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UNITED STATES
SECURITIES AND EXCHANGE COMMISSION  FORM 10-Q [X]
    
    QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES
   EXCHANGE ACT OF 1934For the quarterly period ended September 30, 2004
 Or [   ]
    
    TRANSITION REPORT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT
OF 1934For 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
    
    (I.R.S. Employerincorporation or organization)
    
    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.
[X] Yes [   ] No




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Mewbourne Energy Partners 03-A, L.P. INDEX Page No.Part I  Financial InformationItem 1. Financial StatementsBalance Sheets - September 30, 2004 (Unaudited) and December 31, 2003
    
    
    3Statements of Operations (Unaudited) - For the three months ended September 30, 2004 and 2003 and the nine months ended September 30, 2004 and the period from February 19, 2003 (date of inception) through September 30, 2003
    
    
    4Statements of Cash Flows (Unaudited) - For the nine months ended September 30, 2004 and the period from February 19, 2003 (date of inception) through September 30, 2003
    
    
    5Statement of Changes In Partners Capital (Unaudited) - For the nine months ended September 30, 2004
    
    
    6Notes to Financial Statements
    
    
    7Item 2. Managements Discussion and Analysis of Financial Condition and Results of Operations
    
    
    9Item 4. Disclosure Controls and Procedures
    
    
    12Part II  Other InformationItem 1. Legal Proceedings
    
    
    12Item 6. Exhibits and Reports on Form 8-K
    
    
    13Certification of CEO Pursuant to Section 302Certification of CFO Pursuant to Section 302Certification of CEO Pursuant to Section 906Certification of CFO Pursuant to Section 906
  2




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Mewbourne Energy Partners 03-A, L.P. 
 Part I  Financial Information 
 Item 1. Financial Statements 
 BALANCE SHEETS
September 30, 2004 and December 31, 2003 September 30,
    
    December 31,2004
    
    2003(Unaudited)ASSETSCash and cash equivalents
    
    $
    389,122
    
    
    $
    5,551,936Accounts receivable, affiliate
    
    
    1,439,134
    
    
    
    307,252Total current assets
    
    
    1,828,256
    
    
    
    5,859,188Prepaid well costs
    
    
    
    
    
    
    4,128,424Oil and gas properties at cost,
full cost method
    
    
    18,424,583
    
    
    
    8,661,943Less accumulated depreciation,
depletion and amortization
    
    
    (2,320,270
    )
    
    
    (256,734
    )16,104,313
    
    
    
    8,405,209Total assets
    
    $
    17,932,569
    
    
    $
    18,392,821LIABILITIES AND PARTNERS CAPITALAccounts payable, affiliate
    
    $
    331,053
    
    
    $
    328,517Asset retirement obligation plugging liability
    
    
    363,123
    
    
    
    145,139Partners capitalGeneral partners
    
    
    15,425,494
    
    
    
    16,034,671Limited partners
    
    
    1,812,899
    
    
    
    1,884,494Total partners capital
    
    
    17,238,393
    
    
    
    17,919,165Total liabilities and partners capital
    
    $
    17,932,569
    
    
    $
    18,392,821
 The accompanying notes are an integral part of the financial statements. 3




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Mewbourne Energy Partners 03-A, L.P. 
 STATEMENTS OF OPERATIONS
For the three months ended September 30, 2004 and 2003, and
the nine months ended September 30, 2004 and the period from
February 19, 2003 (date of inception) through September 30, 2003
(Unaudited) Three Months Ended
    
    Nine Months EndedSeptember 30,
    
    September 30,2004
    
    2003
    
    2004
    
    2003Revenues and other income:Oil and gas sales
    
    $
    2,094,420
    
    
    $
    18,645
    
    
    $
    5,468,110
    
    
    $
    18,645Interest income
    
    
    3,222
    
    
    
    14,450
    
    
    
    19,289
    
    
    
    14,450Total revenues and other income
    
    
    2,097,642
    
    
    
    33,095
    
    
    
    5,487,399
    
    
    
    33,095Expenses:Lease operating expense
    
    
    136,132
    
    
    
    707
    
    
    
    282,514
    
    
    
    707Production taxes
    
    
    177,910
    
    
    
    1,787
    
    
    
    453,747
    
    
    
    1,787Administrative and general expense
    
    
    78,086
    
    
    
    2,627
    
    
    
    145,504
    
    
    
    2,627Depreciation, depletion, and amortization
    
    
    817,222
    
    
    
    11,071
    
    
    
    2,063,536
    
    
    
    11,071Cost ceiling write-down
    
    
    
    
    
    
    83,645
    
    
    
    
    
    
    
    83,645Asset retirement obligation accretion
    
    
    6,601
    
    
    
    554
    
    
    
    16,779
    
    
    
    554Net income (loss)
    
    $
    881,691
    
    
    $
    (67,296
    )
    
    $
    2,525,319
    
    
    $
    (67,296
    )Allocation of net income:General partners

    
    $
    788,967
    
    
    $
    (60,219
    )
    
    $
    2,259,740
    
    
    $
    (60,219
    )Limited partners
    
    $
    92,724
    
    
    $
    (7,077
    )
    
    $
    265,579
    
    
    $
    (7,077
    )Basic and diluted net income (loss)
per limited and general partner interest
(18,000 interests outstanding)
    
    $
    48.98
    
    
    $
    (3.74
    )
    
    $
    140.30
    
    
    $
    (3.74
    )
 The accompanying notes are an integral part of the financial statements. 4




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Mewbourne Energy Partners 03-A, L.P. 
 STATEMENTS OF CASH FLOWS
For the nine months ended September 30, 2004 and the period from
February 19, 2003 (date of inception) through September 30, 2003
(Unaudited) 2004
    
    2003Cash flows from operating activities:Net income (loss)
    
    $
    2,525,319
    
    
    $
    (67,296
    )Adjustment to reconcile net income (loss) to net cash
provided by operating activities:Depreciation, depletion, and amortization
    
    
    2,063,536
    
    
    
    11,071Cost ceiling write-down
    
    
    
    
    
    
    83,645Asset retirement obligation accretion
    
    
    16,779
    
    
    
    554Changes in operating assets and liabilities:Accounts receivable, affiliate
    
    
    (1,131,882
    )
    
    
    (18,645
    )Accounts payable, affiliate
    
    
    2,536
    
    
    
    1,786Net cash provided by operating activities
    
    
    3,476,288
    
    
    
    11,115Cash flows from investing activities:Additions to oil and gas properties
    
    
    (5,433,011
    )
    
    
    (1,906,099
    )Net cash used in investing activities
    
    
    (5,433,011
    )
    
    
    (1,906,099
    )Cash flows from financing activities:Capital contributions from partners
    
    
    
    
    
    
    18,000,000Cash distributions to partners
    
    
    (3,206,091
    )
    
    
    Net cash provided by (used in) financing activities
    
    
    (3,206,091
    )
    
    
    18,000,000Net increase (decrease) in cash and cash equivalents
    
    
    (5,162,814
    )
    
    
    16,105,016Cash and cash equivalents, beginning of period
    
    
    5,551,936
    
    
    
    Cash and cash equivalents, end of period
    
    $
    389,122
    
    
    $
    16,105,016
 The accompanying notes are an integral part of the financial statements. 5




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Mewbourne Energy Partners 03-A, L.P. 
 STATEMENT OF CHANGES IN PARTNERS CAPITAL
For the nine months ended September 30, 2004
(Unaudited) General
    
    LimitedPartners
    
    Partners
    
    TotalBalance at December 31, 2003
    
    $
    16,034,671
    
    
    $
    1,884,494
    
    
    $
    17,919,165Cash distributions
    
    
    (2,868,917
    )
    
    
    (337,174
    )
    
    
    (3,206,091
    )Net income
    
    
    2,259,740
    
    
    
    265,579
    
    
    
    2,525,319Balance at September 30, 2004
    
    $
    15,425,494
    
    
    $
    1,812,899
    
    
    $
    17,238,393
 The accompanying notes are an integral part of the financial statements. 6




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Mewbourne Energy Partners 03-A, L.P. 
 NOTES TO FINANCIAL STATEMENTS
(Unaudited) 1. Accounting Policies Reference is hereby made to the Partnerships Annual Report on Form 10-K for
2003, 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. 2. Accounting for Oil and Gas Producing Activities Mewbourne Energy Partners 03-A, L.P., (the Partnership), a Delaware limited
partnership formed on February 19, 2003, is engaged primarily in oil and gas
development and production in Texas, Oklahoma, and New Mexico. 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
Programs and concluded July 9, 2003, with total investor contributions of
$18,000,000. 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 September 30, 2004, approximately $0.2 million of
capitalized costs were excluded from amortization, while at September 30, 2003,
approximately $1.3 million of capitalized costs were excluded from
amortization. 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 that 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 In accordance with FAS 143, the Partnership has recognized an estimated
liability for future oil and gas well 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. 7




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A reconciliation of the Partnerships liability for well plugging and
abandonment costs for the nine months ended September 30, 2004 and the period
from February 19, 2003 (date of inception) through December 31, 2003, is as
follows: 2004
    
    2003Balance, beginning of period
    
    $
    145,139
    
    
    $
    Liabilities incurred
    
    
    201,205
    
    
    
    136,420Accretion expense
    
    
    16,779
    
    
    
    8,719Balance, end of period
    
    $
    363,123
    
    
    $
    145,139
 4. Related Party Transactions Mewbourne Development Corporation (MD) is managing general partner and
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. The Partnership reimburses MOC for supervision and other operator charges.
Services and operator charges are billed in accordance with the program and
partnership agreements. In general, during any particular calendar year the total amount of
administrative expenses allocated to the Partnership 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 an income tax
partnership, the Program. The Partnership and MD are parties to the Program
agreement. The costs and revenues of the Program are allocated to MD and the
Partnership as follows: Partnership
    
    MDRevenues: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 will
approximate 30% of total capital costs. To the extent that organization and
offering costs and lease acquisition costs are less that 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. 8




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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 03-A, L.P. (the Partnership) 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. The Partnership has acquired interests in oil and gas prospects for the purpose
of development drilling. At September 30, 2004, 61 wells had been drilled and
were productive and 7 wells were drilled and abandoned. 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 $1,497,203 at September 30, 2004. During the nine months ended September 30, 2004, the Partnership made cash
distributions to the investor partners in the amount of $3,206,091. No
distributions were made during the period from February 19, 2003 (date of
inception) through September 30, 2003. The Partnership expects that cash
distributions will continue during 2004 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. Results of Operations Three months ended September 30, 2004 as compared to the three months ended
September 30, 2003. Oil and gas revenues. Oil and gas revenues during the three months ended
September 30, 2004 totaled $2,094,420. Production volumes during the period
were approximately 4,009 bbls of oil and 368,820 mcf of gas at corresponding
average realized prices of $43.62 per bbl of oil and $5.20 per mcf of gas. Oil
and gas revenues during the three months ended September 30, 2003 totaled
$18,645. Production volumes during the period were approximately 4,194 mcf of
gas at a corresponding average realized price of $4.45 per mcf of gas. Oil and
gas revenues increased primarily due to additional wells being drilled and
completed in 2004. Interest income. Interest income was $3,222 during the three month period
ended September 30, 2004 as compared to $14,450 during the three month period
ended September 30, 2003. The decrease is primarily due to the decrease in
funds available for investment. 9




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Lease operations and production taxes. Lease operating expense during the
period ended September 30, 2004 totaled $136,132 as compared to $707 for the
period ended September 30, 2003. Production taxes during the period ended
September 30, 2004 total $177,910 compared to $1,787 for the period ended
September 30, 2003. Lease operating expense and production taxes increased as
additional wells were drilled and completed in 2004. Depreciation, depletion and amortization. Depreciation, depletion and
amortization for the three month period ended September 30, 2004 total $817,222
compared to $11,071 for the three month period ended September 30, 2003. The
increase is due to the additional wells drilled and producing and therefore
depleting their reserves. Administrative and general expense. Administrative and general expense for the
three month period ended September 30, 2004 total $78,086 compared to $2,627
for the period ended September 30, 2003. The partnership is charged overhead
based on 3.5% of gross oil and gas revenue by the operator. Thereby the
increase in administrative and general expenses is due to the increase in oil
and gas revenues. Nine months ended September 30, 2004 as compared to the period from February
19, 2003 (date of inception) through ended September 30, 2003. Oil and gas revenues. Oil and gas revenues during the nine months ended
September 30, 2004 totaled $5,468,110. Production volumes during the period
were approximately 15,639 bbls of oil and 923,886 mcf of gas at corresponding
average realized prices of $37.86 per bbl of oil and $5.28 per mcf of gas. Oil
and gas revenues during the period ended September 30, 2003 totaled $18,645.
Production volumes during the period were approximately 4,194 mcf of gas at a
corresponding average realized price of $4.45 per mcf of gas. Oil and gas
revenues increased primarily due to additional wells being drilled and
completed in 2004. Interest income. Interest income was $19,289 during the nine month period
ended September 30, 2004 as compared to $14,450 during the period ended
September 30, 2003. The decrease is primarily due to the decrease in funds
available for investment. Lease operations and production taxes. Lease operating expense during the
period ended September 30, 2004 totaled $282,514 as compared to $707 for the
period ended September 30, 2003. Production taxes during the period ended
September 30, 2004 total $453,747 compared to $1,787 for the period ended
September 30, 2003. Lease operating expense and production taxes increased as
additional wells were drilled and completed in 2004. Depreciation, depletion and amortization. Depreciation, depletion and
amortization for the nine month period ended September 30, 2004 total
$2,063,536 compared to $11,071 for the period ended September 30, 2003. The
increase is due to the additional wells drilled and producing and therefore
depleting their reserves. Administrative and general expense. Administrative and general expense for the
nine month period ended September 30, 2004 total $145,504 compared to $2,627
for the period ended September 30, 2003. The partnership is charged overhead
based on 3.5% of gross oil and gas revenue by the operator. Thereby the
increase in administrative and general expenses is due to the increase in oil
and gas revenues. 10




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Asset Retirement Obligation In accordance with FAS 143, the Partnership has recognized an estimated
liability for future oil and gas well plugging and abandonment costs (see Note
3). The estimated liability is based on historical experience and estimated
well lives. 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. A reconciliation of the Partnerships liability for well plugging and
abandonment costs for the nine months ended September 30, 2004 and the period
from February 19, 2003 (date of inception) through December 31, 2003, is as
follows: 2004
    
    2003Balance, beginning of period
    
    $
    145,139
    
    
    $
    Liabilities incurred
    
    
    201,205
    
    
    
    136,420Accretion expense
    
    
    16,779
    
    
    
    8,719Balance, end of period
    
    $
    363,123
    
    
    $
    145,139
 11




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Item 4. Disclosure Controls and Procedures Mewbourne Development Corporation (MDC), the Managing General Partner of the
Partnership, 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. Within 90 days prior to the filing of this
report, MDCs Chief Executive Officer and Chief Financial Officer have
evaluated the effectiveness of the design and operation of our disclosure
controls and procedures with the assistance and participation of other members
of management. Based upon that evaluation, MDCs Chief Executive Officer and
Chief Financial Officer concluded that our 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. There have been no significant changes in MDCs internal
controls or in other factors which could significantly affect internal controls
subsequent to the date MDC carried out its evaluation. 
 Part II  Other Information 
 Item 1. Legal Proceedings 1. Faulconer Resources 2000, LP, et al. v. Mewbourne Oil Company; No.
CV-2004-56 JWF; In the Fifth Judicial District Court, Eddy County New Mexico Plaintiffs Faulconer filed suit February 13, 2004 for Declaratory Judgment,
Tortious Interference with Leasehold Interest, Temporary Restraining Order and
Preliminary Injunction, seeking direct and consequential damages for breach of
duties, attorneys fees and punitive damages for tortious interference with
malice. Plaintiffs sought an injunction to deny Mewbourne Oil Company (MOC)
the opportunity to drill its La Huerta 30 Fee Com. No. 1-Y well, in which
the Partnership owns a working interest. Plaintiffs claim that MOC had no right to cause the wellbore of the La Huerta
well to traverse the underground rock strata in the SE/4 of Section 19 and the
NE/4 of Section 30 on its way to a bottom hole location in the SE/4 of Section
30, all in Township 21 South, Range 27 East, Eddy County, New Mexico.
Plaintiffs own no interest in the SE/4 of Section 30, but do own oil and gas
leasehold interests in the SE/4 of Section 19 and the NE/4 of Section 30,
subject to a current Farmout Agreement with MOC as Farmee and Plaintiffs as
Farmor. Plaintiffs claim the right to exclude MOCs La Huerta wellbore from
proceeding through the underground rock strata where Plaintiffs own oil and gas
leasehold interests. Plaintiffs assert MOCs wellbore would constitute a
permanent trespass, causing Plaintiffs irreparable injury and sought to enjoin
the drilling of the well. Plaintiffs claim MOCs filing of an application to
drill the well with regulatory bodies constituted a deliberate and malicious
interference with the contractual relationships between Plaintiffs and their
lessors. MOC believes it had the right to drill its La Huerta well. The bottom hole
location for the well is within a residential area nearby the city of Carlsbad,
New Mexico. A surface location for the well within the SE/4 of Section 30 was
not feasible or appropriate due to the proximity of residences and the
inability to construct and use a natural gas pipeline to gather and transport
natural gas produced by the well. Thus, MOC applied to the New Mexico Oil
Conservation Division and received a permit to drill a deviated well from a
surface location within the SE/4 of Section 19, for which MOC had acquired a

surface use easement and agreement. The wellbore traversed the SE/4 of
Section 19 and the NE/4 of Section 30 before entering MOCs leasehold area in
the S/2 of Section 30. After MOC notified Plaintiffs of MOCs plans,
Plaintiffs asserted that MOC did not have authority to execute its plans
without Plaintiffs consent and sued MOC. Plaintiffs refused to consent to
MOCs wellbore path unless MOC were to give Plaintiffs a substantial working
interest in the La Huerta well. Plaintiffs presented their application for preliminary injunction to the court
on March 3, 2004. MOC vigorously contested Plaintiffs claims. MOC believes
that Plaintiffs have no 12




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##### Table of Contents



right to block the drilling of the La Huerta well unless Plaintiffs can show
that their leasehold rights in the SE/4 of Section 19 and the NE/4 of Section
30 would be interfered with unreasonably by MOCs well. MOC further believes
Plaintiffs failed to prove such unreasonable interference would occur as a
result of the drilling of the La Huerta well. By Order dated March 17, 2004,
the court denied Plaintiffs application for injunctive relief, finding that
MOC would not be trespassing upon Plaintiffs oil and gas leasehold estates,
that MOCs operations would not interfere with operation of Plaintiffs oil and
gas leasehold interests, either surface or subsurface, and that Plaintiffs
would not suffer irreparable damage in any respect. Plaintiffs advised MOC
that they would appeal the courts ruling, but have not done so. MOC does not
believe the courts order will be reversed on appeal. Accordingly, MOC drilled
and completed the La Huerta 30 No. 1-Y well as a commercial gas well in
keeping with the courts order and to prevent drainage and protect its
correlative rights. The drilling and completion of the well proceeded without
incident or injury to Plaintiffs existing wells in the area. The plaintiffs
did not pursue their claims and the case has been dismissed. 
 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. 13




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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 03-A, L.P.By:
    
    Mewbourne Development CorporationManaging General PartnerDate: November 11, 2004By:
    
    /s/ Alan ClarkAlan Clark, Treasurer
 14




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INDEX TO EXHIBITS EXHIBITNUMBER
    
    DESCRIPTION31.1
    
    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.
 15