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                               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 33-47668-01

         SOUTHWEST ROYALTIES INSTITUTIONAL 1992-93 INCOME PROGRAM
         Southwest Royalties Institutional Income Fund XI-A, L.P.
                  (Exact name of registrant as specified
                  in its limited partnership agreement)

Delaware                                75-2427297
(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.

     Net Profits Interest.  An agreement whereby the owner receives a
specified  percentage  of the defined net profits  from  a  producing
property  in  exchange  for  consideration  paid.   The  net  profits
interest owner will not otherwise participate in additional costs and
expenses of the property.

     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 Royalties Institutional 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    $  23,489    21,429
  Receivable  from  Managing     58,031    43,838
General Partner
 Distribution receivables        -         5
                                 --------  --------
                                 -----     -----
   Total current assets          81,520    65,272
                                 --------  --------
                                 -----     -----
Oil  and  gas  properties  -
using the full-
 cost method of accounting       2,097,17  2,029,76
                                 9         9
       Less      accumulated
depreciation,
         depletion       and     1,708,40  1,714,86
amortization                     5         2
                                 --------  --------
                                 -----     -----
      Net   oil   and    gas     388,774   314,907
properties
                                 --------  --------
                                 -----     -----
                              $  470,294   380,179
                                 ========  =======
Liabilities  and   Partners'
Equity
----------------------------
----

Current     liability      -  $  67        -
Distribution payable
                                 --------  --------
                                 -----     -----
Other long term liabilities      129,956   -
                                 --------  --------
                                 -----     -----

Partners' equity:
 General partners                (29,374)  (26,083)
 Limited partners                369,645   406,262
                                 --------  --------
                                 -----     -----
   Total partners' equity        340,271   380,179
                                 --------  --------
                                 -----     -----
                              $  470,294   380,179
                                 ========  ========

<PAGE>
         Southwest Royalties Institutional Income Fund XI-A, L.P.
                         Statements of Operations
                               (unaudited)

                                    Three Months Ended
                                        March 31,
                                      2003      2002
                                    (Restate  (Restate
                                       d)        d)
                                     -----     -----
Revenues
-------------
   Income   from  net   profits  $  66,458    30,280
interests
 Interest                           48        49
                                    --------  --------
                                    --
                                    66,506    30,329
                                    --------  --------
                                    --
Expenses
------------
 General and administrative         10,325    10,233
  Depreciation,  depletion  and     7,000     9,000
amortization
 Accretion                          2,548     -
                                    --------  --------
                                    --
                                    19,873    19,233
                                    --------  --------
                                    --
Net  income  before  cumulative     46,633    11,096
effect

Cumulative effect of change  in
accounting
 principle - SFAS No. 143 - See     (46,541)  -
Note 3
Cumulative effect of change  in
accounting principle
 - change in depletion method -     -         4,000
See Note 4
                                    --------  --------
                                    --
Net income                       $  92        15,096
                                    ======    =====
Net income (loss) allocated to:

 Managing General Partner        $  638       1,809
                                    ======    =====
 General partner                 $  71        201
                                    ======    =====
 Limited partners                $  (617)     13,086
                                    ======    =====
    Per  limited  partner  unit  $     7.62
before cumulative effect                      1.68
     Cumulative   effects   per      (7.73)       .74
limited partner unit
                                    --------  --------
                                    --
  Per limited partner unit       $    (.11)
                                              2.42
                                    ======    =====
Pro   forma  amounts   assuming
changes are applied
 retroactively (See Note 3):
   Net   income  (loss)  before  $  -         8,229
cumulative effect
                                    ======    =====
    Per  limited  partner  unit  $  -            1.20
(5,418.0)
                                    ======    =====
 Net income (loss)               $  -         12,229
                                    ======    =====
    Per  limited  partner  unit  $  -            1.94
(5,418.0)
                                    ======    =====

<PAGE>
         Southwest Royalties Institutional 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  $  51,992    28,963
sales
 Cash paid to suppliers               (10,052)  (22,564)
 Interest received                    48        49
  Cumulative effect of change  in               -
accounting principle
                                      --------  --------
                                                --
   Net cash provided by operating     41,988    6,448
activities
                                      --------  --------
                                                --
Cash   flows  used  in  financing
activities:

 Distributions to partners            (39,928)  (15,047)
                                      --------  --------
                                                --
Net  increase (decrease) in  cash     2,060     (8,599)
and cash equivalents

 Beginning of period                  21,429    22,949
                                      --------  --------
                                                --
 End of period                     $  23,489    14,350
                                      =====     ======

Reconciliation of net  income  to
net cash
     provided     by    operating
activities:

Net income                         $  92        15,096

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

   Depletion,  depreciation   and     7,000     9,000
amortization
 Accretion                            2,548     -
  Cumulative effect of change  in
accounting
  principle - SFAS No. 143            46,541    -
  Cumulative effect of change  in
accounting
  principle - change in depletion     -         (4,000)
method
 Increase in receivables              (14,466)  (1,317)
 Increase (decrease) in payables      273       (12,331)
                                      --------  --------
                                                --
Net  cash  provided by  operating  $  41,988    6,448
activities
                                      =====     ======
Noncash  investing and  financing
activities:

   Increase   in  oil   and   gas
properties - Adoption
  of SFAS No.143                   $  80,867    -
                                      ======    ======

<PAGE>
         Southwest Royalties Institutional Income Fund XI-A, L.P.
                     (a Delaware limited partnership)

                      Notes to Financial Statements


1.   Organization
     Southwest  Royalties Institutional 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 a 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 Royalties Institutional 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  $80,867, a long term liability  of  approximately
     $127,408  and a loss of approximately $46,541 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  $129,956  and  the
     increase in the balance from January 1, 2003 of $2,548 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 $4,000 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 $3,000 ($.55  per
     limited  partner unit) and increase net income by  $1,000  ($.18
     per limited partner unit).

<PAGE>
         Southwest Royalties Institutional 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 $115,280 from $245,236 to $129,956
     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                        $2,548         4,809
     Income before cumulative effect  46,633         44,372
   Cumulative effect of change in     (46,541)       (159,136)
     accounting principle
     Net income (loss)                92             (114,764)
     Net income (loss) allocated
     to:
     Managing General Partner         638            (5,861)
     General partner                  71             (651)
     Limited partners                 (617)          (108,252)
       Income (loss) per limited
     partner unit before
         cumulative effect            7.62           (19.98)
       Cumulative effect per          (7.73)         -
     limited partner unit
       Net income (loss) per          (0.11)         (19.98)
     limited partner unit


         Southwest Royalties Institutional 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  an increase in the Partnership's previously reported net oil
     and  gas  properties of $1,000 from $313,907 to $314,907  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      $9,000         6,000
     amortization
     Income before cumulative effect  11,096         14,096
   Cumulative effect of change in     4,000          -
     accounting principle
     Net income                       15,096         14,096
     Net income allocated to:
     Managing General Partner         1,809          1,809
     General partner                  201            201
     Limited partners                 13,086         12,086
       Income per limited partner
     unit before
         cumulative effect            1.68           2.23
       Cumulative effect per          .74            -
     limited partner unit
       Net income per limited         2.42           2.23
     partner unit


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

General

Southwest  Royalties  Institutional  Income  Fund  XI-A,  L.P.   (the
"Partnership"  or  "Registrant") 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 Royalties Institutional  1992-93
Income  Program.   Minimum capital requirements for  the  Partnership
were  met  on  December  10,  1992,  with  the  offering  of  limited
partnership  interests concluding April 30, 1993.  At the  conclusion
of  the  offering  of  limited  partnership  interests,  217  limited
partners had purchased 5,418 units for $2,709,000.

The  Partnership  was  formed  to acquire  royalty  and  net  profits
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 farm-out  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 11% 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 $3,000 and increase 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>
The  Partnership's interest in oil and gas properties consists of net
profits interests in proved properties located within the continental
United States.  A net profits interest is created when the owner of a
working  interest in a property enters into an arrangement  providing
that  the net profits interest owner will receive a stated percentage
of  the net profit from the property.  The net profits interest owner
will  not  otherwise participate in additional costs and expenses  of
the property.

The  Partnership recognizes income from its net profits  interest  in
oil  and  gas property on an accrual basis, while the quarterly  cash
distributions of the net profits interest are based on a  calculation
of  actual  cash  received from oil and gas sales,  net  of  expenses
incurred  during  that quarterly period. If the net profits  interest
calculation  results in expenses incurred exceeding the oil  and  gas
income received during a quarter, no cash distribution is due to  the
Partnership's  net  profits interest until the deficit  is  recovered
from future net profits.  The Partnership accrues a quarterly loss on
its  net  profits interest provided there is a cumulative net  amount
due  for  accrued revenue as of the balance sheet date.  As of  March
31,  2003,  there  were no timing differences, which  resulted  in  a
deficit net profit interest.

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 $3,000 and increase 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  $   31.89              71%
barrel of oil                         18.69
Average  price per  mcf  $    5.79              190%
of gas                                2.00
Oil    production    in     1,340     1,440     (7%)
barrels
Gas production in mcf       12,000    18,500    (35%)
Income from net profits  $  66,458    30,280    119%
interests
Partnership              $  40,000    15,000    167%
distributions
Limited         partner  $  36,000    13,500    167%
distributions
Per  unit  distribution
to limited
 partners                $    6.64              167%
                                      2.49
Number    of    limited     5,418     5,418
partner units

Revenues

The  Partnership's  income from net profits  interests  increased  to
$66,458 from $30,280 for the quarters ended March 31, 2003 and  2002,
respectively,  an increase of 119%.  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 71%, or $13.20 per  barrel,
    resulting in an increase of approximately $17,700 in income  from
    net  profits interests.  Oil sales represented 38% of  total  oil
    and  gas  sales during the quarter ended March 31, 2003  and  42%
    during quarter ended March 31, 2002.

    The  average  price for an mcf of gas received by the Partnership
    increased  during  the same period by 190%,  or  $3.79  per  mcf,
    resulting in an increase of approximately $45,500 in income  from
    net profits interests.

    The  total increase in income from net profits interests  due  to
    the  change  in  prices received from oil and gas  production  is
    approximately $63,200.  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 100 barrels or 7%  during
    the quarter ended March 31, 2003 as compared to the quarter ended
    March  31, 2002, resulting in a decrease of approximately  $1,900
    in income from net profits interests.

    Gas  production decreased approximately 6,500 mcf or  35%  during
    the same period, resulting in a decrease of approximately $13,000
    in income from net profits interests.

    The  total decrease in income from net profits interests  due  to
    the  change in production is approximately $14,900.  The decrease
    in  gas production is primarily due to one lease, which the wells
    were  shut in during 2002, and production is slowly being brought
    back on.

3.  Lease  operating costs and production taxes were 36%  higher,  or
    approximately  $12,100 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
    mainly  to  repairs  and maintenance being performed  on  several
    leases, and the increase in production taxes in relation  to  the
    increase in gross revenues received in 2003.

Costs and Expenses

Total  costs and expenses increased to $19,873 from $19,233  for  the
quarters ended March 31, 2003 and 2002, respectively, an increase  of
3%.   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 and  general
and administrative expense.

1.  General   and   administrative  costs  consists  of   independent
    accounting and engineering fees, computer services, postage,  and
    Managing   General   Partner  personnel   costs.    General   and
    administrative  costs increased 1% or approximately  $100  during
    the quarter ended March 31, 2003 as compared to the quarter ended
    March 31, 2002.

2.  Depletion expense decreased to $7,000 for the quarter ended March
    31,  2003  from  $9,000  for  the  same  period  in  2002.   This
    represents a decrease of 22%.  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 $3,000 and increase
    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 $2.10 applied to 3,340 BOE as  compared  to
    $1.99 applied to 4,523 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 $80,867, a long  term  liability  of
approximately  $127,408 and a loss of approximately $46,541  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 $129,956, and the increase
in  the  balance from January 1, 2003 of $2,548 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  operating  activities  were  approximately
$42,000  in  the  quarter  ended  March  31,  2003  as  compared   to
approximately  $6,400  in  the quarter ended  March  31,  2002.   The
primary  source  of the 2003 cash flow from operating activities  was
profitable operations.

Cash  flows used in financing activities were $39,900 in the  quarter
ended  March  31,  2003 as compared to $15,000 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
$40,000 of which $36,000 was distributed to the limited partners  and
$4,000 to the general partners.  The per unit distribution to limited
partners  during  the quarter ended March 31, 2003 was  $6.64.  Total
distributions during the quarter ended March 31, 2002 were $15,000 of
which  $13,500 was distributed to the limited partners and $1,500  to
the  general partners.  The per unit distribution to limited partners
during the quarter ended March 31, 2002 was $2.49.

The  primary source for the 2003 distributions of $40,000 was oil and
gas operations of approximately $42,000, resulting in excess cash for
contingencies  or subsequent distributions to partners.  The  primary
source  for  the  2002  distributions of  $15,000  was  oil  and  gas
operations  of approximately $6,400, with the balance from  available
cash on hand at the beginning of the period.

Since   inception  of  the  Partnership,  cumulative   monthly   cash
distributions  of $2,335,467 have been made to the partners.   As  of
March  31, 2003, $2,127,610 or $392.69 per limited partner  unit  has
been  distributed to the limited partners, representing a 79%  return
of the capital contributed.

As  of  March 31, 2003, the Partnership had approximately $81,500  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 ROYALTIES INSTITUTIONAL
                              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 Royalties Institutional 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 Royalties Institutional
  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 Royalties Institutional 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 Royalties
  Institutional 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 Royalties
Institutional  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 Royalties Institutional 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  Royalties
Institutional  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 Royalties Institutional Income Fund XI-A, L.P.


<PAGE>