UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

WASHINGTON, D.C. 20549

FORM 10-Q

☒

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

For the quarterly period ended June 30, 2018

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. 333-113340-01

MEWBOURNE ENERGY PARTNERS 05-A, L.P.

Delaware		20-2306210
(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, a smaller reporting company, or an emerging growth 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  ☒
	Emerging growth company  ☐

If an emerging growth company, indicate by check mark if the registrant has elected not to use the extended transition period for complying with any new or revised financial accounting standards provided pursuant to Section 13(a) of the Exchange Act. ☐

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 05-A, L.P.

INDEX

Part I  -  Financial Information				Page No.
	Item 1.  Financial Statements
		Condensed Balance Sheets -		3
			June 30, 2018  (Unaudited) and December 31, 2017
		Condensed Statements of Operations (Unaudited) -		4
			For the three months ended June 30, 2018 and 2017
			and the six months ended June 30, 2018 and 2017
		Condensed Statement of Changes In Partners’ Capital (Unaudited) -		5
			For the six months ended June 30, 2018
		Condensed Statements of Cash Flows (Unaudited) -		6
			For the six months ended June 30, 2018 and 2017
		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

 

 

MEWBOURNE ENERGY PARTNERS 05-A, L.P.

Part I - Financial Information

Item 1. Financial Statements

CONDENSED BALANCE SHEETS

		June 30, 2018				December 31, 2017
		(Unaudited)
ASSETS
Cash		$	6,825			$	1,967
Accounts receivable, affiliate			162,559				208,566
Prepaid state taxes			2,521				1,317
Total current assets			171,905				211,850
Oil and gas properties at cost, full-cost method			30,229,104				30,227,917
Less accumulated depreciation, depletion, amortization
and cost ceiling write-downs			(28,865,040	)			(28,822,759	)
			1,364,064				1,405,158
Total assets		$	1,535,969			$	1,617,008
LIABILITIES AND PARTNERS’ CAPITAL
Accounts payable, affiliate		$	55,134			$	59,719
Total current liabilities			55,134				59,719
Asset retirement obligation			277,890				269,035
Total liabilities			333,024				328,754
Partners’ capital			1,202,945				1,288,254
Total liabilities and partners’ capital		$	1,535,969			$	1,617,008

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

 

MEWBOURNE ENERGY PARTNERS 05-A, L.P.

CONDENSED STATEMENTS OF OPERATIONS

(Unaudited)

		For the								For the
		Three Months Ended								Six Months Ended
		June 30,								June 30,
		2018				2017				2018				2017
Revenues:
Oil sales		$	131,228			$	97,101			$	343,636			$	156,333
Gas sales			109,045				196,139				256,915				310,712
Total revenues			240,273				293,240				600,551				467,045
Expenses:
Lease operating expense			111,160				109,753				213,499				180,813
Production taxes			16,856				20,517				43,475				30,854
Administrative and general expense			35,467				20,633				54,077				36,973
Depreciation, depletion, and amortization			18,088				26,592				42,281				45,792
Asset retirement obligation accretion			4,224				3,925				8,448				7,933
Total expenses			185,795				181,420				361,780				302,365
Net income		$	54,478			$	111,820			$	238,771			$	164,680

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

 

MEWBOURNE ENERGY PARTNERS 05-A, L.P.

CONDENSED STATEMENT OF CHANGES IN PARTNERS’ CAPITAL

For the six months ended June 30, 2018

(Unaudited)

		Partners’ Capital
Balance at December 31, 2017		$	1,288,254
Cash distributions			(324,080	)
Net income			238,771
Balance at June 30, 2018		$	1,202,945

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

MEWBOURNE ENERGY PARTNERS 05-A, L.P.

CONDENSED STATEMENTS OF CASH FLOWS

(Unaudited)

		Six Months Ended
		June 30,
		2018				2017
Cash flows from operating activities:
Net income		$	238,771			$	164,680
Adjustments to reconcile net income to net cash
provided by operating activities:
Depreciation, depletion, and amortization			42,281				45,792
Asset retirement obligation accretion			8,448				7,933
Changes in operating assets and liabilities:
Accounts receivable, affiliate			46,007				(80,878	)
Prepaid state taxes			(1,204	)			(968	)
Accounts payable, affiliate			(4,585	)			14,788
Net cash provided by operating activities			329,718				151,347
Cash flows from investing activities:
Development of oil and gas properties			(780	)			(354	)
Net cash used in investing activities			(780	)			(354	)
Cash flows from financing activities:
Cash distributions to partners			(324,080	)			(155,142	)
Net cash used in financing activities			(324,080	)			(155,142	)
Net increase (decrease) in cash			4,858				(4,149	)
Cash, beginning of period			1,967				14,000
Cash, end of period		$	6,825			$	9,851
Supplemental Cash Flow Information:
Change to net oil & gas properties related to asset retirement
obligation liabilities		$	407			$	(4,019	)

 

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

 

MEWBOURNE ENERGY PARTNERS 05-A, L.P.

NOTES TO CONDENSED FINANCIAL STATEMENTS

(Unaudited)

1.       Description of Business

Mewbourne Energy Partners 05-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 14, 2005. The offering of limited and general partnership interests began June 1, 2005 as a part of an offering registered under the name Mewbourne Energy Partners 04-05 Drilling Program, (the “Program”), and concluded July 29, 2005, with total investor contributions of $30,000,000 originally being sold to 1,128 subscribers of which $26,844,000 were sold to 998 subscribers as general partner interests and $3,156,000 were sold to 130 subscribers as limited partner interests. During 2007, 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 2017, 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. In preparing these financial statements, the Partnership has evaluated subsequent events for potential recognition and disclosure through the date the financial statements were issued.

Revenue Recognition

In May 2014, the Financial Accounting Standards Board (“FASB”) issued Accounting Standards Update (“ASU”) 2014-09, “Revenue from Contracts with Customers”, a comprehensive new revenue recognition standard. The Partnership has used the modified retrospective transition method to apply the effects of adopting this ASU, effective January 1, 2018, and has evaluated the impact of the ASU on its accounting policies, internal controls, and financial statements and related disclosures.

The Partnership has only non-operated working interests in oil and gas wells and receives monthly net revenue checks from the operator of these oil and gas wells. It recognizes revenue for oil and condensate when control transfers to the purchaser at a contractually specified delivery point at or near the wellhead at prevailing prices in accordance with arrangements which are customary in the oil and gas industry. Sales of gas applicable to the Partnership’s interest are recorded as revenue when the gas is metered and control is transferred pursuant to the gas sales contracts covering the Partnership’s interest in gas reserves.

The Partnership has reviewed its partnership, joint operating and marketing agreements as they relate to its non-operated working interests and this ASU, which includes provisions regarding revenues and expenses under a gross-versus-net presentation as it relates to principal vs agent relationship, and has evaluated the impact on the presentation of its revenues and expenses under this gross-versus-net presentation guidance. Based on its review of how information about revenue has been presented for other purposes, including disclosures presented outside the financial statements and information used by management for evaluating performance operations, the appropriate categories for the disaggregation of revenue are oil and gas sales, as presented in the Partnership’s financial statements and related disclosures.

 

Disaggregation of Revenue

The Partnership has identified two material revenue streams in its business: oil sales and natural gas sales. Revenue attributable to each of the Partnership’s identified revenue streams is disaggregated in the Condensed Statements of Operations.

Significant Judgments

Principal versus agent

In the case of the non-operating agreements, the operator is responsible for providing the goods due to its contractual obligations with the purchaser. Based on the joint operating and marketing agreement arrangements between the Partnership and operator, the Partnership does not take title to the product prior to the operator’s ultimate sale to a customer. The operator is responsible for fulfilling promises to provide specified goods and remitting proceeds back to the Partnership for the Partnership’s proportionate share of the total product sold. MOC, rather than the Partnership, is primarily responsible for fulfilling promises to provide specified goods. MOC, as the operator, enters into the sales contract with the third-party customers and directs all activities from the wellhead to the delivery point that make the commodity available to the customer; there is no agreement between the Partnership and the customers. In the event a production delay occurs as a result of, for example, well-equipment failure, MOC is responsible for correcting the issues preventing fulfillment of its promises to deliver product to its customers.

Transaction price allocated to remaining performance obligations

For the Partnership’s product sales, the Partnership has utilized the practical expedient in ASC 606 that states that it is not required to disclose the transaction price allocated to remaining performance obligations if the variable consideration is allocated entirely to a wholly unsatisfied performance obligation. Under the operator’s sales contracts, each unit of product represents a separate performance obligation; therefore, future volumes are wholly unsatisfied and disclosure of the transaction price allocated to remaining performance obligations is not required.

Contract balances

Under the Partnership’s joint operating and marketing agreements, the Partnership is entitled to consideration as production occurs at the wellhead and the value of such consideration is an estimate. Final amounts are only determined upon sale by the operator to the ultimate third-party customer, and recorded in “Accounts receivable, affiliate” in its balance sheet.

Based upon its assessments, the ASU has no effect on the timing of the Partnership’s revenue recognition or its financial position.

New Accounting Developments

In February 2016, the FASB issued ASU 2016-02, “Leases.” ASU 2016-02 requires the recognition of lease assets and lease liabilities by lessees for those leases currently classified as operating leases and makes certain changes to the way lease expenses are accounted for. This update is effective for fiscal years beginning after December 15, 2019, and interim periods within fiscal years beginning after December 15, 2020. This update should be applied using a modified retrospective approach, and early adoption is permitted. In January 2018, the FASB issued ASU 2018-01, which permits an entity to elect an optional transition practical expedient to not evaluate land easements that exist or expire before the Partnership’s adoption of Topic 842 and that were not previously accounted for as leases under Topic 840. The Partnership is currently evaluating the new guidance to determine the impact it will have on its financial statements.

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, 2018 and 2017, 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 no cost ceiling write-downs for the six months ended June 30, 2018 or 2017.

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. Depletion 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, 2018 and the year ended December 31, 2017 is as follows:

		2018				2017
Balance, beginning of period		$	269,035			$	256,573
Liabilities incurred			407				4,019
Liabilities reduced due to settlements and trades			—				(7,350	)
Accretion expense			8,448				15,793
Balance, end of period		$	277,890			$	269,035

5.       Related Party Transactions

In accordance with the laws of the State of Delaware, MD 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 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			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 2.

Management’s Discussion and Analysis of Financial Condition and Results of Operations

Liquidity and Capital Resources

Mewbourne Energy Partners 05-A, L.P. was formed February 14, 2005. The offering of limited and general partnership interests began June 1, 2005 and concluded July 29, 2005, with total investor contributions of $30,000,000. During 2007, 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 $116,771 at June 30, 2018.

During the six months ended June 30, 2018, the Partnership made cash distributions to the investor partners (including state tax payments for the benefit of investor partners) in the amount of $324,080 as compared to $155,142 for the six months ended June 3. Since inception, the Partnership has made distributions of $30,447,566, 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, 2018 as compared to the three months ended June 30, 2017:

		Three Months Ended June 30,
		2018				2017
Oil sales		$	131,228			$	97,101
Barrels produced			1,965				2,183
Average price/bbl		$	66.78			$	44.48
Gas sales		$	109,045			$	196,139
Mcf produced			44,299				70,192
Average price/mcf		$	2.46			$	2.79

Oil and gas revenues. As shown in the above table, total oil and gas sales decreased by $52,967, an 18.1% decline, for the three months ended June 30, 2018 as compared to the three months ended June 30, 2017.

Of this decrease, $14,559 and $63,737 were due to declines in the volumes of oil and gas sold, respectively. The volumes of oil and gas sold fell by 218 barrels (bbls) and by 25,893 thousand cubic feet (mcf) for the three months ended June 30, 2018 as compared to the three months ended June 30, 2017.

Also contributing to the decrease was $23,357 due to a decline in the average price of gas sold to $2.46 from $2.79 per mcf for the three months ended June 30, 2018 as compared to the three months ended June 30, 2017.

Partially offsetting these decreases was an increase of $48,686 from a rise in the average price of oil sold. The average price rose to $66.78 from $44.48 per bbl for the three months ended June 30, 2018 as compared to the three months ended June 30, 2017.

Lease operations. Lease operating expense during the three months ended June 30, 2018 increased to $111,160 from $109,753 for the three months ended June 30, 2017 due to more well repairs and workovers and overhead.

Production taxes. Production taxes during the three months ended June 30, 2018 decreased to $16,856 from $20,517 for the three months ended June 30, 2017. This was due to lower overall oil and gas revenue for the three months ended June 30, 2018.

Administrative and general expense. Administrative and general expense for the three months ended June 30, 2018 rose to $35,467 from $20,633 for the three months ended June 30, 2017 due to increased administrative expenses allocable to the Partnership.

Depreciation, depletion and amortization. Depreciation, depletion and amortization for the three months ended June 30, 2018 decreased to $18,088 from $26,592 for the three months ended June 30, 2017 due to the decrease in production and to the prior period cost ceiling write-downs that reduced the balance of the full cost pool subject to amortization

Results of Operations

For the six months ended June 30, 2018 as compared to the six months ended June 30, 2017:

		Six Months Ended June 30,
		2018				2017
Oil sales		$	343,636			$	156,333
Barrels produced			5,790				3,425
Average price/bbl		$	59.35			$	45.64
Gas sales		$	256,915			$	310,712
Mcf produced			101,187				111,530
Average price/mcf		$	2.54			$	2.79

Oil and gas revenues. As shown in the above table, total oil and gas sales rose by $133,506, a 28.6% increase, for the six months ended June 30, 2018 as compared to the six months ended June 30, 2017.

Of this increase, $140,363 was due to a rise in the volume of oil sold. The volume of oil sold rose by 2,365 barrels (bbls) for the six months ended June 30, 2018 as compared to the six months ended June 30, 2017. The increase in the volume sold was due to well payouts from farm outs.

Also contributing to the increase was $46,940 due to a rise in the average price of oil sold to $59.35 from $45.64 per bbl for the six months ended June 30, 2018 as compared to the six months ended June 30, 2017.

Partially offsetting these increases was a decrease of $27,536 from a decline in the average price of gas sold. The average price fell to $2.54 from $2.79 per thousand cubic feet (mcf) for the six months ended June 30, 2018 as compared to the six months ended June 30, 2017.

Also partially offsetting these increases was a decrease of $26,261 due to a decline in the volume of gas sold by 10,343 mcf.

Lease operations. Lease operating expense during the six months ended June 30, 2018 increased to $213,499 from $180,813 for the six months ended June 30, 2017 due to more well repairs and workovers and overhead.

Production taxes. Production taxes during the six months ended June 30, 2018 increased to $43,475 from $30,854 for the six months ended June 30, 2017. This was due to higher overall oil and gas revenue for the six months ended June 30, 2018.

Administrative and general expense. Administrative and general expense for the six months ended June 30, 2018 rose to $54,077 from $36,973 for the six months ended June 30, 2017 due to increased administrative expenses allocable to the Partnership.

Depreciation, depletion and amortization. Depreciation, depletion and amortization for the six months ended June 30, 2018 decreased to $42,281 from $45,792 for the six months ended June 30, 2017 due to prior period cost ceiling write-downs that reduced the balance of the full cost pool subject to amortization.

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, 2018, a 10% change in the price received for oil and gas production would have had an approximate $60,000 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, 2017 annual report on internal control over financial reporting, and for the quarter ended June 30, 2018, 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, 2018 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 05-A, L.P.
		By:	Mewbourne Development Corporation
			Managing General Partner

Date:      August 14, 2018

 

		By:	/s/ J. Roe Buckley
			J. Roe Buckley
			Chairman of the Board Executive Vice President Chief Financial Officer

 

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, 2018 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.