1 of 26
                                 FORM 10-Q


                    SECURITIES AND EXCHANGE COMMISSION
                         WASHINGTON, D. C.  20549

(Mark One)

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

For the transition period from _________________ to _______________

Commission file number 33-47667-01

                SOUTHWEST OIL & GAS 1992-93 INCOME PROGRAM
               Southwest Oil and Gas Income Fund XI-A, L.P.
                  (Exact name of registrant as specified
                   in its limited partnership agreement)

Delaware                                          75-2427267
(State or other jurisdiction of                                  (I.R.S.
Employer
incorporation or organization)
          Identification No.)

                       407 N. Big Spring, Suite 300
                  _________Midland, Texas 79701_________
                 (Address of principal executive offices)

                      ________(432) 686-9927________
                      (Registrant's telephone number,
                           including area code)

Indicate  by  check  mark  whether 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:

                            Yes __X__ No _____

Indicate  by  check  mark whether registrant is an  accelerated  filer  (as
defined in Rule 12b-2 of the Exchange Act).

                             Yes ____ No __X__


         The total number of pages contained in this report is 26.

<PAGE>

     Glossary of Oil and Gas Terms
The  following are abbreviations and definitions of terms commonly used  in
the  oil  and  gas industry that are used in this filing.  All  volumes  of
natural gas referred to herein are stated at the legal pressure base to the
state  or area where the reserves exit and at 60 degrees Fahrenheit and  in
most instances are rounded to the nearest major multiple.

     Bbl. One stock tank barrel, or 42 United States gallons liquid volume.

     Developmental well. A well drilled within the proved area of an oil or
natural gas reservoir to the depth of a stratigraphic horizon known  to  be
productive.

     Exploratory well. A well drilled to find and produce oil or gas in  an
unproved  area to find a new reservoir in a field previously  found  to  be
productive of oil or natural gas in another reservoir or to extend a  known
reservoir.

     Farm-out  arrangement. An agreement whereby the owner of the leasehold
or  working  interest  agrees to assign his interest  in  certain  specific
acreage  to  the assignee, retaining some interest, such as  an  overriding
royalty interest, subject to the drilling of one (1) or more wells or other
performance by the assignee.

     Field. An area consisting of a single reservoir or multiple reservoirs
all  grouped  on  or  related to the same individual geological  structural
feature and/or stratigraphic condition.

     Mcf. One thousand cubic feet.

     Oil. Crude oil, condensate and natural gas liquids.

     Overriding  royalty  interest. Interests that  are  carved  out  of  a
working  interest, and their duration is limited by the term of  the  lease
under which they are created.

<PAGE>
     Present  value  and  PV-10 Value. When used with respect  to  oil  and
natural gas reserves, the estimated future net revenue to be generated from
the  production of proved reserves, determined in all material respects  in
accordance  with  the  rules and regulations of the  SEC  (generally  using
prices  and costs in effect as of the date indicated) without giving effect
to  non-property  related  expenses  such  as  general  and  administrative
expenses,  debt service and future income tax expenses or to  depreciation,
depletion  and  amortization, discounted using an annual discount  rate  of
10%.

     Production  costs.  Costs incurred to operate and maintain  wells  and
related  equipment  and facilities, including depreciation  and  applicable
operating  costs  of support equipment and facilities and  other  costs  of
operating and maintaining those wells and related equipment and facilities.

     Proved Area. The part of a property to which proved reserves have been
specifically attributed.

     Proved  developed oil and gas reserves. Proved developed oil  and  gas
reserves  are  reserves that can be expected to be recovered from  existing
wells with existing equipment and operating methods.

     Proved properties. Properties with proved reserves.

     Proved  reserves. The estimated quantities of crude oil, natural  gas,
and  natural  gas liquids that geological and engineering data  demonstrate
with  reasonable  certainty to be recoverable in future  years  from  known
reservoirs under existing economic and operating conditions.

     Proved  undeveloped reserves. Proved undeveloped oil and gas  reserves
are  reserves that are expected to be recovered from new wells on undrilled
acreage,  or  from existing wells where a relatively major  expenditure  is
required for recompletion.

     Reservoir.  A porous and permeable underground formation containing  a
natural  accumulation  of  producible  oil  or  gas  that  is  confined  by
impermeable  rock  or water barriers and is individual  and  separate  from
other reservoirs.

     Royalty  interest.  An  interest in an oil and  natural  gas  property
entitling  the  owner to a share of oil or natural gas production  free  of
costs of production.

     Working  interest.  The operating interest that gives  the  owner  the
right  to  drill, produce and conduct operating activities on the  property
and a share of production.

     Workover.  Operations  on  a producing well  to  restore  or  increase
production.

<PAGE>

                      PART I. - FINANCIAL INFORMATION

Item 1.  Financial Statements

The  unaudited  condensed financial statements included  herein  have  been
prepared  by  the Registrant (herein also referred to as the "Partnership")
in  accordance  with generally accepted accounting principles  for  interim
financial information and with the instructions to Form 10-Q and Rule 10-01
of Regulation S-X.  Accordingly, they do not include all of the information
and  footnotes  required  by generally accepted accounting  principles  for
complete   financial  statements.   In  the  opinion  of  management,   all
adjustments necessary for a fair presentation have been included and are of
a  normal  recurring nature.  The financial statements should  be  read  in
conjunction with the audited financial statements and the notes thereto for
the  year  ended  December 31, 2002, which are found  in  the  Registrant's
Amendment No. 1 to its Annual Report on Form 10-K for 2002 filed  with  the
Securities and Exchange Commission on November 12, 2003.  The December  31,
2002  balance  sheet included herein has been derived from the Registrant's
Amendment  No.  1  to its Annual Report on Form 10-K for  2002.   Operating
results  for the three and nine month periods ended September 30, 2003  are
not necessarily indicative of the results for the full year.

Introductory Note - Statement of Financial Accounting Standard No. 143
The  Partnership implemented SFAS No. 143 effective January  1,  2003  (See
Note 3) to the Partnership's financial statements.

Introductory Note - Depletion Method
During  the fourth quarter of 2002, the Partnership changed its  method  of
providing  for depletion from the units-of-revenue method to the  units-of-
production  method  as  described in Notes 4 and  6  to  the  Partnership's
financial statements.

This  change  in depletion method was applied as a cumulative effect  of  a
change  in  accounting  principle effective as of  January  1,  2002.   The
unaudited condensed financial statements of the Partnership for the periods
ended September 30, 2002, included herein, have been restated (as described
in  Notes 4 and 6 to the Partnership's financial statements) using the  new
depletion   method  and  differ  from  those  previously  issued   in   the
Partnership's Quarterly Report on Form 10-Q for the periods ended September
30, 2002.

<PAGE>

               Southwest Oil and Gas Income Fund XI-A, L.P.
                              Balance Sheets

                                 Septembe  December
                                  r 30,      31,
                                   2003      2002
                                   ----      ----
                                 (unaudit
                                   ed)
Assets
---------
Current assets:
 Cash and cash equivalents    $  47,859    17,179
  Receivable  from  Managing     -         24,291
General Partner
                                 --------  --------
                                 -----     -----
   Total current assets          47,859    41,470
                                 --------  --------
                                 -----     -----
Oil  and  gas  properties  -
using the full-
 cost method of accounting       1,032,99  1,053,59
                                 1         6
       Less      accumulated
depreciation,
         depletion       and     (828,236  838,555
amortization                     )
                                 --------  --------
                                 -----     -----
      Net   oil   and    gas     204,755   215,041
properties
                                 --------  --------
                                 -----     -----
                              $  252,614   256,511
                                 =======   =======

Liabilities  and   Partners'
Equity
----------------------------
------------

Current liability:
 Distribution payable         $  -         46
 Payable to Managing General     641       -
Partner
                                 --------  --------
                                 -----     -----
          Total      current     641       46
liabilities
                                 --------  --------
                                 -----     -----

Other long term liabilities      55,133    -
                                 --------  --------
                                 -----     -----

Partners' equity:
 General partners                (6,545)   (4,038)
 Limited partners                203,385   260,503
                                 --------  --------
                                 -----     -----
   Total partners' equity        196,840   256,465
                                 --------  --------
                                 -----     -----
                              $  252,614   256,511
                                 =======   =======

<PAGE>

               Southwest Oil and Gas Income Fund XI-A, L.P.
                         Statements of Operations
                                (unaudited)

                                 Three Months Ended    Nine Months
                                                          Ended
                                   September 30,      September 30,
                                   2003      2002      2003     2002
                                           (Restate            (Resta
                                              d)                ted)
                                   ----      ----      ----     ----
Revenues
--------
Oil and Gas                   $  28,911    34,463    126,438   104,28
                                                               2
Interest                         85        40        157       91
Miscellaneous settlement         -         -         6         1,236
                                 --------  --------  --------  ------
                                 --        --        --        ----
                                 28,996    34,503    126,601   105,60
                                                               9
                                 --------  --------  --------  ------
                                 --        --        --        ----
Expenses
--------
Production                       21,818    22,595    67,242    55,714
General and administrative       6,182     5,110     21,848    13,600
Depreciation, depletion and      4,000     5,000     14,000    17,000
amortization
Accretion of asset retirement    1,040     -         3,587     -
obligation
                                 --------  --------  --------  ------
                                 --        --        --        ----
                                 33,040    32,705    106,677   86,314
                                 --------  --------  --------  ------
                                 --        --        --        ----
Net income (loss) from           (4,044)   1,798     19,924    19,295
continuing operations

Results from discontinued
operations -
 sale of oil and gas lease -     5,479     4,484     19,231    9,227
See Note 5
                                 --------  --------  --------  ------
                                 --        --        --        ----
Net income before cumulative     1,435     6,282     39,155    28,522
effect

Cumulative effect of change
in accounting
 principle - SFAS No. 13 -       -         -         (5,725)   -
See Note3
Cumulative effect of change
in accounting principle
 - change in depletion method    -         -         -         1,000
- See Note 4
                                 --------  --------  --------  ------
                                 --        --        --        ----
Net income                    $  1,435     6,282     33,430    29,522
                                 ======    ======    ======    ======
               Southwest Oil and Gas Income Fund XI-A, L.P.
                         Statements of Operations
                                (unaudited)

                                 Three Months Ended  Nine Months Ended
                                   September 30,       September 30,
                                   2003      2002      2003      2002
                                           (Restate            (Restate
                                              d)                  d)
                                   ----      ----      ----      ----
Net income allocated to:
 Managing General Partner     $  489       1,015     4,269     4,097
                                 ======    ======    ======    ======
 General Partner              $  54        113       474       455
                                 ======    ======    ======    ======
 Limited Partners             $  892       5,154     28,687    24,970
                                 ======    ======    ======    ======
  Per limited partner unit
before discontinued
   operations and cumulative  $  (1.43)       .40
effect                                               5.86      5.55
  Discontinued operations per      1.75
limited partner unit                       1.43      6.14      2.94
  Cumulative effects per              -         -    (1.83)       .35
limited partner unit
                                 --------  --------  --------  --------
                                 --        --        --        --
  Per limited partner unit    $     .32
                                           1.83      10.17     8.84
                                 ======    ======    ======    ======
Pro forma amounts assuming
change is applied
 retroactively (See Note 3):
 Net income before cumulative $  -         5,109     -         25,006
effect
                                 ======    ======    ======    ======
   Per  limited partner  unit $  -           1.45    -           7.37
(2,821.0)
                                 ======    ======    ======    ======
 Net income                   $  -         5,109     -         26,006
                                 ======    ======    ======    ======
   Per  limited partner  unit $  -           1.45    -           7.72
(2,821.0)
                                 ======    ======    ======    ======

<PAGE>
               Southwest Oil and Gas Income Fund XI-A, L.P.
                         Statements of Cash Flows
                                (unaudited)

                                                     Nine Months Ended
                                                       September 30,
                                                      2003      2002
                                                              (Restate
                                                                 d)
                                                      ----      ----
            Cash flows from operating activities
             Cash received from oil and gas       $ 137,458   98,980
            sales
             Cash paid to suppliers                 (75,179   (82,079)
                                                    )
             Cash received from discontinued        19,231    9,227
            operations
             Interest received                      157       91
             Miscellaneous settlement               6         1,236
                                                    -------   --------
                                                    ----      ---
              Net cash provided by operating        81,673    27,455
            activities
                                                    -------   --------
                                                    ----      ---
            Cash flows from investing activities
             Additions to oil and gas properties    (325)     -
             Sale of oil and gas properties         42,433    706
                                                    -------   --------
                                                    ----      ---
              Net cash provided by investing        42,108    706
            activities
                                                    -------   --------
                                                    ----      ---
            Cash flows used in financing
            activities
             Distributions to partners              (93,101   (24,046)
                                                    )
                                                    -------   --------
                                                    ----      ---
              Net increase in cash and cash         30,680    4,115
            equivalents

             Beginning of period                    17,179    13,139
                                                    -------   --------
                                                    ----      ---
             End of period                        $ 47,859    17,254
                                                    ======    ======
            Reconciliation of net income to net
            cash
             provided by operating activities

            Net income                            $ 33,430    29,522

            Adjustments to reconcile net income
            to net
             cash provided by operating
            activities

             Depreciation, depletion and            14,000    17,000
            amortization
             Accretion of asset retirement          3,587     -
            obligation
             Cumulative effect of change in
            accounting
              principle - SFAS No. 143              5,725     -
             Cumulative effect of change in
            accounting
              principle - change in depletion       -         (1,000)
            method
             Decrease (increase) in receivables     11,020    (5,302)
             Increase (decrease) in payables        13,911    (12,765)
                                                    -------   --------
                                                    ----      ---
            Net cash provided by operating        $ 81,673    27,455
            activities
                                                    ======    =======
            Noncash investing and financing
            activities:
             Increase in oil and gas properties
            - Adoption
              of SFAS No. 143                     $ 57,971    -
                                                    ======    =======
             Decrease in oil and gas properties
            SFAS No. 143
              sale of oil and gas properties      $ 12,150    -
                                                    ======    =======
<PAGE>
                Southwest Oil & Gas Income Fund XI-A, L.P.
                     (a Delaware limited partnership)

                      Notes to Financial Statements

1.   Organization
     Southwest  Oil  & Gas Income Fund XI-A, L.P. was organized  under  the
     laws  of  the  state of Delaware on May 5, 1992, for  the  purpose  of
     acquiring  producing oil and gas properties and to produce and  market
     crude oil and natural gas produced from such properties for a term  of
     50  years, unless terminated at an earlier date as provided for in the
     Partnership  Agreement.  The Partnership will sell  its  oil  and  gas
     production  to  a  variety of purchasers with the prices  it  receives
     being  dependent  upon the oil and gas economy.  Southwest  Royalties,
     Inc. serves as the Managing General Partner and H. H. Wommack, III, as
     the  individual general partner.  Partnership profits and  losses,  as
     well as all items of income, gain, loss, deduction, or credit, will be
     credited or charged as follows:

                              Limited   General
                              Partners  Partners
                                          (1)
                              --------  --------
Organization  and   offering  100%      -
expenses (2)
Acquisition costs             100%      -
Operating costs               90%       10%
Administrative costs (3)      90%       10%
Direct costs                  90%       10%
All other costs               90%       10%
Interest  income  earned  on
capital
 contributions                100%      -
Oil and gas revenues          90%       10%
Other revenues                90%       10%
Amortization                  100%      -
Depletion allowances          100%      -

          (1)   H.H.  Wommack,  III,  President  of  the  Managing  General
          Partner, is an additional general partner in the Partnership  and
          has  a  one percent interest in the Partnership.  Mr. Wommack  is
          the  majority  stockholder of the Managing General Partner  whose
          continued  involvement in Partnership management is important  to
          its  operations.  Mr. Wommack, as a general partner, shares  also
          in Partnership liabilities.
          (2)   Organization and Offering Expenses (including all  cost  of
          selling  and  organizing the offering) include a payment  by  the
          Partnership of an amount equal to three percent (3%)  of  Capital
          Contributions   for   reimbursement  of   such   expenses.    All
          Organization Costs (which excludes sales commissions and fees) in
          excess  of  three  percent  (3%) of  Capital  Contributions  with
          respect to the Partnership will be allocated to and paid  by  the
          Managing General Partner.
          (3)   Administrative  Costs will be paid from  the  Partnership's
          revenues;  however; Administrative Costs in the Partnership  year
          in  excess of two percent (2%) of Capital Contributions shall  be
          allocated to and paid by the Managing General Partner.

2.   Summary of Significant Accounting Policies
     The  interim financial information as of September 30, 2003,  and  for
     the  three  and  nine months ended September 30, 2003,  is  unaudited.
     Certain  information  and footnote disclosures  normally  included  in
     financial  statements prepared in accordance with  generally  accepted
     accounting principles have been condensed or omitted in this Form 10-Q
     pursuant  to the rules and regulations of the Securities and  Exchange
     Commission.  However,  in  the opinion of  management,  these  interim
     financial  statements include all the necessary adjustments to  fairly
     present  the  results of the interim periods and all such  adjustments
     are  of a normal recurring nature.  The interim consolidated financial
     statements  should  be  read  in conjunction  with  the  Partnership's
     Amendment  No. 1 to its Annual Report on Form 10-K for the year  ended
     December 31, 2002, filed with SEC on November 12, 2003.

<PAGE>
                Southwest Oil & Gas Income Fund XI-A, L.P.
                     (a Delaware limited partnership)

                      Notes to Financial Statements

3.   Cumulative effect of change in accounting principle - SFAS No. 143
     On  January  1, 2003, the Partnership adopted Statement  of  Financial
     Accounting   Standards  No.  143,  Accounting  for  Asset   Retirement
     Obligations  ("SFAS No. 143").  Adoption of SFAS No. 143  is  required
     for  all  companies with fiscal years beginning after June  15,  2002.
     The new standard requires the Partnership to recognize a liability for
     the  present  value  of  all  legal obligations  associated  with  the
     retirement  of tangible long-lived assets and to capitalize  an  equal
     amount as a cost of the asset and depreciate the additional cost  over
     the  estimated  useful  life of the asset.  On January  1,  2003,  the
     Partnership    recorded   additional   costs,   net   of   accumulated
     depreciation,  of  approximately $57,971, a  long  term  liability  of
     approximately  $63,696  and  a loss of approximately  $5,725  for  the
     cumulative  effect  on  depreciation  of  the  additional  costs   and
     accretion  expense  on  the liability related to expected  abandonment
     costs  of  its oil and natural gas producing properties.  At September
     30,  2003,  the  asset  retirement obligation  was  $55,133,  and  the
     decrease  in  the balance from January 1, 2003 is due to the  sale  of
     three  oil  and  gas properties, which decreased the asset  retirement
     obligation  by  $  12,150, partially offset by  accretion  expense  of
     $3,587.   The  pro forma amounts for the three and nine  months  ended
     September  30, 2002, which are presented on the face of the statements
     of  operations, reflect the effect of retroactive application of  SFAS
     No. 143.

4.    Cumulative  effect  of change in accounting  principle  -  change  in
depletion method
     In  the  fourth  quarter of 2002, the Partnership changed  methods  of
     accounting  for  depletion  of capitalized costs  from  the  units-of-
     revenue  method to the units-of-production method.  The newly  adopted
     accounting  principle is preferable in the circumstances  because  the
     units-of-production method results in a better matching of  the  costs
     of  oil  and  gas production against the related revenue  received  in
     periods of volatile prices for production as have been experienced  in
     recent  periods.  Additionally, the units-of-production method is  the
     predominant  method used by full cost companies in  the  oil  and  gas
     industry,  accordingly, the change improves the comparability  of  the
     Partnership's   financial  statements  with  its  peer   group.    The
     Partnership   adopted  the  units-of-production  method  through   the
     recording  of a cumulative effect of a change in accounting  principle
     in  the  amount  of  $1,000  effective as of  January  1,  2002.   The
     Partnership's depletion for the three and nine months ended  September
     30,  2003  and  2002 has been calculated using the units-of-production
     method.   The effect of the change on the three and nine months  ended
     September 30, 2002 was to decrease income before cumulative effect  of
     a  change in accounting principle by $1,000 and $2,000 ($.35 and  $.70
     per  limited  partner unit), respectively and decrease net  income  by
     $1,000   and  $1,000  ($.35  and  $.35  per  limited  partner   unit),
     respectively.

5.   Discontinued Operations - Sale of oil and gas leases
     During the nine months ended September 30, 2003, the Partnership  sold
     its  interest  in  certain oil and gas wells for $42,433  and  retired
     $12,150 of asset retirement obligation associated with the properties.
     Since  the  Partnership  is  under  the  full  cost  pool  method   of
     accounting,  the  sales  proceeds  and  asset  retirement   obligation
     liability were taken against the oil and gas properties asset  account
     and therefore, no gain or loss was recorded and shown on the statement
     of operations as part of the discontinued operations.  Pursuant to the
     requirements  of SFAS No. 144, the historical operating  results  from
     these properties have been reported as discontinued operations in  the
     accompanying statements of operations.  The following table summarizes
     certain  historical operating information related to the  discontinued
     operations:

                   Three Months Ended       Nine Months Ended
                    2003       2002         2003       2002

Revenues          $7,832     7,863        26,794    18,340
Net income        5,479      4,484        19,231    9,227

<PAGE>
                Southwest Oil & Gas Income Fund XI-A, L.P.
                     (a Delaware limited partnership)

                      Notes to Financial Statements

6.   September 30, 2002 Restatement
     During  the fourth quarter of 2002, the Partnership changed its method
     of  providing  for depletion from the units-of-revenue method  to  the
     units-of-production method as described in Note 4.

     This  change in the method used to implement the Partnership's  change
     in  the manner in which it determines depletion resulted in a decrease
     in the Partnership's previously reported net oil and gas properties of
     $1,000  from $216,041 to $215,041 as of December 31, 2002 and did  not
     effect the Partnership's 2002 cash flows from operations, investing or
     financing activities.

     The  change  had the following effects on the Statement of  Operations
     for the three and nine months ended September 30, 2002.

                           Three Months Ended      Nine Months Ended
                                    Previousl               Previousl
                                        y                       y
                          Restated   Reported     Restated  Reported
  Depreciation,
  depletion and
  amortization             $5,000   4,000         17,000    15,000
  Income before           6,282     7,282         28,522    30,522
  cumulative effect
Cumulative effect of
  change in
  accounting principle    -         -             1,000     -
  Net income              6,282     7,282         29,522    30,522
  Net income allocated
  to:
  Managing General        1,015     1,015         4,097     3,986
  Partner
  General partner         113       113           455       443
  Limited partners        5,154     6,154         24,970    26,093
   Income per limited
  partner
     unit before            1.83       2.18
  cumulative effect                               8.49      9.25
   Cumulative effect
  per limited
     partner unit              -         -             -         -
   Net income per
  limited
     partner unit           1.83         2.18
                                                  8.84      9.25

<PAGE>
Item 2.  Management's Discussion and Analysis of Financial Condition and
Results of Operations

General
Southwest  Oil  & Gas Income Fund XI-A, L.P. was organized  as  a  Delaware
limited  partnership  on  May  5,  1992.   The  offering  of  such  limited
partnership  interests began August 20, 1992 as part of  a  shelf  offering
registered  under  the  name Southwest Oil & Gas  1992-93  Income  Program.
Minimum  capital  requirements for the Partnership were met  on  March  17,
1993,  with the offering of limited partnership interests concluding  April
30,  1993.   At  the  conclusion  of the offering  of  limited  partnership
interests, 122 limited partners had purchased 2,821 units for $1,410,500.

The  Partnership was formed to acquire interests in producing oil  and  gas
properties,  to produce and market crude oil and natural gas produced  from
such properties, and to distribute the net proceeds from operations to  the
limited  and  general partners.  Net revenues from producing  oil  and  gas
properties will not be reinvested in other revenue producing assets  except
to the extent that production facilities and wells are improved or reworked
or  where methods are employed to improve or enable more efficient recovery
of oil and gas reserves.

Increases   or   decreases   in  Partnership   revenues   and,   therefore,
distributions  to partners will depend primarily on changes in  the  prices
received  for  production,  changes in volumes of  production  sold,  lease
operating  expenses, enhanced recovery projects, offset drilling activities
pursuant to farmout arrangements, sales of properties, and the depletion of
wells.  Since wells deplete over time, production can generally be expected
to decline from year to year.

Well  operating costs and general and administrative costs usually decrease
with   production   declines;  however,  these  costs  may   not   decrease
proportionately.  Net income available for distribution to the partners  is
therefore expected to fluctuate in later years based on these factors.

Based on current conditions, management anticipates performing no workovers
during  2003 to enhance production.  Additional workovers may be  performed
in  the  year  2004.   The Partnership may have an increase  in  production
volumes  for  the  year 2004, otherwise, the Partnership will  most  likely
experience the historical production decline, which has approximated 9% per
year.

Oil and Gas Properties
Oil  and  gas  properties  are accounted for at cost  under  the  full-cost
method.  Under this method, all productive and nonproductive costs incurred
in  connection with the acquisition, exploration and development of oil and
gas  reserves  are capitalized.  Gain or loss on the sale of  oil  and  gas
properties  is not recognized unless significant oil and gas  reserves  are
involved.

In  the  fourth  quarter  of  2002,  the  Partnership  changed  methods  of
accounting  for  depletion of capitalized costs from  the  units-of-revenue
method  to  the  units-of-production method.  The newly adopted  accounting
principle   is  preferable  in  the  circumstances  because  the  units-of-
production method results in a better matching of the costs of oil and  gas
production  against  the related revenue received in  periods  of  volatile
prices   for  production  as  have  been  experienced  in  recent  periods.
Additionally, the units-of-production method is the predominant method used
by full cost companies in the oil and gas industry, accordingly, the change
improves  the comparability of the Partnership's financial statements  with
its peer group.

Should the net capitalized costs exceed the estimated present value of  oil
and gas reserves, discounted at 10%, such excess costs would be charged  to
current  expense.  As of September 30, 2003, the net capitalized costs  did
not exceed the estimated present value of oil and gas reserves.

<PAGE>
Critical Accounting Policies

Full cost ceiling calculations The Partnership follows the full cost method
of  accounting  for  its  oil and gas properties.   The  full  cost  method
subjects  companies to quarterly calculations of a "ceiling", or limitation
on  the  amount of properties that can be capitalized on the balance sheet.
If  the  Partnership's capitalized costs are in excess  of  the  calculated
ceiling, the excess must be written off as an expense.

The  Partnership's discounted present value of its proved oil  and  natural
gas  reserves  is  a  major  component  of  the  ceiling  calculation,  and
represents  the  component  that requires the  most  subjective  judgments.
Estimates  of  reserves are forecasts based on engineering data,  projected
future  rates  of  production and the timing of future  expenditures.   The
process  of  estimating oil and natural gas reserves  requires  substantial
judgment,  resulting  in  imprecise determinations,  particularly  for  new
discoveries.   Different reserve engineers may make different estimates  of
reserve  quantities  based  on the same data.   The  Partnership's  reserve
estimates are prepared by outside consultants.

The  passage  of  time  provides  more  qualitative  information  regarding
estimates of reserves, and revisions are made to prior estimates to reflect
updated  information.   However,  there  can  be  no  assurance  that  more
significant  revisions  will not be necessary in  the  future.   If  future
significant  revisions  are  necessary  that  reduce  previously  estimated
reserve quantities, it could result in a full cost property writedown.   In
addition to the impact of these estimates of proved reserves on calculation
of  the  ceiling,  estimates  of proved reserves  are  also  a  significant
component of the calculation of DD&A.

While  estimating  the  quantities of proved reserves  require  substantial
judgment,  the associated prices of oil and natural gas reserves  that  are
included  in  the discounted present value of the reserves do  not  require
judgment.  The ceiling calculation dictates that prices and costs in effect
as  of the last day of the period are generally held constant indefinitely.
Because  the ceiling calculation dictates that prices in effect as  of  the
last  day  of  the  applicable quarter are held constant indefinitely,  the
resulting  value  may  not be indicative of the  true  fair  value  of  the
reserves.  Oil and natural gas prices have historically been cyclical  and,
on  any particular day at the end of a quarter, can be either substantially
higher or lower than the Partnership's long-term price forecast that  is  a
barometer for true fair value.

In  the  fourth  quarter  of  2002,  the  Partnership  changed  methods  of
accounting  for  depletion of capitalized costs from  the  units-of-revenue
method  to  the  units-of-production method.  The newly adopted  accounting
principle   is  preferable  in  the  circumstances  because  the  units-of-
production method results in a better matching of the costs of oil and  gas
production  against  the related revenue received in  periods  of  volatile
prices   for  production  as  have  been  experienced  in  recent  periods.
Additionally, the units-of-production method is the predominant method used
by full cost companies in the oil and gas industry, accordingly, the change
improves  the comparability of the Partnership's financial statements  with
its peer group.


<PAGE>
Results of Operations

A.  General Comparison of the Quarters Ended September 30, 2003 and 2002

The  following  table  provides certain information  regarding  performance
factors for the quarters ended September 30, 2003 and 2002:

                                    Three Months
                                       Ended         Percenta
                                                        ge
                                   September 30,     Increase
                                   2003      2002    (Decreas
                                                        e)
                                   ----      ----    --------
                                                        --
Average price per barrel  of  $   28.65              12%
oil                                        25.68
Average price per mcf of gas  $    3.58              50%
                                           2.38
Oil production in barrels        770       1,000     (23%)
Gas production in mcf            4,100     7,000     (41%)
Gross oil and gas revenue     $  28,911    34,463    (16%)
Net oil and gas revenue       $  7,093     11,868    (40%)
Partnership distributions     $  50,555    9,000     462%
Limited              partner  $  47,555    8,100     487%
distributions
Per  unit  distribution   to
limited
 partners                     $   16.86              487%
                                           2.87
Number  of  limited  partner     2,821     2,821
units

Revenues

The  Partnership's oil and gas revenues decreased to $28,911  from  $34,463
for  the  quarters  ended  September 30, 2003  and  2002,  respectively,  a
decrease  of  16%.  The principal factors affecting the comparison  of  the
quarters ended September 30, 2003 and 2002 are as follows:

1.  The  average  price  for a barrel of oil received  by  the  Partnership
    increased  during the quarter ended September 30, 2003 as  compared  to
    the  quarter  ended  September 30, 2002 by 12%, or  $2.97  per  barrel,
    resulting  in  an  increase of approximately $2,300 in  revenues.   Oil
    sales  represented  60% of total oil and gas sales during  the  quarter
    ended  September 30, 2003 as compared to 61% during the  quarter  ended
    September 30, 2002.

    The  average  price  for  an  mcf of gas received  by  the  Partnership
    increased during the same period by 50%, or $1.20 per mcf, resulting in
    an increase of approximately $4,900 in revenues.

    The  total  increase in revenues due to the change in  prices  received
    from  oil and gas production is approximately $7,200.  The market price
    for  oil  and gas has been extremely volatile over the past decade  and
    management  expects a certain amount of volatility to continue  in  the
    foreseeable future.

<PAGE>

2.  Oil  production decreased approximately 230 barrels or 23%  during  the
    quarter  ended  September 30, 2003 as compared  to  the  quarter  ended
    September 30, 2002, resulting in a decrease of approximately $5,900  in
    income from net profits interests.

    Gas production decreased approximately 2,900 mcf or 41% during the same
    period, resulting in a decrease of approximately $6,900 in revenues.

    The  total  decrease  in revenues due to the change  in  production  is
    approximately $12,800.  The decrease in production is due primarily  to
    two oil and gas properties sold in July 2003.

Costs and Expenses

Total costs and expenses increased to $33,040 from $32,705 for the quarters
ended  September 30, 2003 and 2002, respectively, an increase of  1%.   The
increase  is  the result of higher general and administrative  expense  and
accretion expense, partially offset by a decrease in depletion expense  and
lease operating costs.

1.    Lease  operating  costs  and  production  taxes  were  3%  lower,  or
   approximately $800 less during the quarter ended September 30,  2003  as
   compared to the quarter ended September 30, 2002.

2.  General and administrative costs consist of independent accounting  and
    engineering  fees,  computer services, postage,  and  Managing  General
    Partner  personnel costs.  General and administrative  costs  increased
    21% or approximately $1,100 during the quarter ended September 30, 2003
    as  compared to the quarter ended September 30, 2002.  The increase  in
    general and administrative expense is due to an increase in independent
    accounting review and audit fees.

3.  Depletion  expense decreased to $4,000 for the quarter ended  September
    30,  2003  from $5,000 for the same period in 2002.  This represents  a
    decrease  of  20%.   In  the fourth quarter of  2002,  the  Partnership
    changed  methods of accounting for depletion of capitalized costs  from
    the  units-of-revenue  method to the units-of-production  method.   The
    newly  adopted  accounting principle is preferable in the circumstances
    because the units-of-production method results in a better matching  of
    the  costs  of  oil  and  gas production against  the  related  revenue
    received  in  periods of volatile prices for production  as  have  been
    experienced  in  recent periods.  Additionally, the units-of-production
    method is the predominant method used by full cost companies in the oil
    and gas industry, accordingly, the change improves the comparability of
    the Partnership's financial statements with its peer group.  The effect
    of  this  change  in method was to increase depletion expense  for  the
    three months ended September 30, 2002 by $1,000 and decrease net income
    for  the three months ended September 30, 2002 by $1,000(See Note 4  of
    the notes to the financial statements).  The contributing factor to the
    decrease in depletion expense is in relation to the BOE depletion  rate
    for  the  quarter ended September 30, 2003, which was $2.75 applied  to
    1,453  BOE  as  compared to $2.31 applied to 2,167  BOE  for  the  same
    period.


<PAGE>

B.   General Comparison of the Nine Month Periods Ended September 30,  2003
and 2002

The  following  table  provides certain information  regarding  performance
factors for the nine month periods ended September 30, 2003 and 2002:

                                    Nine Months
                                       Ended         Percenta
                                                        ge
                                   September 30,     Increase
                                   2003      2002    (Decreas
                                                        e)
                                   ----      ----    --------
                                                        --
Average price per barrel  of  $   28.97              25%
oil                                        23.18
Average price per mcf of gas  $    4.41              87%
                                           2.36
Oil production in barrels        2,670     2,900     (8%)
Gas production in mcf            17,200    23,500    (27%)
Gross oil and gas revenue     $  126,438   104,282   21%
Net oil and gas revenue       $  59,196    48,568    22%
Partnership distributions     $  93,055    24,000    288%
Limited              partner  $  85,805    21,600    297%
distributions
Per  unit  distribution   to
limited
 partners                     $   30.42              297%
                                           7.66
Number  of  limited  partner     2,821     2,821
units

Revenues

The  Partnership's oil and gas revenues increased to $126,438 from $104,282
for  the  nine  months ended September 30, 2003 and 2002, respectively,  an
increase  of  21%.  The principal factors affecting the comparison  of  the
nine months ended September 30, 2003 and 2002 are as follows:

1.  The  average  price  for a barrel of oil received  by  the  Partnership
    increased  during the nine months ended September 30, 2003 as  compared
    to  the  nine  months ended September 30, 2002 by  25%,  or  $5.79  per
    barrel,  resulting in an increase of approximately $15,500 in revenues.
    Oil sales represented 50% of total oil and gas sales during the quarter
    ended  September 30, 2003 as compared to 55% during the  quarter  ended
    September 30, 2002.

    The  average  price  for  an  mcf of gas received  by  the  Partnership
    increased during the same period by 87%, or $2.05 per mcf, resulting in
    an increase of approximately $35,300 in revenues.

    The  total  increase in revenues due to the change in  prices  received
    from oil and gas production is approximately $50,800.  The market price
    for  oil  and gas has been extremely volatile over the past decade  and
    management  expects a certain amount of volatility to continue  in  the
    foreseeable future.

<PAGE>

2.  Oil  production decreased approximately 230 barrels or  8%  during  the
    nine  months  ended September 30, 2003 as compared to the  nine  months
    ended  September  30,  2002, resulting in a decrease  of  approximately
    $5,300 in revenues.

    Gas production decreased approximately 6,300 mcf or 27% during the same
    period, resulting in a decrease of approximately $14,900 in revenues.

    The  total  decrease  in revenues due to the change  in  production  is
    approximately $20,200.  The decrease in gas production is due primarily
    to  the  sale  of a gas lease in July 2003, in addition  another  lease
    experienced  downtime during the end of 2002 and is slowly resuming  to
    normal.

Costs and Expenses

Total  costs and expenses increased to $106,677 from $86,314 for  the  nine
months ended September 30, 2003 and 2002, respectively, an increase of 24%.
The  increase  is the result of higher general and administrative  expense,
accretion expense and lease operating costs, partially offset by a decrease
in depletion expense.

1.  Lease  operating  costs  and  production  taxes  were  21%  higher,  or
    approximately  $11,500 more during the nine months ended September  30,
    2003  as  compared to the nine months ended September  30,  2002.   The
    increase  in  lease operating expense and production taxes  is  due  to
    several  small  leases having repairs and maintenance performed  during
    2003,  and the increase in production taxes due to an increase in gross
    revenues received during the nine months ended September 30, 2003.

2.  General and administrative costs consist of independent accounting  and
    engineering  fees,  computer services, postage,  and  Managing  General
    Partner  personnel costs.  General and administrative  costs  increased
    61%  or approximately $8,200 during the nine months ended September 30,
    2003  as  compared to the nine months ended September  30,  2002.   The
    increase in general and administrative expense is due to an increase in
    independent accounting review and audit fees.

3.  Depletion  expense  decreased to $14,000  for  the  nine  months  ended
    September  30,  2003 from $17,000 for the same period  in  2002.   This
    represents  a  decrease of 18%.  In the fourth  quarter  of  2002,  the
    Partnership  changed methods of accounting for depletion of capitalized
    costs  from  the  units-of-revenue method  to  the  units-of-production
    method.   The newly adopted accounting principle is preferable  in  the
    circumstances  because  the units-of-production  method  results  in  a
    better  matching  of  the costs of oil and gas production  against  the
    related  revenue received in periods of volatile prices for  production
    as have been experienced in recent periods.  Additionally, the units-of-
    production method is the predominant method used by full cost companies
    in  the  oil  and  gas industry, accordingly, the change  improves  the
    comparability of the Partnership's financial statements with  its  peer
    group.   The effect of this change in method was to increase  depletion
    expense  for  the nine months ended September 30, 2002  by  $2,000  and
    decrease  net income by $1,000 for the nine months ended September  30,
    2002(See  Note  4  of  the  notes to the  financial  statements).   The
    contributing factor to the decrease in depletion expense is in relation
    to the BOE depletion rate for the nine months ended September 30, 2003,
    which  was  $2.53 applied to 5,537 BOE as compared to $2.49 applied  to
    6,817 BOE for the same period.

Cumulative effect of change in accounting principle

On  January  1,  2003,  the  Partnership  adopted  Statement  of  Financial
Accounting  Standards No. 143, Accounting for Asset Retirement  Obligations
("SFAS  No. 143").  Adoption of SFAS No. 143 is required for all  companies
with fiscal years beginning after June 15, 2002.  The new standard requires
the Partnership to recognize a liability for the present value of all legal
obligations  associated with the retirement of tangible  long-lived  assets
and to capitalize an equal amount as a cost of the asset and depreciate the
additional cost over the estimated useful life of the asset.  On January 1,
2003,  the  Partnership  recorded  additional  costs,  net  of  accumulated
depreciation,   of  approximately  $57,971,  a  long  term   liability   of
approximately $63,696 and a loss of approximately $5,725 for the cumulative
effect on depreciation of the additional costs and accretion expense on the
liability related to expected abandonment costs of its oil and natural  gas
producing   properties.   At  September  30,  2003,  the  asset  retirement
obligation  was  $55,133, and the decrease in the balance from  January  1,
2003  is  due to the sale of three oil and gas properties, which  decreased
the  asset retirement obligation by $ 12,150, partially offset by accretion
expense  of  $3,587.  The pro forma amounts for the three and  nine  months
ended September 30, 2002, which are presented on the face of the statements
of  operations, reflect the effect of retroactive application of  SFAS  No.
143.


<PAGE>

Liquidity and Capital Resources

The  primary source of cash is from operations, the receipt of income  from
interests in oil and gas properties.  The Partnership knows of no  material
change, nor does it anticipate any such change.

Cash  flows provided by operating activities were approximately $81,700  in
the  nine  months  ended  September 30, 2003 as compared  to  approximately
$27,500 in the nine months ended September 30, 2002.  The primary source of
the 2003 cash flow from operating activities was profitable operations.

Cash  flows provided by investing activities were approximately $42,100  in
the  nine months ended September 30, 2003 as compared to approximately $700
in  the  nine months ended September 30, 2002.  The primary source  of  the
2003  cash  flow  from investing activities was the sale  of  oil  and  gas
properties.

Cash  flows used in financing activities were approximately $93,100 in  the
nine  months ended September 30, 2003 as compared to approximately  $24,000
in  the  nine  months ended September 30, 2002.  The only use in  financing
activities was the distributions to partners.

Total  distributions during the nine months ended September 30,  2003  were
$93,055 of which $85,805 was distributed to the limited partners and $7,250
to  the  general  partners.  The per unit distribution to limited  partners
during  the  nine  months  ended September  30,  2003  was  $30.42.   Total
distributions during the nine months ended September 30, 2002 were  $24,000
of  which $21,600 was distributed to the limited partners and $2,400 to the
general partners.  The per unit distribution to limited partners during the
nine months ended September 30, 2002 was $7.66.

The  sources  for  the  2003  distributions of  $93,055  was  oil  and  gas
operations of approximately $81,700, a change in oil and gas properties  of
approximately  $42,100,  resulting  in excess  cash  for  contingencies  or
subsequent  distributions.   The  sources for  the  2002  distributions  of
$24,000  were  oil  and gas operations of approximately $27,500,  partially
offset  by  the  change  in oil and gas properties of  approximately  $700,
resulting in excess cash for contingencies or subsequent distributions.

Since  inception  of  the  Partnership, cumulative  cash  distributions  of
$1,360,972  have  been  made to the partners.  As of  September  30,  2003,
$1,240,100 or $439.60 per limited partner unit has been distributed to  the
limited partners, representing an 88% return of the capital contributed.

As  of  September  30, 2003, the Partnership had approximately  $47,200  in
working  capital.   The  Managing  General  Partner  knows  of  no  unusual
contractual  commitments.  Although the partnership  held  many  long-lived
properties   at  inception,  because  of  the  restrictions   on   property
development  imposed by the partnership agreement, the  Partnership  cannot
develop   its   non-producing  properties,  if  any.    Without   continued
development,  the producing reserves continue to deplete.  Accordingly,  as
the  Partnership's properties have matured and depleted, the net cash flows
from  operations  for  the  partnership has steadily  declined,  except  in
periods  of  substantially  increased commodity  pricing.   Maintenance  of
properties  and administrative expenses for the Partnership are  increasing
relative to production.  As the properties continue to deplete, maintenance
of  properties  and administrative costs as a percentage of production  are
expected to continue to increase.

The  Managing General Partner has examined various alternatives to  address
the  issue of depleting producing reserves.  Continuing operations  exposes
the   partnership  to  an  inevitable  decline  in  operating  results  and
distributions  of  cash.   Liquidating  the  partnership  would  result  in
immediate  realization of cash for limited partners,  but  prices  paid  by
purchasers  of Partnership property in liquidation would likely  include  a
substantial  discount  for risks and uncertainties of  future  cash  flows.
After   reviewing  various  alternatives,  the  Managing  General   Partner
initiated a plan to merge the Partnership and 20 other limited partnerships
with  and  into  the Managing General Partner.  On October  17,  2002,  the
Managing  General Partner filed a Registration Statement on form  S-4  with
the  Securities  and Exchange Commission relating to this proposed  merger.
There  is  no  assurance, however, that this merger  will  be  consummated.
Currently  the  Managing General Partner is evaluating whether  or  not  to
continue to pursue the proposed merger.


<PAGE>
Liquidity - Managing General Partner
In  previous  reports  the Partnership provided that the  Managing  General
Partner  had  $124.0  million  of principal  scheduled  to  mature  between
December 31, 2002 and December 31, 2004.  Subsequent to September 30,  2003
the   Managing  General  Partner  refinanced  the  majority  of  its   debt
obligations and currently has $71.7 million in debt scheduled to mature  on
June  1, 2006 and $40.0 million in debt scheduled to mature on October  15,
2008.   The  Managing General Partner believes that it  has  adequate  cash
flows to meet its debt principal maturities scheduled for 2004.

Recent Accounting Pronouncements

The  FASB  has  issued Statement No. 143 "Accounting for  Asset  Retirement
Obligations" which establishes requirements for the accounting of  removal-
type  costs  associated with asset retirements.  The standard is  effective
for  fiscal  years beginning after June 15, 2002, with earlier  application
encouraged.   This statement has been adopted by the Partnership  effective
January 1, 2003.  The transition adjustment resulting from the adoption  of
SFAS  No.  143  has been reported as a cumulative effect  of  a  change  in
accounting principle.

In  April 2003, the FASB issued Statement of Financial Accounting Standards
No.  149,  Amendment  of  Statement No. 133 on Derivative  Instruments  and
Hedging Activities ("SFAS No. 149").  SFAS No. 149 amendments require  that
contracts  with  comparable  characteristics be  accounted  for  similarly,
clarifies   when   a  contract  with  an  initial  investment   meets   the
characteristic  of  a  derivative and clarifies when a derivative  requires
special  reporting  in  the  statement of cash  flows.   SFAS  No.  149  is
effective  for  hedging relationships designated and for contracts  entered
into or modified after June 30, 2003, except for provisions that relate  to
SFAS  No. 133 Statement Implementation Issues that have been effective  for
fiscal  quarters  prior to June 15, 2003, should be applied  in  accordance
with  their  respective effective dates and certain provisions relating  to
forward  purchases or sales of when-issued securities or  other  securities
that  do not yet exist, should be applied to existing contracts as well  as
new contracts entered into after June 30, 2003.  Assessment by the Managing
General  Partner  revealed this pronouncement to  have  no  impact  on  the
Partnership.

In  May  2003, the FASB issued Statement of Financial Accounting  Standards
No.150,  Accounting for Certain Financial Instruments with  Characteristics
of  both  Liabilities  and  Equity  ("SFAS  150").   SFAS  150  establishes
standards  for  how  an  issuer classifies and measures  certain  financial
instruments  with  characteristics of  both  liabilities  and  equity.   It
requires that an issuer classify a financial instrument that is within  the
scope of SFAS 150 as a liability (or an asset in some circumstances).  Many
of those instruments were previously classified as equity.  The application
of  SFAS 150 is not expected to have a material effect on the Partnership's
consolidated  financial  statements.   This  Statement  is  effective   for
financial  instruments entered into or modified after  May  31,  2003,  and
otherwise  is  effective  at  the beginning of  the  first  interim  period
beginning after June 15, 2003.


<PAGE>
Item 3.   Quantitative and Qualitative Disclosures About Market Risk

The  Partnership  is  not a party to any derivative or embedded  derivative
instruments.

Item 4.   Controls and Procedures

(a)   Evaluation  of  Disclosure  Controls  and  Procedures.   The   senior
management of the Partnership's Managing General Partner is responsible for
establishing and maintaining a system of disclosure controls and procedures
(as defined in Rule 13a-14 and 15d-14 under the Securities Exchange Act  of
1934 (the "Exchange Act")) designed to ensure that information required  to
be  disclosed  by the Partnership in the reports that it files  or  submits
under  the  Exchange Act is recorded, processed, summarized  and  reported,
within   the  time  periods  specified  in  the  Securities  and   Exchange
Commission's rules and forms.  Disclosure controls and procedures  include,
without  limitation,  controls  and  procedures  designed  to  ensure  that
information required to be disclosed by the issuer in the reports  that  it
files or submits under the Exchange Act is accumulated and communicated  to
the  issuer's  management,  including its principal  executive  officer  of
officers  and principal financial officer or officers, or person performing
similar  functions,  as  appropriate to allow  timely  decisions  regarding
required disclosure.

In  accordance  with Exchange Act Rules 13a-15 and 15d-15, the  Partnership
carried  out  an evaluation, with the participation of the Chief  Executive
Officer  and  Chief Financial Officer of the Managing General  Partner,  as
well as other key members of the Managing General Partner's management,  of
the  effectiveness of the Partnership's disclosure controls and  procedures
as  of  the  end  of  the  period covered by this report.   Based  on  that
evaluation,  the  Managing General Partner's Chief  Executive  Officer  and
Chief   Financial  Officer  concluded  that  the  Partnership's  disclosure
controls and procedures were effective, as of the end of the period covered
by  this  report, to provide reasonable assurance that information required
to  be disclosed in the Partnership's reports filed or submitted under  the
Exchange  Act  is recorded, processed, summarized and reported  within  the
time  periods  specified in the Securities and Exchange Commission's  rules
and forms.

(b)  Changes in Internal Controls.  There have not been any changes in  the
Partnership's  internal  controls over financial  reporting  identified  in
connection  with  the evaluation described above that occurred  during  the
Partnership's  last  fiscal  quarter that has materially  affected,  or  is
reasonably  likely  to  materially affect,  these  internal  controls  over
financial reporting.

<PAGE>

                        PART II - OTHER INFORMATION


Item 1.  Legal Proceedings

         None

Item 2.  Changes in Securities

         None

Item 3.  Defaults Upon Senior Securities

         None

Item 4.  Submission of Matter to a Vote of Security Holders

         None

Item 5.  Other Information

         None

Item 6.  Exhibits and Reports on Form 8-K

        (a)  Exhibits:

               31.1 Rule 13a-14(a)/15d-14(a) Certification
31.2 Rule 13a-14(a)/15d-14(a) Certification
               32.1 Certification of Chief Executive Officer Pursuant to
18 U.S.C. Section
                  1350, as
                  adopted  Pursuant  to Section 906 of  the  Sarbanes-Oxley
                  Act of 2002
               32.2 Certification of Chief Financial Officer Pursuant to 18
 U.S.C. Section
                  1350, as
                  adopted  Pursuant  to Section 906 of  the  Sarbanes-Oxley
                  Act of 2002


         (b) No reports on Form 8-K were filed during the quarter for
             which this report is filed.



<PAGE>

                                SIGNATURES


Pursuant  to the requirements of the Securities Exchange Act of  1934,  the
registrant  has duly caused this report to be signed on its behalf  by  the
undersigned thereunto duly authorized.

                                   Southwest Oil and Gas Income Fund XI-A,
                                   L.P.
                                   a Delaware limited partnership

                                   By:  Southwest Royalties, Inc.
                                        Managing General Partner


                                   By:  /s/ Bill E. Coggin
                                        ------------------------------
                                        Bill E. Coggin, Executive Vice
President
                                        and Chief Financial Officer

Date:     November 14, 2003

<PAGE>
                    SECTION 302 CERTIFICATION                Exhibit 31.1


I, H.H. Wommack, III, certify that:

1.  I  have reviewed this quarterly report on Form 10-Q of Southwest Oil  &
Gas Income Fund XI-A, L.P.

2.Based  on my knowledge, this report does not contain any untrue statement
  of  a  material fact or omit to state a material fact necessary  to  make
  the  statements  made,  in light of the circumstances  under  which  such
  statements  were made, not misleading with respect to the period  covered
  by this report;

3.Based  on  my  knowledge, the financial statements, and  other  financial
  information  included  in  this report, fairly present  in  all  material
  respects  the financial condition, results of operations and  cash  flows
  of the registrant as of, and for, the periods presented in this report;

4.The  registrant's other certifying officer(s) and I are  responsible  for
  establishing  and  maintaining disclosure  controls  and  procedures  (as
  defined  in  Exchange  Act  Rules 13a-15(e) and  15-15(e))  and  internal
  control  over financial reporting (as defined in Exchange Act Rules  13a-
  15(f) and 15d-15(f) for the registrant and have:

  a)Designed  such  disclosure  controls and  procedures,  or  caused  such
     disclosure   controls  and  procedures  to  be  designed   under   our
     supervision,  to  ensure  that material information  relating  to  the
     registrant, including its consolidated subsidiaries, is made known  to
     us  by others within those entities, particularly during the period in
     which this report is being prepared;

  b)Designed  such  internal control over financial  reporting,  or  caused
     such  internal  control over financial reporting to be designed  under
     our   supervision,  to  provide  reasonable  assurance  regarding  the
     reliability  of financial reporting and the preparation  of  financial
     statements for external purposes in accordance with generally accepted
     accounting principles;

  c)Evaluated  the  effectiveness of the registrant's  disclosure  controls
     and  procedures and presented in this report our conclusions about the
     effectiveness of the disclosure controls and procedures, as of the end
     of the period covered by this report based on such evaluation; and

  d)Disclosed  in  this  report  any change in  the  registrant's  internal
     control over financial reporting that occurred during the registrant's
     most recent fiscal quarter (the registrant's fourth fiscal quarter  in
     the  case  of  an annual report) that has materially affected,  or  is
     reasonably  likely  to  materially affect, the  registrant's  internal
     control over financial reporting; and

5.The  registrant's other certifying officer(s) and I have disclosed, based
  on  our  most  recent  evaluation  of  internal  control  over  financial
  reporting,  to  the  registrant's auditors and  the  audit  committee  of
  registrant's  board  of directors (or persons performing  the  equivalent
  functions):

  a)All  significant deficiencies and material weaknesses in the design  or
     operation   of  internal  controls  over  financial  reporting   which
     reasonably  likely  to  adversely affect the registrant's
 ability  to
     record, process, summarize and report financial information; and

  b)Any  fraud, whether or not material, that involves management or  other
     employees  who  have  a significant role in the registrant's
 internal
     controls over financial reporting.


Date:  November 14, 2003           /s/ H. H. Wommack, III
                                   H. H. Wommack, III
                                    Chairman, President and Chief Executive
Officer
                                   of Southwest Royalties, Inc., the
                                   Managing General Partner of
                                    Southwest  Oil & Gas Income Fund  XI-A,
L.P.



<PAGE>
                    SECTION 302 CERTIFICATION                Exhibit 31.2


I, Bill E. Coggin, certify that:

1.  I  have reviewed this quarterly report on Form 10-Q of Southwest Oil  &
Gas Income Fund XI-A, L.P.

2.Based  on my knowledge, this report does not contain any untrue statement
  of  a  material fact or omit to state a material fact necessary  to  make
  the  statements  made,  in light of the circumstances  under  which  such
  statements  were made, not misleading with respect to the period  covered
  by this report;

3.Based  on  my  knowledge, the financial statements, and  other  financial
  information  included  in  this report, fairly present  in  all  material
  respects  the financial condition, results of operations and  cash  flows
  of the registrant as of, and for, the periods presented in this report;

4.The  registrant's other certifying officer(s) and I are  responsible  for
  establishing  and  maintaining disclosure  controls  and  procedures  (as
  defined  in  Exchange  Act  Rules 13a-15(e) and  15-15(e))  and  internal
  control  over financial reporting (as defined in Exchange Act Rules  13a-
  15(f) and 15d-15(f) for the registrant and have:

  a)Designed  such  disclosure  controls and  procedures,  or  caused  such
     disclosure   controls  and  procedures  to  be  designed   under   our
     supervision,  to  ensure  that material information  relating  to  the
     registrant, including its consolidated subsidiaries, is made known  to
     us  by others within those entities, particularly during the period in
     which this report is being prepared;

  b)Designed  such  internal control over financial  reporting,  or  caused
     such  internal  control over financial reporting to be designed  under
     our   supervision,  to  provide  reasonable  assurance  regarding  the
     reliability  of financial reporting and the preparation  of  financial
     statements for external purposes in accordance with generally accepted
     accounting principles;

  c)Evaluated  the  effectiveness of the registrant's  disclosure  controls
     and  procedures and presented in this report our conclusions about the
     effectiveness of the disclosure controls and procedures, as of the end
     of the period covered by this report based on such evaluation; and

  d)Disclosed  in  this  report  any change in  the  registrant's  internal
     control over financial reporting that occurred during the registrant's
     most recent fiscal quarter (the registrant's fourth fiscal quarter  in
     the  case  of  an annual report) that has materially affected,  or  is
     reasonably  likely  to  materially affect, the  registrant's  internal
     control over financial reporting; and

5.The  registrant's other certifying officer(s) and I have disclosed, based
  on  our  most  recent  evaluation  of  internal  control  over  financial
  reporting,  to  the  registrant's auditors and  the  audit  committee  of
  registrant's  board  of directors (or persons performing  the  equivalent
  functions):

  a)All  significant deficiencies and material weaknesses in the design  or
     operation   of  internal  controls  over  financial  reporting   which
     reasonably  likely  to  adversely affect the registrant's  ability  to
     record, process, summarize and report financial information; and

  b)Any  fraud, whether or not material, that involves management or  other
     employees  who  have  a significant role in the registrant's  internal
     controls over financial reporting.


Date:  November 14, 2003           /s/ Bill E. Coggin
                                   Bill E. Coggin
                                   Executive Vice President
                                   and Chief Financial Officer of
                                   Southwest Royalties, Inc., the
                                   Managing General Partner of
                                    Southwest  Oil & Gas Income Fund  XI-A,
L.P.



<PAGE>

                         CERTIFICATION PURSUANT TO
                               Exhibit 32.1
                          19 U.S.C. SECTION 1350,
                          AS ADOPTED PURSUANT TO
               SECTION 906 OF THE SARBANES-OXLEY ACT OF 2002


      In connection with the Quarterly Report of Southwest Oil & Gas Income
Fund  XI-A, Limited Partnership (the "Company") on Form 10-Q for the period
ending  September  30,  2003  as filed with  the  Securities  and  Exchange
Commission  on the date hereof (the "Report"), I, H.H. Wommack, III,  Chief
Executive Officer of the Managing General Partner of the Company,  certify,
pursuant  to 18 U.S.C.  1350, as adopted pursuant to  906 of the  Sarbanes-
Oxley Act of 2002, that:

  (1)   The Report fully complies with the requirements of section 13(a) or
     15(d) of the Securities Exchange Act of 1934; and

  (2)   The  information  contained in the Report fairly presents,  in  all
     material respects, the financial condition and results of operation of the
     Company.


Date:  November 14, 2003




/s/ H.H. Wommack, III
H. H. Wommack, III
Chairman, President, Director and Chief Executive Officer
  of Southwest Royalties, Inc., the
  Managing General Partner of
  Southwest Oil & Gas Income Fund XI-A, L.P.

<PAGE>
           CERTIFICATION PURSUANT TO               Exhibit 32.2
                          19 U.S.C. SECTION 1350,
                          AS ADOPTED PURSUANT TO
               SECTION 906 OF THE SARBANES-OXLEY ACT OF 2002


   In  connection with the Quarterly Report of Southwest Oil &  Gas  Income
Fund  XI-A, Limited Partnership (the "Company") on Form 10-Q for the period
ending  September  30,  2003  as filed with  the  Securities  and  Exchange
Commission  on  the date hereof (the "Report"), I, Bill  E.  Coggin,  Chief
Financial Officer of the Managing General Partner of the Company,  certify,
pursuant  to 18 U.S.C.  1350, as adopted pursuant to  906 of the  Sarbanes-
Oxley Act of 2002, that:

  (1)   The Report fully complies with the requirements of section 13(a) or
     15(d) of the Securities Exchange Act of 1934; and

  (2)   The  information  contained in the Report fairly presents,  in  all
     material respects, the financial condition and results of operation of the
     Company.


Date:  November 14, 2003




/s/ Bill E. Coggin
Bill E. Coggin
Executive Vice President
  and Chief Financial Officer of
  Southwest Royalties, Inc., the
  Managing General Partner of
  Southwest Oil & Gas Income Fund XI-A, L.P.


<PAGE>