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                                 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, 2004

                                    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 0-15411

                 Southwest Royalties, Inc. Income Fund VI
                  (Exact name of registrant as specified
                   in its limited partnership agreement)

Tennessee                                         75-2127812
(State or other jurisdiction of                                  (I.R.S.
Employer
incorporation or organization)
          Identification No.)

                         6 Desta Drive, Suite 6500
                  _________Midland, Texas 79705_________
                 (Address of principal executive offices)

                      ________(432) 682-6324________
                      (Registrant's telephone number,
                           including area code)

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

                              Yes X No ___

Indicate  by check mark whether the registrant is an accelerated filer  (as
defined in Exchange Act Rule 12b-2).     Yes     No  X

The  registrant's  outstanding  securities  consist  of  Units  of  limited
partnership  interests for which there exists no established public  market
from which to base a calculation of aggregate market value.


         The total number of pages contained in this report is 23



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.

     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.


                      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, 2003, which are found in the Registrant's Form
10-K  Report  for  2003 filed with the Securities and Exchange  Commission.
The December 31, 2003 balance sheet included herein has been taken from the
Registrant's  2003 Form 10-K Report.  Operating results for the  three  and
nine-month  periods ended September 30, 2004 are not necessarily indicative
of the results that may be expected for the full year.


                 Southwest Royalties, Inc. Income Fund VI
                              Balance Sheets

                                         Septembe  December
                                           r 30,      31,
                                           2004      2003
                                          ------    ------
                                         (unaudit
                                            ed)
Assets
---------
Current assets:
 Cash and cash equivalents            $  204,510   234,954
  Receivable  from  Managing  General    205,945   189,477
Partner
 Oklahoma withholding prepayment         124       124
                                         --------  --------
                                         ----      -----
   Total current assets                  410,579   424,555
                                         --------  --------
                                         ----      -----
Oil  and  gas properties - using  the
full-
 cost method of accounting               8,547,31  8,547,31
                                         7         7
  Less accumulated depreciation,
   depletion and amortization            6,224,24  6,143,46
                                         1         0
                                         --------  --------
                                         ----      -----
   Net oil and gas properties            2,323,07  2,403,85
                                         6         7
                                         --------  --------
                                         ----      -----
                                      $  2,733,65  2,828,41
                                         5         2
                                         =======   =======
Liabilities and Partners' Equity
-------------------------------------
---

Asset retirement obligation           $  544,203   513,400
                                         --------  --------
                                         ----      -----

Partners' equity:
 General partner                         (635,385  (622,829
                                         )         )
 Limited partners                        2,824,83  2,937,84
                                         7         1
                                         --------  --------
                                         ----      -----
   Total partners' equity                2,189,45  2,315,01
                                         2         2
                                         --------  --------
                                         ----      -----
                                      $  2,733,65  2,828,41
                                         5         2
                                         =======   =======


                 Southwest Royalties, Inc. Income Fund VI
                         Statements of Operations
                                (unaudited)

                                 Three Months Ended    Nine Months
                                                          Ended
                                    September 30,     September 30,
                                   2004       2003     2004    2003
                                   -----     -----    -----    -----
Revenues
------------
Income from net profits        $ 288,753    292,321  984,532  921,008
interests
Interest                         432        379      1,357    770
Other                            -          -        250      -
                                 ---------  -------- -------  -------
                                 -          --       ---      ---
                                 289,185    292,700  986,139  921,778
                                 ---------  -------- -------  -------
                                 -          --       ---      ---
Expenses
------------
General and administrative       41,229     40,611   125,115  127,511
Accretion of asset retirement    10,268     9,508    30,803   29,501
obligation
Depreciation, depletion and      24,781     37,000   80,781   103,000
amortization
                                 ---------  -------- -------  -------
                                 -          --       ---      ---
                                 76,278     87,119   236,699  260,012
                                 ---------  -------- -------  -------
                                 -          --       ---      ---
Net income before cumulative     212,907    205,581  749,440  661,766
effect

Cumulative effect of change in
accounting
 principle - SFAS No. 143 -      -          -        -        116,637
See Note 3
                                 ---------  -------- -------  -------
                                 -          --       ---      ---
Net income                     $ 212,907    205,581  749,440  778,403
                                 ======     ======   ======   ======
Net income allocated to:

Managing General Partner       $ 21,291     20,558   74,944   77,840
                                 ======     ======   ======   ======
Limited Partners               $ 191,616    185,023  674,496  700,563
                                 ======     ======   ======   ======
 Per limited partner unit      $    9.58              33.72
before cumulative effect                    9.25              29.78
 Cumulative effect per limited         -         -        -
partner unit                                                  5.25
                                 ---------  -------- -------  -------
                                 -          --       ---      ---
 Per limited partner unit      $    9.58              33.72
                                            9.25              35.03
                                 ======     ======   ======   ======

                 Southwest Royalties, Inc. Income Fund VI
                         Statements of Cash Flows
                                (unaudited)

                                                      Nine Months
                                                         Ended
                                                     September 30,
                                                     2004     2003
                                                    -----    -----
          Cash flows from operating activities
          Cash received from income from net    $  916,079  748,132
          profits interests
          Cash paid to suppliers                   (73,130  (62,726
                                                   )        )
          Interest received                        1,357    770
          Other                                    250      -
                                                   -------  -------
                                                   ---      ---
           Net cash provided by operating          844,556  686,176
          activities
                                                   -------  -------
                                                   ---      ---
          Cash flows provided by investing
          activities:
          Sale of oil and gas properties           -        306
                                                   -------  -------
                                                   ---      ---
          Cash flows used in financing
          activities
          Distributions to partners                (875,00  (503,44
                                                   0)       7)
                                                   -------  -------
                                                   ---      ---
           Net (decrease) increase in cash and     (30,444  183,035
          cash equivalents                         )

          Beginning of period                      234,954  18,015
                                                   -------  -------
                                                   ---      ---
          End of period                         $  204,510  201,050
                                                   ======   ======
          Reconciliation of net income to net
          cash
          provided by operating activities
          Net income                            $  749,440  778,403

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

          Depreciation, depletion and              80,781   103,000
          amortization
          Accretion of asset retirement            30,803   29,501
          obligation
          Cumulative effect of change in
          accounting
           principle - SFAS No. 143                -        (116,63
                                                            7)
          Increase in receivables                  (68,453  (172,87
                                                   )        1)
          Increase in payables                     51,985   64,780
                                                   -------  -------
                                                   ---      ---
          Net cash provided by operating        $  844,556  686,176
          activities
                                                   ======   ======
          Noncash investing and financing
          activities:
          Increase in oil and properties -
          Adoption
           of SFAS No. 143                      $  -        616,464
                                                   ======   ======
          Increase in oil and gas properties -
          SFAS No. 143
           additional wells from farm-out       $  -        422
          arrangements
                                                   ======   ======
          Decrease in oil and gas properties -
          SFAS No. 143
           sale of property                     $  -        (25,857
                                                            )
                                                   ======   ======
                 Southwest Royalties, Inc. Income Fund VI
                    (a Tennessee limited partnership)

                      Notes to Financial Statements

1.  Organization
          Southwest Royalties, Inc. Income Fund VI was organized under  the
    laws of the state of Tennessee on December 4, 1986, 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  sells  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.  a
    wholly owned subsidiary of Clayton Williams Energy, Inc., serves as the
    Managing  General Partner.  Revenues, costs and expenses are  allocated
    as follows:
                              Limited   General
                              Partners  Partners
                              --------  --------
Interest  income on  capital  100%      -
contributions
Oil and gas sales             90%       10%
All other revenues            90%       10%
Organization  and   offering  100%      -
costs (1)
Amortization of organization  100%      -
costs
Property acquisition costs    100%      -
Gain/loss    on     property  90%       10%
disposition
Operating and administrative  90%       10%
costs (2)
Depreciation, depletion  and
amortization
 of oil and gas properties    90%       10%
All other costs               90%       10%

         (1)All  organization  costs in excess of  3%  of  initial  capital
         contributions  will  be paid by the Managing General  Partner  and
         will  be treated as a capital contribution.  The Partnership  paid
         the  Managing  General Partner an amount equal to  3%  of  initial
         capital contributions for such organization costs.

         (2)Administrative costs in any year, which exceed  2%  of  capital
         contributions  shall be paid by the Managing General  Partner  and
         will be treated as a capital contribution.

2.   Summary of Significant Accounting Policies
     The  interim financial information as of September 30, 2004,  and  for
     the  three  and  nine months ended September 30, 2004,  is  unaudited.
     Certain  information  and footnote disclosures  normally  included  in
     financial  statements prepared in accordance with  generally  accepted
     accounting principles have been condensed or omitted in this Form 10-Q
     pursuant  to the rules and regulations of the Securities and  Exchange
     Commission.  However,  in  the opinion of  management,  these  interim
     financial  statements include all the necessary adjustments to  fairly
     present  the  results of the interim periods and all such  adjustments
     are  of a normal recurring nature.  The interim consolidated financial
     statements should be read in conjunction with the Partnership's Annual
     Report on Form 10-K for the year ended December 31, 2003.

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 $616,464, a long  term  liability  of
     approximately  $499,827 and a gain of approximately $116,637  for  the
     cumulative  effect  on  depreciation  of  the  additional  costs   and
     accretion  expense  on  the liability related to expected  abandonment
     costs  of  its oil and natural gas producing properties.  At September
     30,  2004, the asset retirement obligation was $544,203.  The increase
     in  the  asset retirement obligation from January 1, 2004  is  due  to
     accretion expense of $30,803.


                 Southwest Royalties, Inc. Income Fund VI
                    (a Tennessee limited partnership)

                      Notes to Financial Statements

4.   Change in Control of Managing General Partner
     On  May  21,  2004,  Clayton Williams Energy, Inc.  acquired  all  the
     outstanding common stock of Southwest Royalties Inc. through a merger.
     Clayton  Williams  Energy,  Inc. paid  $57.1  million  to  holders  of
     Southwest  Royalties,  Inc.  common stock and  common  stock  warrants
     ($45.01   per   share)   and  assumed  and  refinanced   approximately
     $113.9 million of assumed bank debt at closing.

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

General
Southwest  Royalties,  Inc. Income Fund VI was  organized  as  a  Tennessee
limited  partnership  on  December 4, 1986. The offering  of  such  limited
partnership  interests began August 25, 1986, minimum capital  requirements
were met October 3, 1986 and concluded January 29, 1987, with total limited
partner contributions of $10,000,000.

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.

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.

Should the net capitalized costs exceed the estimated present value of  oil
and gas reserves, discounted at 10%, such excess costs would be charged  to
current  expense.  As of September 30, 2004, the net capitalized costs  did
not exceed the estimated present value of oil and gas reserves.


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
September 30, 2004, there were no timing differences, which resulted  in  a
deficit net profit interest.

Critical Accounting Policies

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.  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.


Results of Operations

A.  General Comparison of the Quarters Ended September 30, 2004 and 2003

The  following  table  provides certain information  regarding  performance
factors for the quarters ended September 30, 2004 and 2003:

                                         Three Months
                                            Ended         Percenta
                                                             ge
                                        September 30,     Increase
                                        2004      2003    (Decreas
                                                             e)
                                       -----     -----    --------
                                                             --
Average price per barrel of oil    $  41.84               41%
                                                29.62
Average price per mcf of gas       $   5.08               12%
                                                4.52
Oil production in barrels             4,236     5,300     (20%)
Gas production in mcf                 58,044    78,900    (26%)
Income from net profits interests  $  288,753   292,321   (1%)
Partnership distributions          $  300,000   250,091   20%
Limited partner distributions      $  270,000   225,082   20%
Per unit distribution to limited
 partners                          $  13.50               20%
                                                11.25
Number of limited partner units       20,000    20,000

Revenues

The  Partnership's income from net profits interests decreased to  $288,753
from  $292,321  for  the  quarters  ended  September  30,  2004  and  2003,
respectively,  a  decrease  of  1%.  The principal  factors  affecting  the
comparison  of  the  quarters ended September 30,  2004  and  2003  are  as
follows:

1.  The  average  price  for a barrel of oil received  by  the  Partnership
    increased  during the quarter ended September 30, 2004 as  compared  to
    the  quarter  ended  September 30, 2003 by 41%, or $12.22  per  barrel,
    resulting  in an increase of approximately $51,800 in income  from  net
    profits  interests.  Oil sales represented 38% of  total  oil  and  gas
    sales  during the quarter ended September 30, 2004 as compared  to  31%
    during the quarter ended September 30, 2003.

    The  average  price  for  an  mcf of gas received  by  the  Partnership
    increased during the same period by 12%, or $.56 per mcf, resulting  in
    an  increase  of  approximately $32,500  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
    $84,300.   The market price for oil and gas has been extremely volatile
    over  the  past  decade, and management expects  a  certain  amount  of
    volatility to continue in the foreseeable future.


2.  Oil  production decreased approximately 1,064 barrels or 20% during the
    quarter  ended  September 30, 2004 as compared  to  the  quarter  ended
    September 30, 2003, resulting in a decrease of approximately $31,500 in
    income from net profits interests.

    Gas  production  decreased approximately 20,856 mcf or 26%  during  the
    same period, resulting in a decrease of approximately $94,300 in income
    from net profits interests.

    The  total  decrease in income from net profits interests  due  to  the
    change  in  production is approximately $125,800. The decrease  in  oil
    production is the result of the production decline on three wells.  The
    lower gas volumes are from a sharp decline on four wells.

3.  Lease  operating  costs  and  production  taxes  were  17%  lower,   or
    approximately $38,200 less during the quarter ended September 30,  2004
    as  compared to the quarter ended September 30, 2003.  The lower  lease
    operating costs resulted from the sale of a producing property in  2003
    and work on a well repair work performed on a well in 2003.

Costs and Expenses

Total costs and expenses decreased to $76,278 from $87,119 for the quarters
ended  September  30, 2004 and 2003 respectively, a decrease  of  12%.  The
decrease is the result of lower depletion expense, partially offset  by  an
increase in accretion expense 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 $600 during the quarter ended September 30,  2004  as
    compared to the quarter ended September 30, 2003.

2.  Depletion  expense decreased to $24,781 for the quarter ended September
    30,  2004 from $37,000 for the same period in 2003.  This represents  a
    decrease  of 33%.  The contributing factor to the decrease in depletion
    expense is in relation to the BOE depletion rate for the quarter  ended
    September  30, 2004, which was $1.78 applied to 13,910 BOE as  compared
    to  $2.02 applied to 18,450 BOE for the same period in 2003.  The lower
    depreciation  rate  in 2004 is due to the upward  revision  in  reserve
    estimates resulting from higher oil and gas prices.

3.  Accretion  expense increased to $10,268 for the quarter ended September
    30,  2004 from $9,508 for the same period in 2003.  This represents  an
    increase of 8%.


B.   General Comparison of the Nine-Month Periods Ended September 30,  2004
and 2003

The  following  table  provides certain information  regarding  performance
factors for the nine-month periods ended September 30, 2004 and 2003:

                                    Nine Months
                                       Ended         Percenta
                                                        ge
                                   September 30,     Increase
                                   2004      2003    (Decreas
                                                        e)
                                  -----     -----    --------
                                                        --
Average price per barrel  of  $    36.92             23%
oil                                        29.93
Average price per mcf of gas  $     5.52             9%
                                           5.06
Oil production in barrels        14,986    16,300    (8%)
Gas production in mcf            184,169   208,500   (12%)
Income   from  net   profits  $  984,532   921,008   7%
interests
Partnership distributions     $  875,000   500,091   75%
Limited              partner  $  787,500   450,082   75%
distributions
Per  unit  distribution   to
limited
 partners                     $    39.38             75%
                                           22.50
Number  of  limited  partner     20,000    20,000
units

Revenues

The  Partnership's income from net profits interests increased to  $984,532
from  $921,008  for  the nine months ended September  30,  2004  and  2003,
respectively,  an  increase  of 7%.  The principal  factors  affecting  the
comparison  of  the nine months ended September 30, 2004 and  2003  are  as
follows:

1.  The  average  price  for a barrel of oil received  by  the  Partnership
    increased  during the nine months ended September 30, 2004 as  compared
    to  the  nine  months ended September 30, 2003 by  23%,  or  $6.99  per
    barrel,  resulting in an increase of approximately $104,800  in  income
    from net profits interests.  Oil sales represented 35% of total oil and
    gas  sales during the nine months ended September 30, 2004 as  compared
    to 32% during the nine months ended September 30, 2003.

    The  average  price  for  an  mcf of gas received  by  the  Partnership
    increased  during the same period by 9%, or $.46 per mcf, resulting  in
    an  increase  of  approximately $84,700  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
    $189,500.  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.


2.  Oil  production decreased approximately 1,300 barrels or 8% during  the
    nine  months  ended September 30, 2004 as compared to the  nine  months
    ended  September  30,  2003, resulting in a decrease  of  approximately
    $39,300 in income from net profits interests.

    Gas  production  decreased approximately 24,300 mcf or 12%  during  the
    same  period,  resulting  in  a decrease of approximately  $123,100  in
    income from net profits interests.

    The  total  decrease in income from net profits interests  due  to  the
    change  in production is approximately $162,400.  The decrease  in  gas
    volumes is due to production declines on three wells.

3.  Lease   operating  costs  and  production  taxes  were  6%  lower,   or
    approximately  $36,100 less during the nine months ended September  30,
    2004 as compared to the nine months ended September 30, 2003.

Costs and Expenses

Total  costs and expenses decreased to $236,699 from $260,012 for the  nine
months  ended September 30, 2004 and 2003, respectively, a decrease of  9%.
The decrease is the result of depletion expense, general and administrative
costs, partially offset by an increase in accretion 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 decreased 2%
    or approximately $2,400 during the nine months ended September 30, 2004
    as compared to the nine months ended September 30, 2003.

2.  Depletion  expense  decreased to $80,781  for  the  nine  months  ended
    September  30,  2004 from $103,000 for the same period in  2003.   This
    represents a decrease of 22%.  The contributing factor to the  decrease
    in  depletion expense is in relation to the BOE depletion rate for  the
    nine months ended September 30, 2004, which was $1.77 applied to 45,681
    BOE  as compared to $2.02 applied to 51,050 BOE for the same period  in
    2003.   The  lower  depreciation rate in 2004  is  due  to  the  upward
    revision in reserve estimates resulting from higher oil and gas prices.

3.  Accretion  expense  increased to $30,803  for  the  nine  months  ended
    September  30,  2004 from $29,501 for the same period  in  2003.   This
    represents an increase of 4%.




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

Cash  flows  provided by (used in) operating activities were  approximately
$844,600  in  the  nine  months ended September 30,  2004  as  compared  to
approximately  $686,200 in the nine months ended September 30,  2003.   The
primary  source  of  the  2004  cash flow  from  operating  activities  was
operations.

There  were  no  cash flows provided by investing activities  in  the  nine
months   ended  September  30,  2004.  Cash  flows  provided  by  investing
activities  were approximately $300 in the nine months ended September  30,
2003.

Cash flows used in financing activities were approximately $875,000 in  the
nine  months ended September 30, 2004 as compared to approximately $503,400
in  the  nine  months ended September 30, 2003.  The only use in  financing
activities was the distributions to partners.

Total  distributions during the nine months ended September 30,  2004  were
$875,000  of  which  $787,500 was distributed to the limited  partners  and
$87,500  to  the  general partners.  The per unit distribution  to  limited
partners during the nine months ended September 30, 2004 was $39.38.  Total
distributions during the nine months ended September 30, 2003 were $500,091
of  which  $450,082 was distributed to the limited partners and $50,009  to
the general partners.  The per unit distribution to limited partners during
the nine months ended September 30, 2003 was $22.50.

The  sources  for  the  2004 distributions of $875,000  were  oil  and  gas
operations of approximately $844,600, with the balance from available  cash
on  hand  at  the  beginning  of the period.   The  sources  for  the  2003
distributions  of  $500,091  were oil and gas operations  of  approximately
$686,200  and  the change in oil and gas properties of approximately  $300,
resulting in excess cash for contingencies or subsequent distributions.

Cumulative  cash  distributions  of  $19,078,945  have  been  made  to  the
partners.   As  of September 30, 2004, $17,186,759 or $859.34  per  limited
partner  unit has been distributed to the limited partners, representing  a
100% return of the capital and a 72% return on capital contributed.

As  of  September  30, 2004, the Partnership had approximately  410,600  in
working  capital.   The  Managing  General  Partner  knows  of  no  unusual
contractual  commitments.  The partnership held many long-lived  properties
at  inception,  however  due to the restrictions  on  property  development
imposed  by  the partnership agreement, the Partnership cannot develop  its
non-producing  properties.   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.

Managing General Partner

On May 21, 2004, Clayton Williams Energy, Inc. acquired all the outstanding
common  stock  of  Southwest  Royalties Inc.  through  a  merger.   Clayton
Williams Energy, Inc. paid $57.1 million to holders of Southwest Royalties,
Inc.  common stock and common stock warrants ($45.01 per share) and assumed
and  refinanced  approximately  $113.9 million  of  assumed  bank  debt  at
closing.





Item 3.   Quantitative and Qualitative Disclosures About Market Risk

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

Disclosure Controls and Procedures
As  of  the nine months ended September 30, 2004, L. Paul Latham, President
and  Chief  Executive Officer of the Managing General Partner, and  Mel  G.
Riggs,  Vice President and Chief Financial Officer of the Managing  General
Partner,  evaluated  the  effectiveness  of  the  Partnership's  disclosure
controls and procedures.  Based on their evaluation, they believe that:

     The  disclosure  controls  and  procedures  of  the  Partnership  were
     effective in ensuring that information required to be disclosed by the
     Partnership in the reports it files or submits under the Exchange  Act
     was  recorded,  processed,  summarized and reported  within  the  time
     periods specified in the SEC's rules and forms; and

     The  disclosure  controls  and  procedures  of  the  Partnership  were
     effective  in  ensuring  that  material  information  required  to  be
     disclosed by the Partnership in the report it filed or submitted under
     the  Exchange  Act was accumulated and communicated  to  the  Managing
     General  Partner's  management, including its Chief Executive  Officer
     and  Chief Financial Officer, as appropriate to allow timely decisions
     regarding required disclosure.

Internal Control Over Financial Reporting
There  has  not been any change in the Partnership's internal control  over
financial  reporting that occurred during the nine months  ended  September
30,  2004  that  has  materially  affected,  or  is  reasonably  likely  to
materially affect, internal control over financial reporting.



                        PART II - OTHER INFORMATION


Item 1.Legal Proceedings

       None

Item 2.Changes in Securities

       None

Item 3.Defaults Upon Senior Securities

       None

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

       None

Item 5.Other Information

       None

Item 6.Exhibits and Reports on Form 8-K

          (a)  Exhibits:

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

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



                                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, INC.
                              INCOME FUND VI,
                              a Tennessee limited partnership


                              By:  Southwest Royalties, Inc.
                                   Managing General Partner


                              By: /s/ Mel G. Riggs
                                Mel G. Riggs
                                Vice President and Chief Financial Officer


Date:  November 15, 2004

                    SECTION 302 CERTIFICATION                Exhibit 31.1


I, L. Paul Latham, certify that:

1.   I  have  reviewed  this quarterly report on  Form  10-Q  of  Southwest
Royalties, Inc. Income Fund VI

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

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

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

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

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

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

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

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

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


Date:  November 15, 2004           /s/ L. Paul Latham
                                   L. Paul Latham
                                   President and Chief Executive Officer
                                   of Southwest Royalties, Inc., the
                                   Managing General Partner of
                                   Southwest Royalties, Inc. Income Fund VI

                    SECTION 302 CERTIFICATION                Exhibit 31.2


I, Mel G. Riggs, certify that:

1.   I  have  reviewed  this quarterly report on  Form  10-Q  of  Southwest
Royalties, Inc. Income Fund VI

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

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

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

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

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

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

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

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

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


Date:  November 15, 2004           /s/ Mel G. Riggs
                                   Mel G. Riggs
                                     Vice  President  and  Chief  Financial
Officer of
                                   Southwest Royalties, Inc., the
                                   Managing General Partner of
                                   Southwest Royalties, Inc. Income Fund VI


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


      In  connection with the Quarterly Report of Southwest Royalties, Inc.
Income  Fund  VI,  (the  "Company") on Form  10-Q  for  the  period  ending
September 30, 2004 as filed with the Securities and Exchange Commission  on
the  date hereof (the "Report"), I, L. Paul Latham, 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 15, 2004




/s/ L. Paul Latham
L. Paul Latham
President and Chief Executive Officer
  of Southwest Royalties, Inc., the
  Managing General Partner of
  Southwest Royalties, Inc. Income Fund VI



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


      In  connection with the Quarterly Report of Southwest Royalties, Inc.
Income  Fund  VI,  (the  "Company") on Form  10-Q  for  the  period  ending
September 30, 2004 as filed with the Securities and Exchange Commission  on
the date hereof (the "Report"), I, Mel G. Riggs, 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 15, 2004




/s/ Mel G. Riggs
Mel G. Riggs
Vice President and Chief Financial Officer of
  Southwest Royalties, Inc., the
  Managing General Partner of
  Southwest Royalties, Inc. Income Fund VI