Page 20 of 20
                                 FORM 10-Q


                    SECURITIES AND EXCHANGE COMMISSION
                         WASHINGTON, D. C.  20549

(Mark One)

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

For the quarterly period ended September 30, 2002

                                    OR

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

For the transition period from _________________ to _______________

Commission file number 33-47667-01

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

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

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

                      ________(915) 686-9927________
                      (Registrant's telephone number,
                           including area code)

Indicate  by  check  mark  whether registrant (1)  has  filed  all  reports
required to be filed by Section 13 or 15(d) of the Securities Exchange  Act
of 1934 during the preceding 12 months (or for such shorter period that the
registrant was required to file such reports), and (2) has been subject  to
such filing requirements for the past 90 days:

                            Yes __X__ No _____

         The total number of pages contained in this report is 20.

<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 note thereto  for
the  year ended December 31, 2001, which are found in the Registrant's Form
10-K  Report  for  2001 filed with the Securities and Exchange  Commission.
The December 31, 2001 balance sheet included herein has been taken from the
Registrant's  2001 Form 10-K Report.  Operating results for the  three  and
nine  month periods ended September 30, 2002 are not necessarily indicative
of the results that may be expected for the full year.

<PAGE>

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

                              Balance Sheets

                                          September        December
                                             30,             31,
                                             2002            2001
                                         -----------      ---------
                                         (unaudited)
Assets
------
Current assets:
 Cash and cash equivalents             $ 17,254            13,139
   Receivable  from  Managing  General   15,348                 -
Partner
                                         ---------       ---------
   Total current assets                  32,602            13,139
                                         ---------       ---------
Oil  and  gas properties -  using  the
full-
 cost method of accounting               1,053,483       1,054,189
  Less accumulated depreciation,
   depletion and amortization            832,555          817,555
                                         ---------       ---------
   Net oil and gas properties            220,928          236,634
                                         ---------       ---------
                                       $ 253,530          249,773
                                         =========       =========

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

Current liability -
 Distribution payable                  $ -                     46
 Payable to Managing General Partner     -                  2,719
                                         ---------       ---------
   Total current liabilities             -                  2,765
                                         ---------       ---------

Partners' equity:
 General partners                        (4,931)          (6,960)
 Limited partners                        258,461          253,968
                                         ---------       ---------
   Total partners' equity                253,530          247,008
                                         ---------       ---------
                                       $ 253,530          249,773
                                         =========       =========


<PAGE>

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

                         Statements of Operations
                                (unaudited)


                                 Three Months Ended    Nine Months
                                                          Ended
                                   September 30,      September 30,
                                   2002      2001      2002     2001
                                   ----      ----      ----     ----
Revenues
--------
Oil and Gas                   $  42,326    42,641    122,622   198,36
                                                               6
Interest                         40        214       91          897
Miscellaneous settlement         -         -         1,236         -
                                 -------   -------   -------   ------
                                                               -
                                 42,366    42,855    123,949   199,26
                                                               3
                                 -------   -------   -------   ------
                                                               -

Expenses
--------
Production                       25,974     26,193   64,827    99,587
General and administrative       5,110       4,007   13,600    12,764
Depreciation, depletion and
 amortization                    4,000      19,000   15,000    42,000
                                 -------   -------   -------   ------
                                                               -
                                 35,084     49,200   93,427    154,35
                                                               1
                                 -------   -------   -------   ------
                                                               -
Net income (loss)             $  7,282     (6,345)             44,912
                                                     30,522
                                 =======   =======   =======   ======
                                                               =

Net income (loss) allocated
to:

Managing General Partner      $  1,015       1,139     3,986   7,822
                                 =======   =======   =======   ======
                                                               =
General Partner               $  113           127       443     869
                                 =======   =======   =======   ======
                                                               =
Limited Partners              $  6,154     (7,611)    26,093   36,221
                                 =======   =======   =======   ======
                                                               =
 Per limited partner unit     $     2.18    (2.70)      9.25   12.84
                                 =======   =======   =======   ======
                                                               =


<PAGE>

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

                         Statements of Cash Flows
                                (unaudited)


                                                     Nine Months Ended
                                                       September 30,
                                                       2002     2001
                                                       ----     ----
Cash flows from operating activities

 Cash received from oil and gas sales             $  117,320  232,834
 Cash paid to suppliers                              (91,192  (108,472
                                                     )        )
 Interest received                                   91       897
  Miscellaneous settlement                           1,236    -
                                                     -------  -------

   Net cash provided by operating activities         27,455   125,259
                                                     -------  -------

Cash flows from investing activities

  Additions to oil and gas properties                -        (1,343)
  Sale of oil and gas properties                     706      -
                                                     -------  -------

    Net cash provided by (used in) investing         706      (1,343)
activities                                           -------  -------

Cash flows used in financing activities

 Distributions to partners                           (24,046  (133,500
                                                     )        )
                                                     -------  -------

   Net increase (decrease) in cash and cash          4,115    (9,584)
equivalents

 Beginning of period                                 13,139   21,569
                                                     -------  -------
 End of period                                    $  17,254   11,985
                                                     =======  =======
Reconciliation of net income to net cash
provided by operating activities

Net income                                        $  30,522   44,912

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

  Depreciation, depletion and amortization           15,000   42,000
  (Increase) decrease receivables                    (5,302)  34,468
  (Decrease) increase in payables                    (12,765  3,879
                                                     )
                                                     -------  -------
Net cash provided by operating activities         $  27,455   125,259
                                                     =======  =======



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

                      Notes to Financial Statements

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

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

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

2.   Summary of Significant Accounting Policies
     The  interim financial information as of September 30, 2002,  and  for
     the  three  and  nine months ended September 30, 2002,  is  unaudited.
     Certain  information  and footnote disclosures  normally  included  in
     financial  statements prepared in accordance with  generally  accepted
     accounting principles have been condensed or omitted in this Form 10-Q
     pursuant  to the rules and regulations of the Securities and  Exchange
     Commission.   However,  in  the opinion of management,  these  interim
     financial  statements include all the necessary adjustments to  fairly
     present  the  results of the interim periods and all such  adjustments
     are  of a normal recurring nature.  The interim consolidated financial
     statements  should  be read in conjunction with the audited  financial
     statements for the year ended December 31, 2001.

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

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

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

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

Based on current conditions, management anticipates performing no workovers
during  2002  to  enhance  production.  The partnership  will  most  likely
experience the historical production decline of approximately 8% 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.

The  Partnership's policy for depreciation, depletion and  amortization  of
oil  and  gas  properties is computed under the units  of  revenue  method.
Under the units of revenue method, depreciation, depletion and amortization
is  computed  on  the  basis of current gross revenues from  production  in
relation  to future gross revenues, based on current prices, from estimated
production of proved oil and gas reserves.

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.  For the nine months ended September 30,  2002,  the  net
capitalized costs did not exceed the estimated present value.

Under  the  units of revenue method, the Partnership computes the provision
by  multiplying the total unamortized cost of oil and gas properties by  an
overall  rate  determined by dividing (a) oil and gas revenues  during  the
period  by (b) the total future gross oil and gas revenues as estimated  by
the  Partnership's  independent petroleum consultants.   It  is  reasonably
possible  that  those estimates of anticipated future gross  revenues,  the
remaining estimated economic life of the product, or both could be  changed
significantly in the near term due to the potential fluctuation of oil  and
gas prices or production.  The depletion estimate would also be affected by
this change.
<PAGE>
Critical Accounting Policies

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

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

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

While  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.

The  Partnership's policy for depreciation, depletion and  amortization  of
oil  and  gas  properties is computed under the units  of  revenue  method.
Under the units of revenue method, depreciation, depletion and amortization
is  computed  on  the  basis of current gross revenues from  production  in
relation  to future gross revenues, based on current prices, from estimated
production of proved oil and gas reserves.

<PAGE>
Results of Operations

A.  General Comparison of the Quarters Ended September 30, 2002 and 2001

The  following  table  provides certain information  regarding  performance
factors for the quarters ended September 30, 2002 and 2001:

                                                 Three Months
                                                    Ended        Percentage
                                                September 30,     Increase
                                                2002      2001   (Decrease)
                                                ----      ----   ---------
Average price per barrel of oil            $   25.68     23.05     11%
Average price per mcf of gas               $    2.38      2.50    (5%)
Oil production in barrels                      1,000     1,000       -
Gas production in mcf                          7,000     9,400   (26%)
Gross oil and gas revenue                  $  42,326    42,641    (1%)
Net oil and gas revenue                    $  16,352    16,448    (1%)
Partnership distributions                  $   9,000    35,000   (74%)
Limited partner distributions              $   8,100    31,500   (74%)
Per unit distribution to limited partners  $    2.87     11.17   (74%)
Number of limited partner units                2,821     2,821


Revenues

The  Partnership's oil and gas revenues decreased to $42,326  from  $42,641
for  the  quarters  ended  September 30, 2002  and  2001,  respectively,  a
decrease  of  1%.   The principal factors affecting the comparison  of  the
quarters ended September 30, 2002 and 2001 are as follows:

1.  The  average  price  for a barrel of oil received  by  the  Partnership
    increased  during the quarter ended September 30, 2002 as  compared  to
    the  quarter  ended  September 30, 2001 by 11%, or  $2.63  per  barrel,
    resulting  in  an  increase of approximately $2,600 in  revenues.   Oil
    sales  represented  61% of total oil and gas sales during  the  quarter
    ended  September 30, 2002 as compared to 50% during the  quarter  ended
    September 30, 2001.

    The  average  price  for  an  mcf of gas received  by  the  Partnership
    decreased during the same period by 5%, or $.12 per mcf, resulting in a
    decrease of approximately $800 in revenues.

    The net total increase in revenues due to the change in prices received
    from  oil and gas production is approximately $1,800.  The market price
    for  oil  and gas has been extremely volatile over the past decade  and
    management  expects a certain amount of volatility to continue  in  the
    foreseeable future.

<PAGE>

2.       Oil production
   remained the same during the quarter ended September 30, 2002 as
compared to the quarter ended September 30, 2001.

    Gas production decreased approximately 2,400 mcf or 26% during the same
    period, resulting in a decrease of approximately $6,000 in revenues.

    The  total  decrease  in revenues due to the change  in  production  is
    approximately $6,000.  The decrease in gas production is mainly due  to
    downtime  with  a  parted  rod on one well  during  the  quarter  ended
    September 30, 2002.

Costs and Expenses

Total costs and expenses decreased to $35,084 from $49,200 for the quarters
ended  September 30, 2002 and 2001, respectively, a decrease of  29%.   The
decrease  is  the  result of lower depletion expense  and  lease  operating
costs,  partially  offset  by  an increase in  general  and  administrative
expense.

1.    Lease  operating  costs  and  production  taxes  were  1%  lower,  or
   approximately $200 less during the quarter ended September 30,  2002  as
   compared to the quarter ended September 30, 2001.

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
    28% or approximately $1,100 during the quarter ended September 30, 2002
    as  compared to the quarter ended September 30, 2001.  The increase  in
    general and administrative costs is predominantly due to an increase in
    independent accounting fees.

3.  Depletion  expense decreased to $4,000 for the quarter ended  September
    30,  2002 from $19,000 for the same period in 2001.  This represents  a
    decrease  of 79%.  Depletion is calculated using the units  of  revenue
    method  of  amortization based on a percentage of current period  gross
    revenues  to  total future gross oil and gas revenues, as estimated  by
    the  Partnership's independent petroleum consultants.  The contributing
    factor  to  the  decrease in depletion expense between the  comparative
    periods  was the increase in the price of oil and gas used to determine
    the Partnership's reserves for October 1, 2002 as compared to 2001.

<PAGE>

B.   General Comparison of the Nine Month Periods Ended September 30,  2002
and 2001

The  following  table  provides certain information  regarding  performance
factors for the nine month periods ended September 30, 2002 and 2001:

                                                 Nine Months
                                                    Ended        Percentage
                                                September 30,     Increase
                                                2002      2001   (Decrease)
                                                ----      ----   ---------
Average price per barrel of oil            $   23.18     23.96     (3%)
Average price per mcf of gas               $    2.36      4.31    (45%)
Oil production in barrels                      2,900     3,100     (6%)
Gas production in mcf                         23,500    28,800    (18%)
Gross oil and gas revenue                  $ 122,622   198,366    (38%)
Net oil and gas revenue                    $  57,795    98,779    (41%)
Partnership distributions                  $  24,000   133,500    (82%)
Limited partner distributions              $  21,600   120,150    (82%)
Per unit distribution to limited partners  $    7.66     42.59    (82%)
Number of limited partner units                2,821     2,821

Revenues

The  Partnership's oil and gas revenues decreased to $122,622 from $198,366
for  the  nine  months ended September 30, 2002 and 2001,  respectively,  a
decrease  of  38%.  The principal factors affecting the comparison  of  the
nine months ended September 30, 2002 and 2001 are as follows:

1.  The  average  price  for a barrel of oil received  by  the  Partnership
    decreased  during the nine months ended September 30, 2002 as  compared
    to  the nine months ended September 30, 2001 by 3%, or $.78 per barrel,
    resulting in a decrease of approximately $2,300 in revenues. Oil  sales
    represented  55%  of total oil and gas sales during the  quarter  ended
    September  30,  2002  as  compared to  37%  during  the  quarter  ended
    September 30, 2001.

    The  average  price  for  an  mcf of gas received  by  the  Partnership
    decreased during the same period by 45%, or $1.95 per mcf, resulting in
    a decrease of approximately $45,800 in revenues.

    The  total  decrease in revenues due to the change in  prices  received
    from oil and gas production is approximately $48,100.  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 200 barrels or  6%  during  the
    nine  months  ended September 30, 2002 as compared to the  nine  months
    ended  September  30,  2001, resulting in a decrease  of  approximately
    $4,800 in revenues.

    Gas production decreased approximately 5,300 mcf or 18% during the same
    period, resulting in a decrease of approximately $22,800 in revenues.

    The  total  decrease  in revenues due to the change  in  production  is
    approximately $27,600.  The decrease in gas production is mainly due to
    downtime  with  a parted rod on one well during the nine  months  ended
    September 30, 2002.

Costs and Expenses

Total  costs and expenses decreased to $93,427 from $154,351 for  the  nine
months ended September 30, 2002 and 2001, respectively, a decrease of  39%.
The  decrease is the result of lower depletion expense and lease  operating
costs,  partially  offset  by  an increase in  general  and  administrative
expense.

1.  Lease  operating  costs  and  production  taxes  were  35%  lower,   or
    approximately  $34,800 less during the nine months ended September  30,
    2002  as  compared to the nine months ended September  30,  2001.   The
    decrease  in  lease operating expense is due to repairs and maintenance
    performed during the nine months ended September 30, 2001.

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 7%
    or  approximately $800 during the nine months ended September 30,  2002
    as compared to the nine months ended September 30, 2001.

3.  Depletion  expense  decreased to $15,000  for  the  nine  months  ended
    September  30,  2002 from $42,000 for the same period  in  2001.   This
    represents a decrease of 64%.  Depletion is calculated using the  units
    of  revenue  method  of amortization based on a percentage  of  current
    period  gross  revenues to total future gross oil and gas revenues,  as
    estimated  by  the  Partnership's  independent  petroleum  consultants.
    Contributing factors to the decrease in depletion expense  between  the
    comparative periods were the increase in the price of oil and gas  used
    to determine the Partnership's reserves for October 1, 2002 as compared
    to  2001,  and  the decrease in oil and gas revenues  received  by  the
    Partnership during 2002 as compared to 2001.

<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 $27,500  in
the  nine  months  ended  September 30, 2002 as compared  to  approximately
$125,300  in the nine months ended September 30, 2001.  The primary  source
of the 2002 cash flow from operating activities was profitable operations.

Cash  flows  provided by (used in) investing activities were  approximately
$700  in  the  nine  months  ended  September  30,  2002  as  compared   to
approximately  $(1,300) in the nine months ended September 30,  2001.   The
principle  use  of  the 2002 cash flow from investing  activities  was  the
change in oil and gas properties.

Cash  flows used in financing activities were approximately $24,000 in  the
nine  months ended September 30, 2002 as compared to approximately $133,500
in  the  nine  months ended September 30, 2001.  The only use in  financing
activities was the distributions to partners.

Total  distributions during the nine months ended September 30,  2002  were
$24,000 of which $21,600 was distributed to the limited partners and $2,400
to  the  general  partners.  The per unit distribution to limited  partners
during  the  nine  months  ended  September  30,  2002  was  $7.66.   Total
distributions during the nine months ended September 30, 2001 were $133,500
of  which  $120,150 was distributed to the limited partners and $13,350  to
the general partners.  The per unit distribution to limited partners during
the nine months ended September 30, 2001 was $42.59.

The  sources  for  the  2002  distributions of $24,000  were  oil  and  gas
operations of approximately $27,500, partially offset by the change in  oil
and  gas  properties of approximately $700, resulting in  excess  cash  for
contingencies  or  subsequent  distributions.   The  source  for  the  2001
distributions  of  $133,500  was oil and gas  operations  of  approximately
$125,300,  partially  offset  by a change in  oil  and  gas  properties  of
approximately $(1,300), with the balance from available cash on hand at the
beginning of the period.

Since  inception of the Partnership, cumulative monthly cash  distributions
of  $1,258,870 have been made to the partners.  As of September  30,  2002,
$1,146,153 or $406.29 per limited partner unit has been distributed to  the
limited partners, representing a 81% return of the capital contributed.

As  of  September  30, 2002, the Partnership had approximately  $32,600  in
working  capital.   The  Managing  General  Partner  knows  of  no  unusual
contractual commitments and believes the revenues generated from operations
are adequate to meet the needs of the Partnership.

<PAGE>
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.  The Managing General Partner is currently assessing the impact
on the partnerships financial statements.

On  October 3, 2001, the FASB issued Statement No. 144 "Accounting for  the
Impairment   or   Disposal  of  Long-Lived  Assets."   This   pronouncement
supercedes FAS 121 "Accounting for the Impairment of Long-Lived Assets  and
for  Long-Lived  Assets to Be Disposed" and eliminates the  requirement  of
Statement  121 to allocate goodwill to long-lived assets to be  tested  for
impairment.   The provisions of this statement are effective for  financial
statements issued for fiscal years beginning after December 15,  2001,  and
interim  periods  within those fiscal years.  The Managing General  Partner
believes  that  the impact from SFAS No. 144 on the Partnerships  financial
position  and  results  of operation should not be significantly  different
from that of SFAS No. 121.

In April 2002, FASB issued SFAS No. 145, "Rescission of SFAS No. 4, 44, and
64,  Amendment of SFAS No. 13, and Technical Corrections."  This  Statement
rescinds  SFAS  No.  4, "Reporting Gains and Losses from Extinguishment  of
Debt", and an amendment of that Statement, SFAS No. 64, "Extinguishments of
Debt  Made  to  Satisfy Sinking-Fund Requirements".   This  Statement  also
rescinds  or  amends  other existing authoritative pronouncements  to  make
various   technical  corrections,  clarify  meanings,  or  describe   their
applicability  under changed conditions.  This standard  is  effective  for
fiscal  years  beginning after May 15, 2002.  The Managing General  Partner
believes  that  the adoption of this statement will not have a  significant
impact on the Partnerships financial statements.

In  July  2002,  FASB issued SFAS No. 146 "Accounting for Costs  Associated
with  Exit  or  Disposal  Activities" which  establishes  requirements  for
financial  accounting  and  reporting for costs  associated  with  exit  or
disposal  activities.   This standard is effective  for  exit  or  disposal
activities initiated after December 31, 2002.  The Managing General Partner
is  currently  assessing the impact of this statement on the  Partnerships'
future financial statements.

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



<PAGE>

                                SIGNATURES


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

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

                                   By:  Southwest Royalties, Inc.
                                        Managing General Partner


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

Date:     November 14, 2002

<PAGE>
                         CERTIFICATIONS


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

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

          2.   Based on my knowledge, this 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

<PAGE>

          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 14, 2002




/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 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

<PAGE>


          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 14, 2002




/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>