UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

WASHINGTON, D.C. 20549

 

FORM 10-Q

 

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

For the quarterly period ended June 30, 2016

 

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. 333-85994-01

 

MEWBOURNE ENERGY PARTNERS 03-A, L.P. 

 

Delaware		27-0055431
(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 ☒   No ☐

 

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

 

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

 

Indicate by check mark if the registrant is a shell company (as defined in Rule 12b-2 of the Exchange Act).

Yes ☐   No ☒

 

 

MEWBOURNE ENERGY PARTNERS 03-A, L.P.
INDEX
Part 1 –  Financial Information				Page No.
	Item 1.  Financial Statements
		Condensed Balance Sheets –
			June 30, 2016 (Unaudited) and December 31, 2015	3
		Condensed Statements of Operations (Unaudited) –
			For the three months ended June 30, 2016 and 2015
			and the six months ended June 30, 2016 and 2015	4
		Condensed Statement of Changes In Partners' Capital (Unaudited) –
			For the six months ended June 30, 2016	5
		Condensed Statements of Cash Flows (Unaudited) –
			For the six months ended June 30, 2016 and 2015	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

 

 

MEWBOURNE ENERGY PARTNERS 03-A, L.P.

 

Part I - Financial Information

 

Item 1.  Financial Statements

 

CONDENSED BALANCE SHEETS

 

		June 30, 2016				December 31, 2015
		(Unaudited)
ASSETS
Cash		$	2,150			$	4,775
Accounts receivable, affiliate			40,556				36,620
Prepaid state taxes			2,890				1,994
Total current assets			45,596				43,389
Oil and gas properties at cost, full-cost method			19,618,788				19,618,601
Less accumulated depreciation, depletion, amortization
and cost ceiling write-downs			(18,919,673	)			(18,721,720	)
			699,115				896,881
Total assets		$	744,711			$	940,270
LIABILITIES AND PARTNERS' CAPITAL
Accounts payable, affiliate		$	92,061			$	58,165
Total current liabilities			92,061				58,165
Asset retirement obligation			534,284				525,390
Partners' capital			118,366				356,715
Total liabilities and partners' capital		$	744,711			$	940,270

 

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

 

 

MEWBOURNE ENERGY PARTNERS 03-A, L.P.

 

CONDENSED STATEMENTS OF OPERATIONS

(Unaudited)

 

		For the								For the
		Three Months Ended								Six Months Ended
		June 30,								June 30,
		2016				2015				2016				2015
Revenues:
Oil sales		$	16,332			$	19,194			$	28,646			$	33,804
Gas sales			41,575				61,143				80,685				127,065
Total revenues			57,907				80,337				109,331				160,869
Expenses:
Lease operating expense			54,042				72,685				106,740				161,473
Production taxes			3,109				5,328				6,290				11,626
Administrative and general expense			16,967				16,983				24,603				27,606
Depreciation, depletion, and amortization			21,444				34,608				36,679				65,627
Cost ceiling write-down			139,281				107,267				164,474				107,267
Asset retirement obligation accretion			4,447				4,307				8,894				8,816
Total expenses			239,290				241,178				347,680				382,415
Net loss		$	(181,383	)		$	(160,841	)		$	(238,349	)		$	(221,546	)

    

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

 

 

MEWBOURNE ENERGY PARTNERS 03-A, L.P.

 

CONDENSED STATEMENT OF CHANGES IN PARTNERS' CAPITAL

For the six months ended June 30, 2016

(Unaudited)

 

		Partners' Capital
Balance at December 31, 2015		$	356,715
Net loss			(238,349	)
Balance at June 30, 2016		$	118,366

   

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

 

 

MEWBOURNE ENERGY PARTNERS 03-A, L.P.

 

CONDENSED STATEMENTS OF CASH FLOWS

(Unaudited)

  

		Six Months Ended
		June 30,
		2016				2015
Cash flows from operating activities:
Net loss		$	(238,349	)		$	(221,546	)
Adjustments to reconcile net loss to net cash
(used in) provided by operating activities:
Depreciation, depletion, and amortization			36,679				65,627
Cost ceiling write-down			164,474				107,267
Asset retirement obligation accretion			8,894				8,816
Plugging and abandonment cost paid from asset retirement obligation			(3,200	)			—
Changes in operating assets and liabilities:
Accounts receivable, affiliate			(3,936	)			36,374
Prepaid state taxes			(896	)			(921	)
Accounts payable, affiliate			33,896				18,976
Net cash (used in) provided by operating activities			(2,438	)			14,593
Cash flows from investing activities:
Proceeds from sale of oil and gas properties			—				3,901
Purchase and development of oil and gas properties			(187	)			—
Net cash (used in) provided by investing activities			(187	)			3,901
Cash flows from financing activities:
Cash distributions to partners			—				(25,783	)
Net cash used in financing activities			—				(25,783	)
Net decrease in cash			(2,625	)			(7,289	)
Cash, beginning of period			4,775				10,030
Cash, end of period		$	2,150			$	2,741
Supplemental Cash Flow Information:
Change to net oil & gas properties related to asset retirement
obligation liabilities		$	3,200			$	—

  

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

 

 

MEWBOURNE ENERGY PARTNERS 03-A, L.P.

 

NOTES TO CONDENSED FINANCIAL STATEMENTS

(Unaudited)

 

1. Description of Business

 

Mewbourne Energy Partners 03-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 February 19, 2003. The offering of limited and general partnership interests began May 16, 2003 as a part of an offering registered under the name Mewbourne Energy Partners 02-03 Drilling Program, (the “Program”), and concluded July 9, 2003, with total investor contributions of $18,000,000 originally being sold to 710 subscribers of which $16,107,005 were sold to 644 subscribers as general partner interests and $1,892,995 were sold to 66 subscribers as limited partner interests. During 2005, 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 2015, 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, 2016 and 2015, 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 estimated future net cash flows of proved reserves, computed using the 12-month unweighted average of first-day-of-the-month oil and natural gas prices, discounted at 10%, and the lower of cost or fair value of unproved properties. If unamortized costs capitalized exceed the ceiling, the excess is charged to expense in the period the excess occurs. There were cost ceiling write-downs totaling $164,474 and $107,267 for the six months ended June 30, 2016 and 2015, respectively.

 

 

4. Asset Retirement Obligations

 

The Partnership has recognized an estimated asset retirement obligation liability (ARO) 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, 2016 and the year ended December 31, 2015 is as follows:

 

		2016				2015
Balance, beginning of period		$	525,390			$	513,303
Liabilities reduced due to settlements			—				(5,260	)
Accretion expense			8,894				17,347
Balance, end of period		$	534,284			$	525,390

 

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 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.

 

 

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 (1)
Revenues:
Proceeds from disposition of depreciable and depletable properties			60	%			40	%
All other revenues			60	%			40	%
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			60	%			40	%

 

(1)

As noted above, pursuant to the Program, MD must contribute 100% of organization and offering costs and lease acquisition costs which should approximate 30% of total capital costs. To the extent that organization and offering costs and lease acquisition costs are less than 30% of total capital costs, MD is responsible for tangible drilling costs until its share of the Program's total capital costs reaches approximately 30%. 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 03-A, L.P. was formed February 19, 2003. The offering of limited and general partnership interests began May 16, 2003 and concluded July 9, 2003, with total investor contributions of $18,000,000. During 2005, all general partner equity interests were converted to limited partner equity interests.

 

The Partnership had negative net working capital of $46,465 at June 30, 2016. MOC has informed the Partnership that if cash flows are insufficient to fund its operating costs, MOC will not demand immediate payment of amounts owed to it.

 

The Partnership had reduced cash flows from operations for the six months ended June 30, 2016 due to the steep decline in oil and gas prices during the previous twelve months. Considering these reduced operating cashflows, the Partnership does not anticipate resuming distributions until oil and gas prices improve.

 

During the six months ended June 30, 2016, the Partnership made no cash distributions to the investor partners as compared to $25,783 for the six months ended June 30, 2015. Since inception, the Partnership has made distributions of $20,448,648, inclusive of state tax payments.

 

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.

 

 

Results of Operations

 

For the three months ended June 30, 2016 as compared to the three months ended June 30, 2015:

 

		Three Months Ended June 30,
		2016				2015
Oil sales		$	16,332			$	19,194
Barrels produced			431				372
Average price/bbl		$	37.89			$	51.60
Gas sales		$	41,575			$	61,143
Mcf produced			28,133				27,489
Average price/mcf		$	1.48			$	2.22

 

Oil and gas revenues. As shown in the above table, total oil and gas sales decreased by $22,430, a 27.9% decline, for the three months ended June 30, 2016 as compared to the three months ended June 30, 2015.

 

Of this decline, $5,098 and $20,520 were due to decreases in the average prices of oil and gas sold, respectively. The average price fell to $37.89 from $51.60 per barrel (bbl) and to $1.48 from $2.22 per thousand cubic feet (mcf) for the three months ended June 30, 2016 as compared to the three months ended June 30, 2015.

 

Slightly offsetting these declines were increases of $2,236 and $952 from increases in the volumes of oil and gas sold, respectively, by 59 bbls and 644 mcf.

 

Lease operations. Lease operating expense during the three month period ended June 30, 2016 decreased to $54,042 from $72,685 for the three month period ended June 30, 2015 due to fewer well repairs and workovers.

 

Production taxes. Production taxes during the three month period ended June 30, 2016 decreased to $3,109 from $5,328 for the three month period ended June 30, 2015. This was due to lower overall oil and gas revenue for the three month period ended June 30, 2016.

 

Depreciation, depletion and amortization. Depreciation, depletion and amortization for the three months ended June 30, 2016 decreased to $21,444 from $34,608 for the three months ended June 30, 2015 due to the prior period cost ceiling write-downs that reduced the balance of the full cost pool subject to amortization.

 

Cost ceiling write-down. There were cost ceiling write-downs of $139,281 and $107,267 for the three months ended June 30, 2016 and 2015, respectively. These were due to lower average oil and gas prices for the twelve months preceding the write-downs.

 

 

Results of Operations

 

For the six months ended June 30, 2016 as compared to the six months ended June 30, 2015:

 

		Six Months Ended June 30,
		2016				2015
Oil sales		$	28,646			$	33,804
Barrels produced			857				719
Average price/bbl		$	33.43			$	47.02
Gas sales		$	80,685			$	127,065
Mcf produced			52,966				54,319
Average price/mcf		$	1.52			$	2.34

 

Oil and gas revenues. As shown in the above table, total oil and gas sales decreased by $51,538, a 32.0% decline, for the six months ended June 30, 2016 as compared to the six months ended June 30, 2015.

 

Of this decline, $9,771 and $44,319 were due to decreases in the average prices of oil and gas sold, respectively. The average price fell to $33.43 from $47.02 per barrel (bbl) and to $1.52 from $2.34 per thousand cubic feet (mcf) for the six months ended June 30, 2016 as compared to the six months ended June 30, 2015.

 

Also contributing to the decline in sales was $2,061 due to a lower volume of gas sold by 1,353 mcf.

 

Slightly offsetting these declines was an increase of $4,613 from an increase in the volume of oil sold by 138 bbls.

 

Lease operations. Lease operating expense during the six month period ended June 30, 2016 decreased to $106,740 from $161,473 for the six month period ended June 30, 2015 due to fewer well repairs and workovers.

 

Production taxes. Production taxes during the six month period ended June 30, 2016 decreased to $6,290 from $11,626 for the six month period ended June 30, 2015. This was due to lower overall oil and gas revenue for the six month period ended June 30, 2016.

 

Administrative and general expense. Administrative and general expense for the six month period ended June 30, 2016 fell to $24,603 from $27,606 for the six month period ended June 30, 2015 due to decreased administrative expenses allocable to the Partnership.

 

Depreciation, depletion and amortization. Depreciation, depletion and amortization for the six months ended June 30, 2016 decreased to $36,679 from $65,627 for the six months ended June 30, 2015 due to the overall decrease in oil and gas production.

 

Cost ceiling write-down. There were cost ceiling write-downs totaling $164,474 and $107,267 for the six months ended June 30, 2016 and 2015, respectively. These were due to lower average oil and gas prices for the twelve months preceding the write-downs. 

 

  

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, 2016, a 10% change in the price received for oil and gas production would have had an approximate $11,000 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, 2015 annual report on internal control over financial reporting, and for the quarter ended June 30, 2016, 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.

 

 

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, 2016 formatted in Extensible Business Reporting Language (XBRL): (i) the Condensed Balance Sheets, (ii) the Condensed Statements of Operations, (iii) the Condensed Statement of Changes in Partners' Capital, (iv) the Condensed Statements of Cash Flows, and (v) related notes.
		(b)	Reports on Form 8-K
			None.

 

 

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 03-A, L.P.
	By:	Mewbourne Development Corporation
		Managing General Partner

 

Date:	August 15, 2016
		By:	/s/ Alan Clark
			Alan Clark, Treasurer and Controller

 

 

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, 2016 formatted in Extensible Business Reporting Language (XBRL): (i) the Condensed Balance Sheets, (ii) the Condensed Statements of Operations, (iii) the Condensed Statement of Changes in Partners' Capital, (iv) the Condensed Statements of Cash Flows, and (v) related notes.