Page 24 of 24
                               FORM 10-Q/A
                             AMENDMENT NO. 1


                    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 March 31, 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 & 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      No_X_

        The total number of pages contained in this report is 24.

<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 Form
10-K/A  Report for 2002 filed with the Securities and Exchange  Commission.
The December 31, 2002 balance sheet included herein has been taken from the
Registrant's  2002  Form 10-K/A Report.  Operating results  for  the  three
month  period  ended March 31, 2003 are not necessarily indicative  of  the
results that may be expected 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.  Subsequent  to  the
filing  of the Partnership's Quarterly Report on Form 10-Q, the Partnership
discovered an omission in the calculation of the asset retirement liability
and  therefore  has restated it's unaudited condensed financial  statements
for  the  period  ended  March  31, 2003 as described  in  Note  5  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  period
ended March 31, 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 period ended March  31,
2002.

<PAGE>
                Southwest Oil & Gas Income Fund XI-A, L.P.
                              Balance Sheets

                                  March    December
                                   31,       31,
                                   2003      2002
                                 (Restate
                                    d)
                                   ----      ----
                                 (unaudit
                                   ed)
Assets
---------
Current assets:
 Cash and cash equivalents    $  23,653    17,179
  Receivable  from  Managing     31,663    24,291
General Partner
                                 --------  --------
                                 -----     -----
   Total current assets          55,316    41,470
                                 --------  --------
                                 -----     -----
Oil  and  gas  properties  -
using the full-
 cost method of accounting       1,087,24  1,053,59
                                 8         6
       Less      accumulated
depreciation,
         depletion       and     819,236   838,555
amortization
                                 --------  --------
                                 -----     -----
      Net   oil   and    gas     268,012   215,041
properties
                                 --------  --------
                                 -----     -----
                              $  323,328   256,511
                                 =======   =======

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

Current liability:
 Distribution payable         $  -         46
                                 --------  --------
                                 -----     -----
Other long term liabilities      64,970    -
                                 --------  --------
                                 -----     -----

Partners' equity:
 General partners                (3,350)   (4,038)
 Limited partners                261,708   260,503
                                 --------  --------
                                 -----     -----
   Total partners' equity        258,358   256,465
                                 --------  --------
                                 -----     -----
                              $  323,328   256,511
                                 =======   =======

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

                                    Three Months Ended
                                        March 31,
                                      2003      2002
                                    (Restate  (Restate
                                       d)        d)
                                     -----     -----
Revenues
------------
 Oil and gas                     $  62,391    33,034
 Interest                           34        24
                                    --------  --------
                                    -         -
                                    62,425    33,058
                                    --------  --------
                                    -         -
Expenses
------------
 Production                         26,712    14,238
 General and administrative         4,320     4,196
  Depreciation,  depletion  and     5,000     6,000
amortization
 Accretion                          1,274     -
                                    --------  --------
                                    -         -
                                    37,306    24,434
                                    --------  --------
                                    -         -
Net  income  before  cumulative     25,119    8,624
effect

Cumulative effect of change  in
accounting
 principle - SFAS No. 143 - See     (5,725)   -
Note 3
Cumulative effect of change  in
accounting principle
 - change in depletion method -     -         1,000
See Note 4
                                    --------  --------
                                    -         -
Net income                       $  19,394    9,624
                                    =====     =====
Net income allocated to:

 Managing General Partner        $  2,195     1,316
                                    =====     =====
 General partner                 $  244       146
                                    =====     =====
 Limited partners                $  16,955    8,162
                                    =====     =====
    Per  limited  partner  unit  $     7.84
before cumulative effect                      2.54
     Cumulative   effects   per      (1.83)       .35
limited partner unit
                                    --------  --------
                                    -         -
  Per limited partner unit       $     6.01
                                              2.89
                                    =====     =====
Pro   forma  amounts   assuming
changes are applied
 retroactively (See Note 3):
  Net  income before cumulative  $  -         7,191
effect
                                    =====     =====
    Per  limited  partner  unit  $  -            2.08
(2,821.0)
                                    =====     =====
 Net income                      $  -         8,191
                                    =====     =====
    Per  limited  partner  unit  $  -            2.43
(2,821.0)
                                    =====     =====
<PAGE>
                Southwest Oil & Gas Income Fund XI-A, L.P.
                         Statements of Cash Flows
                               (unaudited)

                                      Three Months Ended
                                          March 31,
                                        2003      2002
                                      (Restate  (Restate
                                         d)        d)
                                       -----     -----
Cash    flows   from    operating
activities:

  Cash received from oil and  gas  $  49,667    35,379
sales
 Cash paid to suppliers               (25,681)  (35,439)
 Interest received                    34        24
                                      --------  --------
                                      -         -
   Net cash provided by (used in)     24,020    (36)
operating activities
                                      --------  --------
                                      -         -
Cash  flows provided by investing
activities:

 Sale of oil and gas properties       -         1,047
                                      --------  --------
                                      -         -
Cash   flows  used  in  financing
activities:

 Distributions to partners            (17,546)  (6,023)
                                      --------  --------
                                      -         -
Net  increase (decrease) in  cash     6,474     (5,012)
and cash equivalents

 Beginning of period                  17,179    13,139
                                      --------  --------
                                      -         -
 End of period                     $  23,653    8,127
                                      =====     =====
Reconciliation of net  income  to
net cash
  provided by (used in) operating
activities:

Net income                         $  19,394    9,624

Adjustments   to  reconcile   net
income to net
   cash  provided  by  (used  in)
operating activities:

   Depreciation,  depletion   and     5,000     6,000
amortization
 Accretion                            1,274     -
  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
     (Increase)    decrease    in     (12,724)  2,345
receivables
  Increase (decrease) increase in     5,351     (17,005)
payables
                                      --------  --------
                                      -         -
Net  cash  provided by (used  in)  $  24,020    (36)
operating activities
                                      =====     =====
Noncash  investing and  financing
activities:

   Increase   in  oil   and   gas
properties - Adoption
  of SFAS No.143                   $  57,971    -
                                      ======    ======

<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    100%       -
offering expenses (2)
Acquisition costs          100%       -
Operating costs            90%       10%
Administrative    costs    90%       10%
(3)
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.


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

                      Notes to Financial Statements


2.   Summary of Significant Accounting Policies
     The  interim financial information as of March 31, 2003, and  for  the
     three  months ended March 31, 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/A 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 Annual
     Report on Form 10-K/A for the year ended December 31, 2002.

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 March  31,
     2003, the asset retirement obligation was $64,970, and the increase in
     the  balance  from  January  1, 2003 of $1,274  is  due  to  accretion
     expense.   The pro forma amounts for the three months ended March  31,
     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 months ended March 31, 2003  and
     2002  has  been calculated using the units-of-production method.   The
     effect  of the change on the three months ended March 31, 2002 was  to
     decrease  income  before cumulative effect of a change  in  accounting
     principle by $2,000 ($.71 per limited partner unit) and net income  by
     $1,000 ($.35 per limited partner unit).

<PAGE>

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

                      Notes to Financial Statements


5.   March 31, 2003 Restatement
     On  January  1, 2003, the Partnership adopted Statement  of  Financial
     Accounting Standards No. 143 as described in Note 3.

     Subsequent  to the issuance of the Partnership's Quarterly  Report  on
     Form  10-Q  for the three months ended March 31, 2003, the Partnership
     determined  that  it  did not properly discount the  estimated  future
     plugging liability to its present value.

     This  change  in the calculation used to determine the amount  of  the
     Partnership's asset retirement liability under SFAS No.  143  resulted
     in a decrease in the Partnership's previously reported other long term
     liability of $72,252 from $137,222 to $64,970 as of March 31, 2003 and
     did  not  effect  the Partnership's 2003 cash flows  from  operations,
     investing or financing activities.

     The  change  had the following effects on the Statement of  Operations
     for  the  three months ended March 31, 2003.  (Periods prior  to  2003
     were not affected by the change).

                                        Restated      Previously
                                                       Reported
     Accretion                        $1,274         2,691
     Income before cumulative effect  25,119         23,702
   Cumulative effect of change in     (5,725)        (89,767)
     accounting principle
     Net income (loss)                19,394         (66,065)
     Net income (loss) allocated
     to:
     Managing General Partner         2,195          (3,308)
     General partner                  244            (368)
     Limited partners                 16,955         (62,389)
       Income (loss) per limited
     partner unit before
         cumulative effect            7.84           (22.12)
       Cumulative effect per          (1.83)         -
     limited partner unit
       Net income (loss) per          6.01           (22.12)
     limited partner unit


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

                      Notes to Financial Statements


6.   March 31, 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.

     Subsequent  to the issuance of the Partnership's Quarterly  Report  on
     Form  10-Q  for the three months ended March 31, 2003, the Partnership
     determined that the above change in accounting method should have been
     adopted  by  the  Partnership as a cumulative effect of  a  change  in
     accounting principle effective as of January 1, 2002.  The Partnership
     had  previously  applied  the change in the method  of  providing  for
     depletion prospectively as of October 1, 2002.

     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 months ended March 31, 2002.

                                        Restated      Previously
                                                       Reported
     Depreciation, depletion and      $6,000         4,000
     amortization
     Income (loss) before cumulative  8,624          10,624
     effect
   Cumulative effect of change in     1,000          -
     accounting principle
     Net income (loss)                9,624          10,624
     Net income (loss) allocated
     to:
     Managing General Partner         1,316          1,316
     General partner                  146            146
     Limited partners                 8,162          9,162
       Income (loss) per limited
     partner unit before
         cumulative effect            2.54           3.25
       Cumulative effect per          .35            -
     limited partner unit
       Net income (loss) per          2.89           3.25
     limited partner unit

<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.  The economic life of the Partnership thus depends
on  the  period  over  which the Partnership's oil  and  gas  reserves  are
economically recoverable.

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.   The  effect of this change in method  was  to  increase
depletion  expense for the three months ended March 31, 2002 by $2,000  and
decrease  net income for the three months ended March 31, 2002  by  $1,000.
See Note 4 of the notes to the Partnership's financial statements.

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 March 31, 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  on  an  annual  basis  prepared  by  outside  consultants.
Quarterly  reserve estimates are prepared by the Managing General Partner's
internal staff of engineers.

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  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
is  not 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.   The  effect of this change in method  was  to  increase
depletion  expense for the three months ended March 31, 2002 by $2,000  and
decrease net income for the three months ended March 31, 2002 by $1,000.
<PAGE>

Results of Operations

A.  General Comparison of the Quarters Ended March 31, 2003 and 2002

The  following  table  provides certain information  regarding  performance
factors for the quarters ended March 31, 2003 and 2002.

                               Three Months
                                  Ended         Percenta
                                                   ge
                                March 31,       Increase
                              2003      2002    (Decreas
                                                   e)
                              ----      ----    --------
                                                   --
Average    price    per  $    32.11             66%
barrel of oil                         19.36
Average  price per  mcf  $     5.32             186%
of gas                                1.86
Oil    production    in     900       900       -
barrels
Gas production in mcf       6,300     8,400     (25%)
Gross   oil   and   gas  $  62,391    33,034    89%
revenue
Net oil and gas revenue  $  35,679    18,796    90%
Partnership              $  17,500    6,000     192%
distributions
Limited         partner  $  15,750    5,400     192%
distributions
Per  unit  distribution
to limited
 partners                $     5.58             192%
                                      1.91
Number    of    limited     2,821     2,821
partner units

Revenues

The  Partnership's oil and gas revenues increased to $62,391  from  $33,034
for  the  quarters ended March 31, 2003 and 2002, respectively, an increase
of  89%.   The  principal factors affecting the comparison of the  quarters
ended March 31, 2003 and 2002 are as follows:

1.  The  average  price  for a barrel of oil received  by  the  Partnership
    increased  during the quarter ended March 31, 2003 as compared  to  the
    quarter ended March 31, 2002 by 66%, or $12.75 per barrel, resulting in
    an   increase  of  approximately  $11,500  in  revenues.    Oil   sales
    represented  46%  of total oil and gas sales during the  quarter  ended
    March  31,  2003 as compared to 53% during the quarter ended March  31,
    2002.

    The  average  price  for  an  mcf of gas received  by  the  Partnership
    increased  during the same period by 186%, or $3.46 per mcf,  resulting
    in an increase of approximately $21,800 in revenues.

    The  total  increase in revenues due to the change in  prices  received
    from oil and gas production is approximately $33,300.  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 remained unchanged during the quarter ended  March  31,
    2003 as compared to the quarter ended March 31, 2002.

    Gas production decreased approximately 2,100 mcf or 25% during the same
    period, resulting in a decrease of approximately $3,900 in income  from
    net profits interests.

    The  total  decrease  in revenues due to the change  in  production  is
    approximately $3,900.  The decrease in gas production is primarily  due
    to  one lease, which the wells were shut in during 2002, and production
    is being slowly brought back on.

Costs and Expenses

Total costs and expenses increased to $37,306 from $24,434 for the quarters
ended  March  31,  2003 and 2002, respectively, an increase  of  53%.   The
increase  is a direct result of the accretion expense associated  with  our
long  term liability related to expected abandonment costs of our  oil  and
natural  gas  properties, lease operating costs, general and administrative
expense.

1.  Lease  operating  costs  and  production  taxes  were  88%  higher,  or
    approximately $12,500 more during the quarter ended March 31,  2003  as
    compared  to the quarter ended March 31, 2002.  The increase  in  lease
    operating expense and production taxes is due primarily to repairs  and
    maintenance on several leases, and the increase in production taxes  in
    relation to the increase in gross revenues received in 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 3%
    or  approximately  $100  during the quarter ended  March  31,  2003  as
    compared to the quarter ended March 31, 2002.

3.  Depletion  expense decreased to $5,000 for the quarter ended March  31,
    2003  from  $6,000  for  the same period in 2002.   This  represents  a
    decrease  of  17%.   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 March 31, 2002 by $2,000 and decrease net income for
    the  three  months  ended March 31, 2002 by $1,000.   The  contributing
    factor  to the decrease in depletion expense is in relation to the  BOE
    depletion  rate for the quarter ended March 31, 2003, which  was  $2.56
    applied to 1,950 BOE as compared to $2.61 applied to 2,300 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 March 31, 2003, the asset retirement  obligation
was $64,970, and the increase in the balance from January 1, 2003 of $1,274
is  due  to accretion expense.  The pro forma amounts for the three  months
ended March 31, 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 (used in) operating activities were  approximately
$24,000  in  the quarter ended March 31, 2003 as compared to  approximately
$(36)  in  the  quarter ended March 31, 2002.  The primary source  of  cash
flows from operating activities was profitable operations.

There  were not cash flows provided by investing activities in the  quarter
ended  March  31,  2003.  Cash flows provided by investing activities  were
approximately $1,000 in the quarter ended March 31, 2002.

Cash  flows used in financing activities were $17,500 in the quarter  ended
March  31, 2003 as compared to $6,000 in the quarter ended March 31,  2002.
The only use in financing activities was the distributions to partners.

Total distributions during the quarter ended March 31, 2003 were $17,500 of
which  $15,750  was distributed to the limited partners and $1,750  to  the
general partners.  The per unit distribution to limited partners during the
quarter  ended  March 31, 2003 was $5.58.  Total distributions  during  the
quarter ended March 31, 2002 were $6,000 of which $5,400 was distributed to
the  limited  partners  and $600 to the general  partners.   The  per  unit
distribution  to limited partners during the quarter ended March  31,  2002
was $1.91.

The  sources  for  the  2003  distributions of $17,500  were  oil  and  gas
operations  of  approximately  $24,000,  resulting  in  excess   cash   for
contingencies or subsequent distributions to partners.  The sources for the
2002  distributions  of  $6,000  were net of  oil  and  gas  operations  of
approximately   $(36)  and  the  change  of  oil  and  gas  properties   of
approximately $1,000, with the balance from available cash on hand  at  the
beginning of the period.

Since  inception of the Partnership, cumulative monthly cash  distributions
of  $1,285,417  have  been made to the partners.  As  of  March  31,  2003,
$1,170,045 or $414.76 per limited partner unit has been distributed to  the
limited partners, representing a 83% return of the capital contributed.

As  of March 31, 2003, the Partnership had approximately $55,300 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,  as
well  as  any development risks.  After reviewing various alternatives,  we
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.

<PAGE>
Liquidity - Managing General Partner

The  Managing General Partner has a highly leveraged capital structure with
approximately $124.0 million of principal due between December 31, 2002 and
December  31, 2004.  The Managing General Partner is constantly  monitoring
its cash position and its ability to meet its financial obligations as they
become due, and in this effort, is continually exploring various strategies
for  addressing  its  current  and future liquidity  needs.   The  Managing
General Partner regularly pursues and evaluates recapitalization strategies
and  acquisition  opportunities  (including  opportunities  to  engage   in
mergers,  consolidations or other business combinations) and at  any  given
time may be in various stages of evaluating such opportunities.

Based   on  current  production,  commodity  prices  and  cash  flow   from
operations,  the Managing General Partner has adequate cash  flow  to  fund
debt  service, developmental projects and day to day operations, but it  is
not  sufficient  to  build a cash balance which would  allow  the  Managing
General  Partner to meet its debt principal maturities scheduled for  2004.
Therefore  the Managing General Partner is currently seeking to renegotiate
the  terms  of its obligations, including extending maturity dates,  or  to
engage  new  lenders or equity investors in order to satisfy its  financial
obligations maturing in 2004.

There  can  be  no  assurance  that  the Managing  General  Partner's  debt
restructuring efforts will be successful.  In the event these  efforts  are
unsuccessful,  the Managing General Partner would need  to  look  to  other
alternatives  to  meet its debt obligations, including potentially  selling
its  assets.  There can be no assurance, however, that the sales of  assets
can  be  successfully  accomplished on terms  acceptable  to  the  Managing
General Partner.  Please see the Partnership's Quarterly Report on Form 10-
Q  for  the quarterly period ended September 30, 2003, which will be  filed
with the Commission on or before November 14, 2003, for updated information
on  the  liquidity of the Managing General Partner.  The liquidity  of  the
Managing General Partner, however, does not have a material impact  on  the
operations   of  the  Partnership.   The  partnership  agreement   of   the
Partnership  allows  the  limited partners to elect  a  successor  managing
general partner to continue Partnership operations.

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.

<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 chief executive
officer  and chief financial officer of the Partnership's managing  general
partner have evaluated the effectiveness of the design and operation of the
Partnership's  disclosure controls and procedures (as defined  in  Exchange
Act  Rule 13a-14(c)) as of a date within 90 days of the filing date of this
quarterly report. Based on that evaluation, the chief executive officer and
chief  financial  officer have concluded that the Partnership's  disclosure
controls  and procedures are effective to ensure that material  information
relating to the Partnership and the Partnership's consolidated subsidiaries
is   made   known  to  such  officers  by  others  within  these  entities,
particularly during the period this quarterly report was prepared, in order
to allow timely decisions regarding required disclosure.

(b)  Changes  in  Internal Controls.  There have not been  any  significant
changes  in  the Partnership's internal controls or in other  factors  that
could  significantly affect these controls subsequent to the date of  their
evaluation.

<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:

                    99.1 Certification pursuant to 18 U.S.C. Section 1350
               99.2 Certification pursuant to 18 U.S.C. Section 1350

               (b)  Reports on Form 8-K:

                     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 & 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, Vice President
                                   and Chief Financial Officer



Date:  November 12, 2003

<PAGE>
                              CERTIFICATIONS


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

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

          2.   Based on my knowledge, this quarterly 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 quarterly report;

          3.   Based on my knowledge, the financial statements,
and other financial
information  included  in  this quarterly 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
quarterly report;

          4.   The registrant's other certifying officers and I
are responsible for
establishing and maintaining disclosure controls and procedures (as defined
in Exchange Act Rules 13a-14 and 15d-14) for the registrant and we have:

          a)   designed such disclosure controls and procedures 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 quarterly report is being
          prepared;

          b)   evaluated the effectiveness of the registrant's
disclosure controls
          and procedures as of a date within 90 days prior
 to the filing date of this
          quarterly report (the "Evaluation Date"); and

          c)   presented in this quarterly report our conclusions about the
          effectiveness of the disclosure controls and procedures based on our
          evaluation as of the Evaluation Date;

          5.   The registrant's other certifying officers and I
have disclosed, based
on  our most recent evaluation, 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 in the design or
operation of internal
          controls which could adversely affect the
registrant's ability to record,
          process, summarize and report financial data and
 have identified for the
          registrant's auditors any material weaknesses in
internal controls; 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; and

          6.   The registrant's other certifying officers and I
 have indicated in
this  quarterly  report  whether or not there were significant  changes  in
internal  controls  or  in  other factors that could  significantly  affect
internal  controls  subsequent to the date of our most  recent  evaluation,
including  any  corrective actions with regard to significant  deficiencies
and material weaknesses.

Date:  November 12, 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>
                              CERTIFICATIONS

          I, Bill E. Coggin, certify that:

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

          2.   Based on my knowledge, this quarterly 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 quarterly report;

          3.   Based on my knowledge, the financial statements,
and other financial
     information included in this quarterly 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
     quarterly report;

          4.   The registrant's other certifying officers and I are
responsible for
     establishing and maintaining disclosure controls and procedures (as defined
     in Exchange Act Rules 13a-14 and 15d-14) for the registrant and we have:

          a)   designed such disclosure controls and procedures 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 quarterly report is being
          prepared;

          b)   evaluated the effectiveness of the registrant's
 disclosure controls
          and procedures as of a date within 90 days prior to
 the filing date of this
          quarterly report (the "Evaluation Date"); and

          c)   presented in this quarterly report our conclusions about the
          effectiveness of the disclosure controls and procedures based on our
          evaluation as of the Evaluation Date;

          5.   The registrant's other certifying officers and I have
 disclosed, based
     on our most recent evaluation, 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 in the design or
operation of internal
          controls which could adversely affect the registrant's
 ability to record,
          process, summarize and report financial data and
have identified for the
          registrant's auditors any material weaknesses in
 internal controls; 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; and

          6.   The registrant's other certifying officers
and I have indicated in
     this quarterly report whether or not there were significant changes in
     internal controls or in other factors that could significantly  affect
     internal controls subsequent to the date of our most recent evaluation,
     including any corrective actions with regard to significant deficiencies
     and material weaknesses.

Date:  November 12, 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
                          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/A  for  the
period  ending  March  31, 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 12, 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.

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                         CERTIFICATION PURSUANT TO
                          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/A  for  the
period  ending  March  31  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 12, 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.


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