MEWBOURNE ENERGY PARTNERS 01-A LP - 10-Q Quarterly Report

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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 September 30, 2003

or

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

For the transition period from to
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Commission File No. 333-57156

MEWBOURNE ENERGY PARTNERS 01-A, L.P.

Delaware 75-2926279
- ------------------------------ ----------------------
(State or jurisdiction of (I.R.S. Employer
incorporation or organization) Identification Number)

3901 South Broadway, Tyler, Texas 75701
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(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 or 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

MEWBOURNE ENERGY PARTNERS 01-A, L. P.

INDEX

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MEWBOURNE ENERGY PARTNERS 01-A, L. P.

Part I - Financial Information

Item 1. Financial Statements

BALANCE SHEETS
September 30, 2003 and December 31, 2002

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

3

MEWBOURNE ENERGY PARTNERS 01-A, L. P.

STATEMENTS OF INCOME (LOSS)
For the three months ended September 30, 2003 and 2002, and
the nine months ended September 30, 2003 and 2002
(Unaudited)

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

4

MEWBOURNE ENERGY PARTNERS 01-A, L. P.

STATEMENTS OF CASH FLOWS
For the nine months ended September 30, 2003 and 2002
(Unaudited)

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

5

MEWBOURNE ENERGY PARTNERS 01-A, L. P.

STATEMENT OF CHANGES IN PARTNERS' CAPITAL
For the nine months ended September 30, 2003
(Unaudited)

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

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MEWBOURNE ENERGY PARTNERS 01-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
2002, 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 01-A, L.P., (the "Partnership"), a Delaware limited
partnership formed on February 23, 2001, 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 June 12, 2001 as a part of an
offering registered under the name Mewbourne Energy Partners 01-02 Drilling
Programs and concluded August 28, 2001, with total investor contributions of
$15,000,000.

The Partnership follows the full-cost method of accounting for its oil and gas
activities. Under the full-cost method, all productive and nonproductive 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, 2003 and September 30, 2002 substantially all capitalized costs
were subject to 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 periodic 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

On January 1, 2003, the Partnership adopted Statement of Financial Accounting
Standard No. 143 ("FAS 143"), "Accounting for Asset Retirement Obligations."
This statement changes financial accounting and reporting obligations associated
with the retirement and disposal of long-lived assets, including the
Partnership's oil and gas properties, and the associated asset retirement 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

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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.

Upon adoption of FAS 143 on January 1, 2003, the Partnership recorded a
discounted liability of $297,742, increased the net full cost pool by $346,332
and recognized a one-time cumulative effect adjustment of $(48,590). The
increase in the net full cost pool included $182,214 for the reversal of
accumulated depreciation related to the inclusion of estimated salvage value of
equipment on the Partnership's oil and gas properties. Prior to the adoption of
FAS 143, the Partnership assumed salvage value approximated plugging and
abandonment costs and as a result was not included in the full cost pool.

A reconciliation of the Partnership's liability for well plugging and
abandonment costs for the nine months ended September 30, 2003, is as follows:

Balance upon adoption at January 1, 2003 $297,742
Liabilities incurred 9,895
Accretion expense 9,713
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Balance at September 30, 2003 $317,350
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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 01-A, L.P. (the "Partnership")was formed February 23,
2001. The offering of limited and general partnership interests began on June
12, 2001 and concluded on August 28, 2001, with investor partner contributions
of $15,000,000.

The Partnership has acquired interests in oil and gas prospects for the purpose
of development drilling. The Partnership participated in the drilling of 43
wells. 38 wells were productive and 5 wells were abandoned. Of the 38 productive
wells, 37 were producing and 1 was plugged and abandoned at September 30, 2003.

Additional drilling on the prospects 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 $421,538 at September
30, 2003.

During the nine months ended September 30, 2003, the Partnership made cash
distributions to the investor partners in the amount of $3,152,500 as compared
to $1,634,000 for the nine months ended September 30, 2002. The Partnership
expects that cash distributions will continue during 2003 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 which 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, 2003 as compared to the three months ended
September 30, 2002.

Oil and gas revenues. Oil and gas revenues during the three months ended
September 30, 2003 totaled $989,900. Production volumes during the period were
approximately 3,192 bbls of oil and 192,679 mcf of gas at corresponding average
realized prices of $28.89 per bbl of oil and $4.66 per mcf of gas. Oil and gas
revenues during the three months ended September 30, 2002 totaled $853,281.
Production volumes during the period were approximately 772 bbls of oil and
325,897 mcf of gas at corresponding average realized prices of $24.98 per bbl of
oil and $2.56 per mcf of gas. Oil and gas revenues increased primarily due to
the increase in oil production volumes and gas prices, partially offset by a
decline in gas production. The increased oil production volumes were
attributable to the addition of 3 New Mexico wells.

Interest Income. Interest income was $1,071 during the three month period ended
September 30, 2003 as compared to $6,374 during the three months ended September
30, 2002. 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, 2003 totaled $95,220 as compared to $74,010 for the period
ended September 30, 2002. Production taxes during the period ended September 30,
2003 totaled $72,862 compared to $67,140 for the period ended September 30,
2002. Lease operating expense increased due to the increase in the number of
wells producing in 2003 and the workover operations of one Oklahoma well in
2003.

9

Depreciation, depletion, and amortization. Depreciation, depletion, and
amortization for the three month period ended September 30, 2003 totaled
$279,049 compared to $400,767 for the three month period ended September 30,
2002. The decrease is due to the change in value of the reserves caused by
fluctuating oil and gas prices and the decline in production volumes.

Administrative and general expense. Administrative and general expense for the
three month period ended September 30, 2003 totaled $42,061 compared to $34,735
for the period ended September 30, 2002. The increase is primarily due to the
increase in oil and gas revenues.

Nine months ended September 30, 2003 as compared to the nine months ended
September 30, 2002.

Oil and gas revenues. Oil and gas revenues during the nine months ended
September 30, 2003 totaled $3,660,177. Production volumes during the period were
approximately 12,520 bbls of oil and 628,551 mcf of gas at corresponding average
realized prices of $30.15 per bbl of oil and $5.22 per mcf of gas. Oil and gas
revenues during the nine months ended September 30, 2002 totaled $2,381,724.
Production volumes during the period were approximately 2,227 bbls of oil and
895,138 mcf of gas at corresponding average realized prices of $23.90 per bbl of
oil and $2.60 per mcf of gas. Oil and gas revenues increased primarily due to
the increase in oil production volumes and gas prices, partially offset by a
decline in gas production. The increased oil production volumes were
attributable to the addition of 3 New Mexico wells.

Interest Income. Interest income was $3,588 during the nine month period ended
September 30, 2003 as compared to $35,683 during the nine months ended September
30, 2002. 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, 2003 totaled $264,543 as compared to $193,390 for the period
ended September 30, 2002. Production taxes during the period ended September 30,
2003 totaled $290,067 compared to $189,214 for the period ended September 30,
2002. Lease operating expense increased due to the increase in the number of
wells producing in 2003 and the workover operations of one Oklahoma well in
2003. Production taxes increased due to increased oil and gas revenues in 2003.

Depreciation, depletion, and amortization. Depreciation, depletion, and
amortization for the nine month period ended September 30, 2003 totaled $860,859
compared to $1,123,476 for the nine month period ended September 30, 2002. The
decrease is due to the change in value of the reserves caused by fluctuating oil
and gas prices and the decline in production volumes. There was no cost ceiling
write-down for the period ended September 30, 2003 compared to $2,152,691 for
the period ended September 30, 2002.

Administrative and general expense. Administrative and general expense for the
nine month period ended September 30, 2003 totaled $153,592 compared to $63,026
for the period ended September 30, 2002. The increase is primarily due to the
increase in oil and gas revenues.

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.

10

Upon adoption of FAS 143 on January 1, 2003, the Partnership recorded a
discounted liability of $297,742, increased the net full cost pool by $346,332
and recognized a one-time cumulative effect adjustment of $(48,590). The
increase in the net full cost pool included $182,214 for the reversal of
accumulated depreciation related to the inclusion of estimated salvage value of
equipment on the Partnership's oil and gas properties. Prior to the adoption of
FAS 143, the Partnership assumed salvage value approximated plugging and
abandonment costs and as a result was not included in the full cost pool.

A reconciliation of the Partnership's liability for well plugging and
abandonment costs for the nine months ended September 30, 2003, is as follows:

Balance upon adoption at January 1, 2003 $297,742
Liabilities incurred 9,895
Accretion expense 9,713
--------

Balance at September 30, 2003 $317,350
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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
None.

Item 6. Exhibits and Reports on Form 8-K

(a) Exhibits - filed herewith

31.1 Certification of CEO Pursuant ot 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 01-A, L.P.

By: Mewbourne Development Corporation
Managing General Partner

Date: November 13, 2003 By: /s/ Alan Clark
------------------------------------------
Alan Clark, Treasurer

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INDEX TO EXHIBITS