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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 March 31, 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.)


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

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

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

                              Yes X No ___

Indicate  by  check mark whether 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 22.

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

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

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

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

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

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

     Mcf. One thousand cubic feet.

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

     Oil. Crude oil, condensate and natural gas liquids.

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

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

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

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

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

     Proved properties. Properties with proved reserves.

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

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

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

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

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

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

<PAGE>
                     PART I. - FINANCIAL INFORMATION


Item 1.   Financial Statements

The  unaudited condensed financial statements included herein have  been
prepared   by   the  Registrant  (herein  also  referred   to   as   the
"Partnership")   in   accordance  with  generally  accepted   accounting
principles  for interim financial information and with the  instructions
to Form 10-Q and Rule 10-01 of Regulation S-X.  Accordingly, they do not
include  all  of  the  information and footnotes required  by  generally
accepted  accounting principles for complete financial  statements.   In
the  opinion  of  management,  all  adjustments  necessary  for  a  fair
presentation  have  been included and are of a normal recurring  nature.
The  financial statements should be read in conjunction with the audited
financial  statements and the notes thereto for the year ended  December
31,  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-month  period
ended March 31, 2004 are not necessarily indicative of the results  that
may be expected for the full year.




<PAGE>
                 Southwest Royalties, Inc. Income Fund VI
                              Balance Sheets


                                           March   December
                                            31,       31,
                                           2004      2003
                                          ------    ------
                                         (unaudit
                                            ed)
Assets
---------
Current assets:
 Cash and cash equivalents            $  195,181   234,954
  Receivable  from  Managing  General    245,903   189,477
Partner
 Oklahoma withholding prepayment         124       124
                                         --------  --------
                                         -----     -----
   Total current assets                  441,208   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            6,170,46  6,143,46
                                         0         0
                                         --------  --------
                                         -----     -----
   Net oil and gas properties            2,376,85  2,403,85
                                         7         7
                                         --------  --------
                                         -----     -----
                                      $  2,818,06  2,828,41
                                         5         2
                                         =======   =======
Liabilities and Partners' Equity
-------------------------------------
---

Asset retirement obligation           $  523,668   513,400
                                         --------  --------
                                         -----     -----

Partners' equity:
 General partner                         (624,891  (622,829
                                         )         )
 Limited partners                        2,919,28  2,937,84
                                         8         1
                                         --------  --------
                                         -----     -----
   Total partners' equity                2,294,39  2,315,01
                                         7         2
                                         --------  --------
                                         -----     -----
                                      $  2,818,06  2,828,41
                                         5         2
                                         =======   =======


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

                                    Three Months Ended
                                        March 31,
                                      2004      2003
                                     ------    ------
Revenues
-------------
Income    from   net    profits  $  381,225   297,280
interests
Interest                            462       18
Other                               250       -
                                    --------  --------
                                    ---       ---
                                    381,937   297,298
                                    --------  --------
                                    ---       ---
Expenses
-------------
General and administrative          40,284    37,477
Depreciation,   depletion   and     27,000    28,000
amortization
Accretion  of asset  retirement     10,268    9,997
obligation
                                    --------  --------
                                    ---       ---
                                    77,552    75,474
                                    --------  --------
                                    ---       ---
Net  income  before  cumulative     304,385   221,824
effect

Cumulative effect of change  in
accounting
 principle - SFAS No. 143 - See     -         116,637
Note 3
                                    --------  --------
                                    ---       ---
Net income                       $  304,385   338,461
                                    ======    ======
Net income allocated to:

 Managing General Partner        $  30,438    33,846
                                    ======    ======
 Limited partners                $  273,947   304,615
                                    ======    ======
    Per  limited  partner  unit  $   13.70
before cumulative effect                      9.98
  Cumulative effect per limited          -
partner unit                                  5.25
                                    --------  --------
                                    ---       ---
  Per limited partner unit       $   13.70
                                              15.23
                                    ======    ======

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

                                      Three Months Ended
                                          March 31,
                                        2004      2003
                                       ------    ------
Cash    flows   from    operating
activities:

  Cash received from income  from
net profits
  interests                        $  307,243   112,891
 Cash paid to suppliers               (22,728)  (17,482)
 Interest received                    462       18
 Other                                250       -
                                      --------  --------
                                      --        --
   Net cash provided by operating     285,227   95,427
activities
                                      --------  --------
                                      --        --
Cash   flows  used  in  financing
activities:

 Distributions to partners            (325,000  (1,077)
                                      )
                                      --------  --------
                                      --        --
Net  (decrease) increase in  cash     (39,773)  94,350
and cash equivalents

 Beginning of period                  234,954   18,015
                                      --------  --------
                                      --        --
 End of period                     $  195,181   112,365
                                      ======    ======
Reconciliation of net  income  to
net
    cash  provided  by  operating
activities:

Net income                         $  304,385   338,461

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

   Depreciation,  depletion   and     27,000    28,000
amortization
  Accretion  of asset  retirement     10,268    9,997
obligation
  Cumulative effect of change  in
accounting
  principle - SFAS No. 143            -         (116,637
                                                )
 Increase in receivables              (73,982)  (184,389
                                                )
 Increase in payables                 17,556    19,995
                                      --------  --------
                                      --        --
Net  cash  provided by  operating  $  285,227   95,427
activities
                                      ======    ======
Noncash  investing and  financing
activities:

   Increase   in  oil   and   gas  $  -         616,464
properties - Adoption
  of SFAS No.143                      ======    ======
<PAGE>
                 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. 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 costs (1)     100%      -
Amortization of organization costs      100%      -
Property acquisition costs              100%      -
Gain/loss on property disposition       90%       10%
Operating and administrative costs (2)  90%       10%
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 March 31, 2004, and for the
     three   months  ended  March  31,  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  March
     31,  2004,  the  asset  retirement obligation  was  $523,668.   The
     increase in the asset retirement obligation from January 1, 2004 is
     due to accretion expense of $10,268.

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

                      Notes to Financial Statements

4.   Subsequent Event
      Subsequent  to  December  31, 2003, the Managing  General  Partner
announced that its Board of Directors had decided to   explore a  merger
or  sale  of  the  stock  of the Company.  The Board  formed  a  Special
Committee  of  independent directors      to oversee the  sale  process.
The  Special Committee retained independent financial and legal advisors
to work closely     with management to implement the sale process.

     On  May  3, 2004, the Managing General Partner entered into a  cash
     merger  agreement  to  sell all of its stock  to  Clayton  Williams
     Energy,  Inc.   The cash merger price is being negotiated,  but  is
     expected to be approximately $45 per share.  The transaction, which
     is   subject   to  approval  by  the  Managing  General   Partner's
     shareholders, is expected to close no later than May 21, 2004.




<PAGE>
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 decline in later years based on these factors.

Based on current conditions, development drilling and workovers will  be
performed  during  the  years 2004 and 2005 to enhance  production.  The
partnership may have an increase in production volumes for the year 2004
and  2005, but thereafter, the partnership will most likely continue  to
experience the historical production decline, which has approximated 10%
per  year.   Accordingly,  if  commodity prices  remain  unchanged,  the
Partnership  expects  future  earnings to  decline  due  to  anticipated
production declines.

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 sold.

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

Should  the net capitalized costs exceed the estimated present value  of
oil  and  gas  reserves, discounted at 10%, such excess costs  would  be
charged  to  current expense. As of March 31, 2004, the net  capitalized
costs  did  not  exceed  the estimated present  value  of  oil  and  gas
reserves.


<PAGE>
The  Partnership's interest in oil and gas properties  consists  of  net
profits  interests in proved properties located within  the  continental
United  States.  A net profits interest is created when the owner  of  a
working interest in a property enters into an arrangement providing that
the  net profits interest owner will receive a stated percentage of  the
net  profit from the property.  The net profits interest owner will  not
otherwise participate in additional costs and expenses of the property.

The  Partnership recognizes income from its net profits interest in  oil
and  gas  property  on  an  accrual  basis,  while  the  quarterly  cash
distributions of the net profits interest are based on a calculation  of
actual  cash  received from oil and gas sales, net of expenses  incurred
during  that  quarterly period. If the net profits interest  calculation
results  in expenses incurred exceeding the oil and gas income  received
during  a quarter, no cash distribution is due to the Partnership's  net
profits interest until the deficit is recovered from future net profits.
The  Partnership  accrues a quarterly loss on its net  profits  interest
provided there is a cumulative net amount due for accrued revenue as  of
the  balance  sheet date.  As of March 31, 2004, there  were  no  timing
differences, which resulted in a deficit net profit interest.

Critical Accounting Policies

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

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

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

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

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

<PAGE>
Results of Operations

A.  General Comparison of the Quarters Ended March 31, 2004 and 2003

The  following table provides certain information regarding  performance
factors for the quarters ended March 31, 2004 and 2003:

                          Three Months
                             Ended         Percenta
                                              ge
                           March 31,       Increase
                         2004      2003    (Decreas
                                              e)
                        -----     -----    --------
                                              --
Average price  per  $   33.10              2%
barrel of oil                    32.30
Average price  per  $    5.67              (6%)
mcf of gas                       6.01
Oil production  in     5,880     4,600     28%
barrels
Gas production  in     58,800    54,800    7%
mcf
Income  from   net  $  381,225   297,280   28%
profits interests
Partnership         $  325,000   -         100%
distributions
Limited    partner  $  292,500   -         100%
distributions
Per           unit
distribution    to
limited
 partners           $   14.63    -         100%

Number  of limited     20,000    20,000
partner units
Revenues

The  Partnership's  income  from  net  profits  interests  increased  to
$381,225  from $297,280 for the quarters ended March 31, 2004 and  2003,
respectively,  an increase of 28%.  The principal factors affecting  the
comparison of the quarters ended March 31, 2004 and 2003 are as follows:

1.  The  average  price for a barrel of oil received by the  Partnership
    increased during the quarter ended March 31, 2004 as compared to the
    quarter ended March 31, 2003 by 2%, or $.80 per barrel, resulting in
    an  increase  of  approximately $4,700 in income  from  net  profits
    interests.   Oil sales represented 37% of total oil  and  gas  sales
    during  the  quarter ended March 31, 2004 as compared to 31%  during
    the quarter ended March 31, 2003.

    The  average  price  for an mcf of gas received by  the  Partnership
    decreased  during the same period by 6%, or $.34 per mcf,  resulting
    in  a  decrease of approximately $20,000 in income from net  profits
    interests.

    The  net total decrease in income from net profits interests due  to
    the  change  in  prices  received from oil  and  gas  production  is
    approximately $15,300.  The market price for oil and  gas  has  been
    extremely  volatile over the past decade, and management  expects  a
    certain amount of volatility to continue in the foreseeable future.

<PAGE>
2.  Oil  production increased approximately 1,280 barrels or 28%  during
    the  quarter  ended March 31, 2004 as compared to the quarter  ended
    March 31, 2003, resulting in an increase of approximately $41,300 in
    income from net profits interests.

    Gas  production increased approximately 4,000 mcf or 7%  during  the
    same  period, resulting in an increase of approximately  $24,000  in
    income from net profits interests.

    The  total increase in income from net profits interests due to  the
    change  in  production  is  approximately $65,300.   Oil  production
    during  the  first  quarter 2003 was adjusted in connection  with  a
    change in estimate.  The Partnership was receiving revenue on a well
    in  which  they  did not have an interest, but owned  a  very  small
    interest on another well on a different lease.

3.  Lease  operating  costs  and production taxes  were  19%  lower,  or
    approximately $33,400 less during the quarter ended March  31,  2004
    as  compared to the quarter ended March 31, 2003.  The higher  lease
    operating  costs  in 2003 were the result of adding artificial  lift
    equipment to a well.

Costs and Expenses

Total  costs  and  expenses increased to $77,552 from  $75,474  for  the
quarters ended March 31, 2004 and 2003, respectively, an increase of 3%.
The  increase  is  a direct result of the increase in accretion  expense
associated  with our long term liability related to expected abandonment
costs   of   our  oil  and  natural  gas  properties  and  general   and
administrative  expense,  partially offset by a  decrease  in  depletion
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 7% or approximately $2,800 during the quarter ended  March
    31,  2004  as  compared to the quarter ended March  31,  2003.   The
    increase in general and administrative costs is due primarily to  an
    increase of $1,660 in quarterly accounting review fees.

2. Depletion  expense decreased to $27,000 for the quarter  ended  March
   31,  2004  from $28,000 for the same period in 2003.  This represents
   a  decrease  of  4%.   The contributing factor  to  the  decrease  in
   depletion  expense is in relation to the BOE depletion rate  for  the
   quarter  ended March 31, 2004, which was $1.72 applied to 15,680  BOE
   as  compared  to $2.04 applied to 13,733 BOE for the same  period  in
   2003.

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  March  31, 2004, the asset retirement  obligation  was
$523,668.  The increase in the asset retirement obligation from  January
1, 2004 is due to accretion expense of $10,268.


<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 $285,200
in the quarter ended March 31, 2004 as compared to approximately $95,400
in the quarter ended March 31, 2003.

Cash  flows used in financing activities were approximately $325,000  in
the quarter ended March 31, 2004 as compared to approximately $1,100  in
the  quarter ended March 31, 2003.  The only use in financing activities
was the distributions to partners.

Total  distributions  during  the quarter  ended  March  31,  2004  were
$325,000  of which $292,500 was distributed to the limited partners  and
$32,500  to  the general partner.  The per unit distribution to  limited
partners during the quarter ended March 31, 2004 was $14.63.  There were
no distributions during the quarter ended March 31, 2003.

The  source  for  the 2004 distributions of $325,000  was  oil  and  gas
operations  of  approximately $285,200, with the balance from  available
cash on hand at the beginning of the period.

Cumulative  cash  distributions of $18,528,945 have  been  made  to  the
general  and  limited  partners.  As of March 31, 2004,  $16,691,759  or
$834.59  per  limited partner unit has been distributed to  the  limited
partners, representing a 100% return of the capital and a 67% return  on
capital contributed.

As  of  March  31, 2004, the Partnership had approximately  $441,200  in
working  capital.   The Managing General Partner  knows  of  no  unusual
contractual commitments.  Although the partnership held many  long-lived
properties  at  inception,  because  of  the  restrictions  on  property
development imposed by the partnership agreement, the Partnership cannot
develop  its  non  producing  properties,  if  any.   Without  continued
development,  the producing reserves continue to deplete.   Accordingly,
as  the Partnership's properties have matured and depleted, the net cash
flows  from operations for the partnership has steadily declined, except
in periods of substantially increased commodity pricing.  Maintenance of
properties   and   administrative  expenses  for  the  Partnership   are
increasing  relative  to  production.  As  the  properties  continue  to
deplete,  maintenance  of  properties  and  administrative  costs  as  a
percentage of production are expected to continue to increase.


<PAGE>

Liquidity - Managing General Partner

As of December 31, 2003, the Managing General Partner is in violation of
several  covenants  pertaining to their Amended and  Restated  Revolving
Credit  Agreement due June 1, 2006 and their Senior Second Lien  Secured
Credit  Agreement due October 15, 2008.  Due to the covenant violations,
the  Managing  General  Partner is in default under  their  Amended  and
Restated  Revolving Credit Agreement and the Senior Second Lien  Secured
Credit  Agreement, and all amounts due under these agreements have  been
classified  as  a  current liability on the Managing  General  Partner's
balance  sheet  at December 31, 2003.  The significant  working  capital
deficit  and  debt  being  in  default  at  December  31,  2003,   raise
substantial  doubt  about  the  Managing General  Partner's  ability  to
continue as a going concern.

Subsequent to December 31, 2003, the Board of Directors of the  Managing
General Partner announced its decision to explore a merger, sale of  the
stock or other transaction involving the Managing General Partner.   The
Board has formed a Special Committee of independent directors to oversee
the  sales  process.   The  Special Committee has  retained  independent
financial and legal advisors to work closely with the management of  the
Managing General Partner to implement the sales process.  There  can  be
no  assurance  that  a  sale of the Managing  General  Partner  will  be
consummated or what terms, if consummated, the sale will be on.

On  May 3, 2004, the Managing General Partner entered into a cash merger
agreement to sell all of its stock to Clayton Williams Energy, Inc.  The
cash   merger  price  is  being  negotiated,  but  is  expected  to   be
approximately  $45  per share.  The transaction,  which  is  subject  to
approval by the Managing General Partner's shareholders, is expected  to
close no later than May 21, 2004.

Recent Accounting Pronouncements

The  EITF is considering two issues related to the reporting of oil  and
gas mineral rights. Issue No. 03-O, "Whether Mineral Rights Are Tangible
or  Intangible Assets," is whether or not mineral rights are  intangible
assets pursuant to SFAS No. 141, "Business Combinations." Issue No.  03-
S,  "Application of SFAS No. 142, Goodwill and Other Intangible  Assets,
to  Oil  and  Gas  Companies," is, if oil and gas  drilling  rights  are
intangible   assets,   whether  those  assets   are   subject   to   the
classification  and  disclosure  provisions  of  SFAS  No.   142.    The
Partnership  classifies  the  cost of oil  and  gas  mineral  rights  as
properties and equipment and believes that this is consistent  with  oil
and  gas accounting and industry practice.  The disclosures required  by
SFAS  Nos.  141  and  142 would be made in the notes  to  the  financial
statements. There would be no effect on the statement of income or  cash
flows  as  the  intangible assets related to oil and gas mineral  rights
would continue to be amortized under the full cost method of accounting.

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

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

Item 4.   Controls and Procedures

Disclosure Controls and Procedures
As  of  the  three  months  ended March 31,  2004,  H.H.  Wommack,  III,
President  and Chief Executive Officer of the Managing General  Partner,
and Bill E. Coggin, Executive 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 President  and
    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 three months  ended  March
31,  2004  that  has  materially affected, or is  reasonably  likely  to
materially affect, it internal control over financial reporting.



<PAGE>
                       PART II. - OTHER INFORMATION


Item 1.   Legal Proceedings

               None

Item 2.   Changes in Securities

               None

Item 3.   Defaults Upon Senior Securities

               None

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

               None

Item 5.   Other Information

               None

Item 6.   Exhibits and Reports on Form 8-K

               (a)  Exhibits:

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

               (b)  Reports on Form 8-K:

                     No  reports  on  Form  8-K were  filed  during  the
               quarter for which this report is filed.
<PAGE>
                                SIGNATURES


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

                              SOUTHWEST ROYALTIES, INC.
                              INCOME FUND VI,
                              a Tennessee limited partnership


                              By:  Southwest Royalties, Inc.
                                   Managing General Partner


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



Date:  May 14, 2004

<PAGE>

                   SECTION 302 CERTIFICATION                Exhibit 31.1


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

1.    I  have  reviewed this quarterly report on Form 10-Q of  Southwest
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  15-15(e))  and
  internal control over financial reporting (as defined in Exchange  Act
  Rules 13a-15(f) and 15d-15(f) for the registrant and have:

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

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

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

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

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

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

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


Date:  May 14, 2004                /s/ H. H. Wommack, III
                                   H. H. Wommack, III
                                     Chairman,   President   and   Chief
Executive Officer
                                   of Southwest Royalties, Inc., the
                                   Managing General Partner of
                                   Southwest Royalties, Inc. Income Fund
VI

<PAGE>
                   SECTION 302 CERTIFICATION                Exhibit 31.2


I, Bill E. Coggin, certify that:

1.    I  have  reviewed this quarterly report on Form 10-Q of  Southwest
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  15-15(e))  and
  internal control over financial reporting (as defined in Exchange  Act
  Rules 13a-15(f) and 15d-15(f) for the registrant and have:

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

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

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

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

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

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

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


Date:  May 14, 2004                /s/ Bill E. Coggin
                                   Bill E. Coggin
                                   Executive Vice President
                                   and Chief Financial Officer of
                                   Southwest Royalties, Inc., the
                                   Managing General Partner of
                                   Southwest Royalties, Inc. Income Fund
VI

<PAGE>
                  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, L.P. (the "Company") on Form 10-Q for  the  period
ending  March  31,  2004  as  filed with  the  Securities  and  Exchange
Commission  on  the  date hereof (the "Report"), I, H.H.  Wommack,  III,
Chief  Executive Officer of the Managing General Partner of the Company,
certify,  pursuant to 18 U.S.C.  1350, as adopted pursuant  to   906  of
the Sarbanes-Oxley Act of 2002, that:

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

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


Date:  May 14, 2004




/s/ H.H. Wommack, III
H. H. Wommack, III
Chairman, President, Director and Chief Executive Officer
  of Southwest Royalties, Inc., the
  Managing General Partner of
  Southwest Royalties, Inc. Income Fund VI

<PAGE>

                  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, L.P. (the "Company") on Form 10-Q for  the  period
ending  March  31,  2004  as  filed with  the  Securities  and  Exchange
Commission  on the date hereof (the "Report"), I, Bill E. Coggin,  Chief
Financial  Officer  of  the Managing General  Partner  of  the  Company,
certify,  pursuant to 18 U.S.C.  1350, as adopted pursuant  to   906  of
the Sarbanes-Oxley Act of 2002, that:

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

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


Date:  May 14, 2004




/s/ Bill E. Coggin
Bill E. Coggin
Executive Vice President
  and Chief Financial Officer of
  Southwest Royalties, Inc., the
  Managing General Partner of
  Southwest Royalties, Inc. Income Fund VI

<PAGE>