the Partnership. Effective January 1, 2006 the Partnership has elected to include the management fee as part of the full cost pool pursuant to Rule 4-10(c)(6)(iii) and (iv) 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.

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

	Partnership		MD
Revenues:
Proceeds from disposition of depreciable and depletable properties	70	%	30	%
All other revenues	70	%	30	%
Costs and expenses:
Organization and offering costs (1)	0	%	100	%
Lease acquisition costs (1)	0	%	100	%
Tangible and intangible drilling costs (1)	100	%	0	%
Operating costs, reporting and legal expenses, general and administrative expenses and all other costs	70	%	30	%

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

The Partnership’s financial statements reflect its respective proportionate interest in the Program.

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

Liquidity and Capital Resources

Mewbourne Energy Partners 04-A, L.P. was formed January 27, 2004. The offering of limited and general partnership interests began June 10, 2004 and concluded August 20, 2004, with total investor contributions of $30,000,000. During 2006, 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 $1,244,654 at June 30, 2008.

During the six months ended June 30, 2008, the Partnership made cash distributions to the investor partners in the amount of $2,182,376 as compared to $3,168,730 for the six months ended June 30, 2007. The Partnership expects that cash distributions will continue during 2008 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.

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Results of Operations

Three months ended June 30, 2008 as compared to the three months ended June 30, 2007

Oil and gas revenues	Three Months Ended June 30,
	2008		2007
Oil and gas sales	$	1,840,618	$	2,005,231
Barrels produced		1,202		1,788
Mcf produced		192,193		268,165
Average price/bbl	$	121.35	$	60.77
Average price/mcf	$	8.82	$	7.07

As shown in the table above, total oil and gas sales decreased $164,613 (8.2%) for the three months ended June 30, 2008 as compared to the three months ended June 30, 2007.

Of this decrease, $71,139 and $669,929, respectively, were related to decreases in volumes of oil and gas sold. Volumes of oil and gas sold decreased 586 bbls of oil and 75,972 mcf of gas for the three months ended June 30, 2008 as compared to the three months ended June 30, 2007. This decrease in volumes of oil and gas sold was primarily due to normal declines in production.

These decreases were partially offset by increases of $108,323 and $468,132, respectively, related to increases in the average prices of oil and gas sold. Average oil and gas prices increased to $121.35 per bbl and $8.82 per mcf for the three months ended June 30, 2008 from $60.77 per bbl and $7.07 per mcf for the three months ended June 30, 2007.

Production taxes. Production taxes during the three month period ended June 30, 2008 decreased to $69,280 from $160,240 for the three month period ended June 30, 2007. This decrease was due to production tax credits for high cost gas wells and to the decreased revenue.

Lease operations. Lease operating expense during the three month period ended June 30, 2008 totaled $131,710 which was comparable to $134,473 for the three month period ended June 30, 2007.

Depreciation, depletion and amortization. Depreciation, depletion and amortization for the three month period ended June 30, 2008 decreased to $230,108 from $385,935 for the three month period ended June 30, 2007. This decrease was due to the decline in production volumes.

Administrative and general expense. Administrative and general expense for the three month period ended June 30, 2008 increased to $93,049 from $75,872 for the three month period ended June 30, 2007. The overall increase was due to increased administrative expenses allocable to the Partnership for the period ended June 30, 2008.

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Results of Operations

Six months ended June 30, 2008 as compared to the six months ended June 30, 2007

Oil and gas revenues	Six Months Ended June 30,
	2008		2007
Oil and gas sales	$	3,542,683	$	3,847,938
Barrels produced		2,495		3,777
Mcf produced		394,062		525,893
Average price/bbl	$	107.96	$	58.14
Average price/mcf	$	8.31	$	6.90

As shown in the table above, total oil and gas sales decreased $305,255 (7.9%) for the six months ended June 30, 2008 as compared to the six months ended June 30, 2007.

Of this decrease, $138,432 and $1,095,072, respectively, were related to decreases in volumes of oil and gas sold. Volumes of oil and gas sold decreased 1,282 bbls of oil and 131,831 mcf of gas for the six months ended June 30, 2008 as compared to the six months ended June 30, 2007. This decrease in the volumes of oil and gas sold was primarily due to normal declines in production.

These decreases were partially offset by increases of $188,182 and $740,067, respectively, related to increases in the average prices of oil and gas sold. Average oil and gas prices increased to $107.96 per bbl and $8.31 per mcf for the six months ended June 30, 2008 from $58.14 per bbl and $6.90 per mcf for the six months ended June 30, 2007.

Production taxes. Production taxes during the six month period ended June 30, 2008 decreased to $205,252 from $306,844 for the six month period ended June 30, 2007. This decrease was due to production tax credits for high cost gas wells and to decreased revenue.

Lease operations. Lease operating expense during the six month period ended June 30, 2008 increased to $298,549 from $249,048 for the six month period ended June 30, 2007 due to well repairs and workovers.

Depreciation, depletion and amortization. Depreciation, depletion and amortization for the six month period ended June 30, 2008 decreased $501,186 from $760,525 for the six month period ended June 30, 2007. This decrease was due to the decline in production volumes.

Administrative and general expense. Administrative and general expense for the six month period ended June 30, 2008 increased to $150,478 from $133,479 for the six month period ended June 30, 2007. The overall increase was due to increased administrative expenses allocable to the Partnership for the six month period ended June 30, 2008.

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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, 2008, a 10% change in the price received for natural gas production would have had an approximate $327,000 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, 2007 annual report on internal control over financial reporting, and for the quarter ended June 30, 2008, 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.

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Part II – Other Information

Item 1. Legal Proceedings

None.

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.

(b) Reports on Form 8-K

None.

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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 04-A, L.P.
	By:	Mewbourne Development Corporation
		Managing General Partner
Date: August 14, 2008
	By:	/s/ Alan Clark
		Alan Clark, Treasurer and Controller

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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.

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