FORM 10-K
                    SECURITIES AND EXCHANGE COMMISSION
                          WASHINGTON, D.C.  20549
(Mark One)

[x]    Annual  report  pursuant to Section 13 or 15(d)  of  the  Securities
       Exchange Act of 1934

For the fiscal year ended December 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                             (I.R.S. Employer
of incorporation or organization)                       Identification No.)

6 Desta Drive, Suite 6500, Midland, Texas                     79705
(Address of principal executive office)                     (Zip Code)

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

       Securities registered pursuant to Section 12(b) of the Act:

                                   None

       Securities registered pursuant to Section 12(g) of the Act:

                      limited partnership interests

Indicate by check mark whether registrant (1) has filed 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 if disclosure of delinquent filers pursuant to  Item
405  of  Regulation S-K is not contained herein, and will not be contained,
to  the  best of registrant's knowledge, in definitive proxy or information
statements incorporated by reference in Part III of this Form 10-K  or  any
amendment to this Form 10-K.     [x]

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.


<PAGE>

                            Table of Contents

Item                                                                   Page

     Glossary of Oil and Gas Terms                                       3

                                  Part I

 1.  Business                                                            5

 2.  Properties                                                          8

 3.  Legal Proceedings                                                   9

 4.  Submission of Matters to a Vote of Security Holders                 9

                                 Part II

 5.  Market for Registrant's Common Equity, Related
     Stockholder Matters and Issuer Purchases of Equity Securities      10

 6.  Selected Financial Data                                            11

 7.  Management's Discussion and Analysis of
     Financial Condition and Results of Operations                      12

7A.  Quantitative and Qualitative Disclosures About Market Risk         18

 8.  Financial Statements and Supplementary Data                        19

 9.  Changes in and Disagreements with Accountants
     on Accounting and Financial Disclosure                             34

9A.  Controls and Procedures                                            34

9B.  Other Information                                                  34

                                 Part III

10.  Directors and Executive Officers of the Registrant                 35

11.  Executive Compensation                                             35

12.  Security Ownership of Certain Beneficial Owners and Management     36

13.  Certain Relationships and Related Transactions                     36

14.  Principal Accounting Fees and Services                             36

                                 Part IV

15.  Exhibits and Financial Statement Schedules                         37

     Signatures                                                         41

<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.

     BOE.   Equivalent  barrels of oil, with natural gas converted  to  oil
equivalents based on a ratio of six Mcf of natural gas to one Bbl of oil.

     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 a leasehold or
working  interest agrees to assign his interest in certain specific acreage
to  an  assignee,  retaining some interest, such as an  overriding  royalty
interest,  subject  to  the drilling of one (1)  or  more  wells  or  other
specified 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%.

<PAGE>

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

     Proved properties. Properties with proved reserves.

     Proved  oil  and gas reserves. The estimated quantities of crude  oil,
natural  gas, and natural gas liquids with geological and engineering  data
that  demonstrate  with  reasonable certainty to be recoverable  in  future
years   from  known  reservoirs  under  existing  economic  and   operating
conditions, i.e., prices and costs as of the date the estimate is made.

     Proved  undeveloped  reserves. Proved oil  &  gas  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

Item 1.   Business

General
Southwest   Royalties,   Inc.  Income  Fund  VI   (the   "Partnership"   or
"Registrant") was organized as a Tennessee limited partnership on  December
4,  1986.   The offering of limited partnership interests began August  25,
1986, reached minimum capital requirements on October 3, 1986 and concluded
January  29,  1987.   The  Partnership has no subsidiaries.   The  Managing
General  Partner  of  the  Partnership is Southwest  Royalties,  Inc.  (the
"Managing General Partner"), a Delaware corporation.

The  Partnership  has  expended  its  capital  and  acquired  interests  in
producing oil and gas properties.  After such acquisitions, the Partnership
has  produced and marketed the crude oil and natural gas produced from such
properties.  In most cases, the Partnership purchased royalty or overriding
royalty interests and working interests in oil and gas properties that were
converted  into net profits interests or other nonoperating interests.  The
Partnership  purchased  either all or part of the  rights  and  obligations
under various oil and gas leases.

During  2004, the Managing General Partner was acquired by Clayton Williams
Energy,  Inc.  ("CWEI"), a Delaware corporation, and is now a wholly  owned
subsidiary  of  CWEI.   CWEI is an oil and gas company  based  in  Midland,
Texas, and its common stock is traded on the Nasdaq Stock Market's National
Market  under  the  symbol  "CWEI".  All of  the  directors  and  executive
officers  of  the  Managing General Partner are employees  of  CWEI.   CWEI
maintains an internet website at www.claytonwilliams.com from which  public
information about CWEI may be obtained.

The  principal executive offices of the Partnership are located at 6  Desta
Drive, Suite 6500, Midland, Texas, 79705.  The Managing General Partner and
its  staff, together with certain independent consultants used  on  an  "as
needed"  basis,  perform  various services on behalf  of  the  Partnership,
including  the  selection of oil and gas properties and  the  marketing  of
production from such properties.  The Partnership has no employees.

Operations

The business objective of the Partnership is to maximize the production and
related  net  cash  flow  from the properties  it  currently  owns  without
engaging  in  the drilling of any development or exploratory  wells  except
through  farm-out  arrangements.  If additional drilling  is  necessary  to
fully  develop a Partnership property, the Partnership will  enter  into  a
farmout agreement with the Managing General Partner to assign a portion  of
the  Partnership's interest in the property to the Managing General Partner
in  exchange for retaining an interest in the one or more new wells  at  no
cost  to  the Partnership.  The Managing General Partner obtains a fairness
opinion  from an unaffiliated petroleum engineer with respect to the  terms
of each farmout agreement with the Partnership.

Principal Products and Markets
The  Partnership has acquired and holds royalty interests  and  net  profit
interests  in  oil  and gas properties located in Texas and  Oklahoma.  All
activities  of  the  Partnership are confined  to  the  continental  United
States.   During 2004, 35% of the Partnership's revenues were derived  from
the  sale of oil production and 65% were derived from gas production.   All
oil  and  gas  produced from these properties is sold  to  unrelated  third
parties  in  the oil and gas business.  The Partnership believes  that  the
loss  of any of its purchasers would not have a material adverse affect  on
its results of operations due to the availability of other purchasers.

The  revenues  generated from the Partnership's oil and gas activities  are
dependent upon the current market for oil and gas.  The prices received  by
the Partnership for its oil and gas production depend upon numerous factors
beyond   the   Partnership's  control,  including  competition,   economic,
political and regulatory developments and competitive energy sources.   The
Partnership  is  unable  to accurately predict future  prices  of  oil  and
natural gas.


<PAGE>
Competition
Because  the  Partnership has utilized all of its funds available  for  the
acquisition  of net profits or royalty interests in producing oil  and  gas
properties,  it  is  not  subject to competition from  other  oil  and  gas
property purchasers.  See Item 2, Properties.

Factors  that  may  adversely  affect the  Partnership  include  delays  in
completing  arrangements  for  the sale of production,  availability  of  a
market for production, rising operating costs of producing oil and gas  and
complying  with  applicable  water  and  air  pollution  control  statutes,
increasing  costs  and  difficulties of transportation,  and  marketing  of
competitive  fuels.   Moreover, domestic oil  and  gas  must  compete  with
imported oil and gas and with coal, atomic energy, hydroelectric power  and
other forms of energy.

Regulation

The Partnership's oil and gas production and related operations are subject
to  extensive rules and regulations promulgated by federal, state and local
agencies.  Failure to comply with such rules and regulations can result  in
substantial  penalties. The regulatory burden on the oil and  gas  industry
increases  the  Partnership's  cost  of  doing  business  and  affects  the
Partnership's  profitability.  Because  such  rules  and  regulations   are
frequently  amended or reinterpreted, the Partnership is unable to  predict
the future cost or impact of complying with such laws.

All  of  the  states  in which the Partnership conducts business  generally
require  permits  for  drilling  operations,  drilling  bonds  and  reports
concerning  operations  and  impose  other  requirements  relating  to  the
exploration  and production of oil and gas. Such states also have  statutes
or  regulations  addressing conservation matters, including provisions  for
the unitization or pooling of oil and gas properties, the establishment  of
maximum  rates  of  production from oil and  gas  wells  and  the  spacing,
plugging  and  abandonment of such wells. The statutes and  regulations  of
certain  states  also limit the rate at which oil and gas can  be  produced
from the Partnership's properties.

The  Federal  Energy  Regulatory Commission ("FERC")  regulates  interstate
natural  gas transportation rates and service conditions, which affect  the
marketing  of gas produced by the Partnership, as well as the revenues  the
Partnership  receives for sales of such production.  Since  the  mid-1980s,
the  FERC  has  issued various orders that have significantly  altered  the
marketing  and  transportation  of  gas.   These  orders  resulted   in   a
fundamental  restructuring of interstate pipeline sales and  transportation
services,  including the unbundling by interstate pipelines of  the  sales,
transportation,  storage  and  other  components  of  the  city-gate  sales
services  such  pipelines previously performed.  These  FERC  actions  were
designed  to  increase competition within all phases of the  gas  industry.
The  interstate regulatory framework may enhance the Partnership's  ability
to  market and transport its gas, although this framework may also  subject
the  Partnership  to  competition  and to  the  more  restrictive  pipeline
imbalance tolerances and greater associated penalties for violation of such
tolerances.

The  Partnership's sales of oil production are not presently regulated  and
are  made  at market prices.  The price the Partnership receives  from  the
sale of those products is affected by the cost of transporting the products
to  market.  The FERC has implemented regulations establishing an  indexing
system for transportation rates for oil pipelines, which, generally,  would
index   such  rates  to  inflation,  subject  to  certain  conditions   and
limitations.   The  Partnership is not able to predict with  any  certainty
what  effect, if any, these regulations will have on the Partnership,  but,
other factors being equal, the regulations may, over time, tend to increase
transportation costs which may have the effect of reducing wellhead  prices
for oil and natural gas liquids.

Environmental Matters

The  Partnership's  operations pertaining to oil  and  gas  production  and
related activities are subject to numerous and constantly changing federal,
state  and  local  laws  governing  the discharge  of  materials  into  the
environment or otherwise relating to environmental protection.  These  laws
and regulations may require the acquisition of certain permits prior to  or
in  connection  with drilling activities, restrict or prohibit  the  types,
quantities  and concentration of substances that can be released  into  the
environment  in  connection  with  drilling  and  production,  restrict  or
prohibit  drilling  activities that could impact  wetlands,  endangered  or
threatened  species or other protected areas or natural resources,  require
some   degree  of  remedial  action  to  mitigate  pollution  from   former
operations, such as pit cleanups and plugging abandoned wells,  and  impose
substantial  liabilities  for pollution resulting  from  the  Partnership's
operations.  Such laws and regulations may substantially increase the  cost
of developing, producing or processing oil and gas and may prevent or delay
the  commencement  or continuation of a given project  and  thus  generally
could  have a material adverse effect upon the Partnership's cash flow  and
earnings.   The  Partnership believes that it is in substantial  compliance
with current applicable environmental laws and regulations, and the cost of
compliance with such laws and regulations has not been material and is  not
expected  to  be material during 2005.  Nevertheless, changes  in  existing
environmental laws and regulations or in the interpretations thereof  could
have  a significant impact on the Partnership's operations, as well as  the
oil  and  gas  industry  in general.  For instance,  legislation  has  been
proposed  in  Congress from time to time that would reclassify certain  oil
and  gas  production  wastes as "hazardous wastes," which  reclassification
would make exploration and production wastes subject to much more stringent
handling, disposal and clean-up requirements.  State initiatives to further
regulate  the  disposal  of  oil  and gas wastes  and  naturally  occurring
radioactive  materials,  if adopted, could have a  similar  impact  on  the
Partnership.
<PAGE>
The  United  States  Oil  Pollution Act of 1990 ("OPA  `90"),  and  similar
legislation enacted in Texas, Louisiana and other coastal states, addresses
oil  spill  prevention  and  control and  significantly  expands  liability
exposure across all segments of the oil and gas industry. OPA `90 and  such
similar  legislation and related regulations impose  on  us  a  variety  of
obligations  related  to  the prevention of oil spills  and  liability  for
damages  resulting  from  such spills.  OPA `90 imposes  strict  and,  with
limited  exceptions,  joint and several liabilities upon  each  responsible
party for oil removal costs and a variety of public and private damages.

The  Comprehensive Environmental Response, Compensation, and Liability  Act
("CERCLA"),  also known as the "Superfund" law, imposes liability,  without
regard to fault or the legality of the original conduct, on certain classes
of  persons  that are considered to have contributed to the  release  of  a
"hazardous  substance"  into the environment.  These  persons  include  the
owner  or  operator  of  the disposal site or the site  where  the  release
occurred  and companies that disposed or arranged for the disposal  of  the
hazardous substances at the site where the release occurred.  Under CERCLA,
such persons may be subject to joint and several liability for the costs of
cleaning  up  the  hazardous substances that have been  released  into  the
environment  and for damages to natural resources, and it is  not  uncommon
for  neighboring  landowners and other third parties  to  file  claims  for
personal  injury  and  property damage allegedly caused  by  the  hazardous
substances released into the environment.  The failure of an operator of  a
property  owned by the Partnership to comply with applicable  environmental
regulations   may,   in  certain  circumstances,  be  attributed   to   the
Partnership.  The Partnership does not believe that it will be required  to
incur  any  material  expenditures to comply  with  existing  environmental
requirements.

The  Resource  Conservation and Recovery Act ("RCRA"), and analogous  state
laws govern the handling and disposal of hazardous and solid wastes. Wastes
that  are  classified  as  hazardous under RCRA are  subject  to  stringent
handling,   recordkeeping,  disposal  and  reporting   requirements.   RCRA
specifically  excludes  from the definition of  hazardous  waste  "drilling
fluids,  produced waters, and other wastes associated with the exploration,
development, or production of crude oil, natural gas or geothermal energy."
However,  these  wastes may be regulated by the EPA or  state  agencies  as
solid  waste.  Moreover, many ordinary industrial  wastes,  such  as  paint
wastes,  waste solvents, laboratory wastes and waste compressor  oils,  are
regulated  as  hazardous wastes. Although the costs of  managing  hazardous
waste  may  be  significant, the Partnership does not expect to  experience
more burdensome costs than similarly situated companies

State  water  discharge regulations and federal waste discharge  permitting
requirements  adopted pursuant to the Federal Water Pollution  Control  Act
prohibit  or  are  expected  in the future to  prohibit  the  discharge  of
produced  water and sand and some other substances related to the  oil  and
gas  industry, into coastal waters.  Although the costs to comply with such
mandates under state or federal law may be significant, the entire industry
will  experience similar costs, and the Partnership does not  believe  that
these  costs will have a material adverse impact on its financial condition
and operations.

The   Partnership  maintains  insurance  against  "sudden  and  accidental"
occurrences, which may cover some, but not all, of the environmental  risks
described  above.  Most significantly, the insurance we maintain  will  not
cover  the  risks  described above which occur over a sustained  period  of
time.  Further, there can be no assurance that such insurance will continue
to  be  available  to cover all such costs or that such insurance  will  be
available at premium levels that justify its purchase.  The occurrence of a
significant  event not fully insured or indemnified against  could  have  a
material adverse effect on our financial condition and operations.

Limited   partners  should  be  aware  that  the  assessment  of  liability
associated with environmental liabilities is not always correlated  to  the
value of a particular project.  Accordingly, liability associated with  the
environment under local, state, or federal regulations, particularly  clean
ups  under CERCLA, can exceed the value of the Partnership's investment  in
the associated site.

Partnership Employees
The  Partnership has no employees; however the Managing General Partner and
CWEI  have  a  staff  of  geologists, engineers, accountants,  landmen  and
clerical  staff  who  engage in Partnership activities and  operations  and
perform  additional services for the Partnership as needed.   In  addition,
the Partnership engages independent consultants such as petroleum engineers
and geologists as needed.

Item 2.   Properties

As  of December 31, 2004, the Partnership possessed an interest in oil  and
gas  properties  located in Garvin, Leflore, McClain,  Noble  and  Seminole
Counties of Oklahoma; Brazos, Burleson, Fayette, Lee, Nolan, Pecos,  Upton,
Ward  and  Winkler Counties of Texas.  These properties consist of  various
interests in approximately 126 wells and units.

Reserves

The  following table sets forth certain information as of December 31, 2004
with  respect  to the Partnership's estimated proved oil and  gas  reserves
pursuant   to  SEC  guidelines,  present  value  of  proved  reserves   and
standardized measure of discounted future net cash flows.

                       Proved Developed      Proved      Total
                      -------------------    -------    -------
                      -------------------    -------      ----
                           ---------          ----
                      Produci    Nonprod     Undevel     Proved
                         ng       ucing       oped
                      -------    -------     -------    -------
                      -------    -------     -------      ----
                       -----       ----       ----
Oil (Bbls)            143,000     84,000      44,000      271,000
Gas (Mcf)             3,986,00    340,000     1,555,00    5,881,00
                      0                      0           0
Total (BOE)           807,000     141,000     303,000     1,251,00
                                                        0
Present   value    of $7,392,     $1,889,     $4,740,     $14,021
proved reserves       000        000         000         ,000
Standardized  measure
of discounted
   future  net   cash                                     $14,025
flows                                                   ,000

The  following table sets forth certain information as of December 31, 2004
regarding  the  Partnership's  proved oil  and  gas  reserves  for  certain
significant properties.

                  Proved Reserves                             Percen
                                                                t
              ------------------------             Present      of
              ------------------------                        Presen
                      --------                                  t
                                Total     Percen    Value     Value
                                 Oil       t of       of        of
               Oil      Gas     Equiva    Total     Proved    Proved
                                 lent      Oil
              (Bbls    (Mcf)    (BOE)     Equiva   Reserve    Reserv
                )                          lent       s         es
              -----    ------   ------    ------ -----------  ------
              -----    -----    ------    ------ -----------  ------
               ---               ---       ---                 ---

        Mobil 59,00    5,183,   923,00    73.8%    10,110,    72.1%
Amacker       0        000      0                  000
Tippet
  Enron Rhoda 162,0    498,00   245,00    19.6%    3,023,0    21.6%
Walker        00       0        0                  00
 Other        50,00    200,00   83,000    6.6%     888,000    6.3%
              0        0
              -----    ------   ------    ------   -------    ------
              -----    ------   ------    ------   -------    ------
              --                --        --                  ---
 Total        271,0    5,881,   1,251,    100.0%   $          100.0%
              00       000      000                14,021,
                                                   000
              =====    ======   ======    ======   =======    ======
              ==       =        ==        ==       =          ===

The estimates of proved reserves at December 31, 2004 and the present value
of  proved  reserves  were derived from a report prepared  by  Ryder  Scott
Company,  L.P.,  petroleum consultants.  These calculations  were  prepared
using standard geological and engineering methods generally accepted by the
petroleum  industry  and  in accordance with SEC financial  accounting  and
reporting  standards.  The estimated present value of proved reserves  does
not  give  effect  to indirect expenses such as general and  administrative
expenses,   debt   service  (if  any)  and  depletion,   depreciation   and
amortization.

In  accordance with applicable financial accounting and reporting standards
of  the  SEC,  the estimates of the Partnership's proved reserves  and  the
present  value of proved reserves set forth herein are made using  oil  and
gas  sales prices estimated to be in effect as of the date of such  reserve
estimates  and  are  held constant throughout the life of  the  properties.
Estimated  quantities  of  proved reserves  and  their  present  value  are
affected by changes in oil and gas prices.  The average prices utilized for
the  purposes  of  estimating the Partnership's  proved  reserves  and  the
present  value of proved reserves as of December 31, 2004 were  $42.02  per
Bbl of oil and natural gas liquids and $5.36 per Mcf of gas, as compared to
$31.26 per Bbl of oil and $5.31 per Mcf of gas as of December 31, 2003.

<PAGE>
The  reserve  information shown is estimated.  The accuracy of any  reserve
estimate is a function of the quality of available geological, geophysical,
engineering  and  economic  data,  the precision  of  the  engineering  and
geological interpretation and judgment.  The estimates of reserves,  future
cash  flows  and present value are based on various assumptions,  including
those  prescribed by the SEC, and are inherently imprecise.   Although  the
Partnership   believes  these  estimates  are  reasonable,  actual   future
production, cash flows, taxes, development expenditures, operating expenses
and  quantities  of  recoverable  oil and natural  gas  reserves  may  vary
substantially from these estimates.  Also, the use of a 10% discount factor
for  reporting purposes may not necessarily represent the most  appropriate
discount  factor,  given  actual interest rates  and  risks  to  which  our
business or the oil and natural gas industry in general are subject.

Unanticipated  depletion, if it occurs, will result in lower reserves  than
previously  estimated; thus an ultimately lower return for the Partnership.
Basic  changes in past reserve estimates occur annually.  As  new  data  is
gathered  during the subsequent year, the engineer must revise his  earlier
estimates.  A year of new information, which is pertinent to the estimation
of  future  recoverable volumes, is available during  the  subsequent  year
evaluation.   In applying industry standards and procedures, the  new  data
may cause the previous estimates to be revised.  This revision may increase
or  decrease the earlier estimated volumes.  Pertinent information gathered
during the year may include actual production and decline rates, production
from  offset  wells  drilled to the same geologic formation,  increased  or
decreased water production, workovers, and changes in lifting costs,  among
others.   Accordingly,  reserve  estimates are  often  different  from  the
quantities of oil and gas that are ultimately recovered.

Item 3.   Legal Proceedings

There are no material pending legal proceedings to which the Partnership is
a party.

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

No  matter  was submitted to a vote of security holders during  the  fourth
quarter of 2004 through the solicitation of proxies or otherwise.

<PAGE>

                                 Part II


Item 5.   Market   for  Registrant's  Common  Equity,  Related  Stockholder
          Matters and Issuer Purchases of Equity Securities

Market Information
Limited  partnership interests, or units, in the Partnership were initially
offered and sold for a price of $500.  Limited partner units are not traded
on  any  exchange  and there is no public or organized trading  market  for
them.

Number of Limited Partner Interest Holders
As  of December 31, 2004 there were 602 holders of limited partner units in
the Partnership.

Distributions
Pursuant  to Article IV, Section 4.01 of the Partnership's Certificate  and
Agreement  of  Limited Partnership "Net Cash Flow" is  distributed  to  the
partners  on  a quarterly basis.  "Net Cash Flow" is defined as  "the  cash
generated  by  the  Partnership's investments  in  producing  oil  and  gas
properties,  less  (i)  General and Administrative  Costs,  (ii)  Operating
Costs,  and  (iii) any reserves necessary to meet current  and  anticipated
needs  of  the  Partnership, as determined at the sole  discretion  of  the
Managing  General Partner."  During 2004, distributions were made  totaling
$1,125,041,  with $1,012,532 ($50.63 per unit) distributed to  the  limited
partners and $112,509 to the general partner.

Issuer Purchases of Equity Securities
After  completion of the Partnership's first full fiscal year of operations
and each year thereafter, the Managing General Partner has offered and will
continue  to  offer  to  purchase each limited partner's  interest  in  the
Partnership in accordance with the obligations set forth in the partnership
agreement. The pricing mechanism used to calculate the repurchase is  based
on tangible assets of the Partnership, plus the present value of the future
net  revenues  of proved oil and gas properties, minus liabilities  with  a
risk  factor  discount of up to one-third which may be implemented  at  the
sole  discretion  of the Managing General Partner.  However,  the  Managing
General  Partner's obligation to purchase limited partner units  under  the
partnership agreement is limited to an annual expenditure of an amount  not
in  excess  of 10% of the total limited partner units initially  subscribed
for   by   limited  partners.   The  following  table  sets  forth  certain
information  regarding  purchases  of  limited  partnership  units  by  the
Managing General Partner during the year of 2004.

                                                      Maximum
                                          Total     Number (or
                                          Number
                                         of Units   Approximat
                                                         e
                                        Purchased    Value) of
                                            as         Units
                                         Part of     that May
                                         Publicly     Yet Be
                Total                   Announced    Purchased
               Number
              of Units       Average     Plans or    Under the
                              Price                    Plans
   Period     Purchase      Paid Per     Programs       or
                  d           Unit                   Programs
------------- --------      --------    ----------  ----------
------------- --------      --------    ----------  ----------
     --           -            --          ---          ---
January 2004       -         $    -         -           (1)
February 2004      -              -         -           (1)
 March 2004        -              -         -           (1)
 April 2004        -              -         -           (1)
  May 2004         -              -         -           (1)
  June 2004        -              -         -           (1)
  July 2004        -              -         -           (1)
 August 2004       -              -         -           (1)
  September        -              -         -           (1)
    2004
October 2004  1,140.4         467.72        -           (1)
November 2004      -              -         -           (1)
December 2004      -              -         -           (1)
              --------        -------    -------
              -             ---
   TOTALS     1,140.4        $467.72        -
               =====         ======        ====
(1) Not determinable.

<PAGE>
Item 6.   Selected Financial Data

The  following  selected financial data for the years  ended  December  31,
2004,  2003,  2002,  2001 and 2000 should be read in conjunction  with  the
financial statements included in Item 8:

                                   Years ended December 31,
                        2004       2003       2002      2001       2000
                       ------     ------     ------    ------     ------
Revenues            $ 1,375,04    1,237,7   104,701    964,152    1,435,6
                      0           19                              64

Net  income (loss)
before
        cumulative
effects of
        accounting    1,082,16    904,659   (171,77    571,669    1,215,5
changes               8                     5)                    73

Net income            1,082,16    1,021,2   358,225    571,669    1,215,5
                      8           96                              73

Partners' share
 of net income:

General partners      108,217     102,130   35,822     57,167     121,557

Limited partners      973,951     919,166   322,403    514,502    1,094,0
                                                                  16

Limited partners'
 net income (loss)
per unit
 before cumulative     48.70      40.71     (7.73)     25.73      54.70
effect

Limited partners'
  net  income  per     48.70      45.96     16.12      25.73      54.70
unit

Limited partners'
              cash
distributions
 per unit              50.63      33.75     -          50.74      52.88

Total assets        $ 2,773,79    2,828,4   2,047,1    1,688,4    2,242,9
                      2           12        63         19         02



<PAGE>
Item 7.   Management's  Discussion and Analysis of Financial Condition  and
          Results of Operations

General
The  Partnership was formed to acquire non-operating interests in producing
oil  and  gas  properties, to produce and market crude oil and natural  gas
produced  from  such  properties and to distribute any  net  proceeds  from
operations  to  the  general  and  limited  partners.   Net  revenues  from
producing  oil  and  gas  properties are not reinvested  in  other  revenue
producing  assets except to the extent that producing facilities and  wells
are  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 and on 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  limited
partners has fluctuated over the past few years and is expected to  decline
in later years based on these factors.

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.

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 depletion, depreciation, and amortization
("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.

<PAGE>
Results of Operations

General Comparison of the Years Ended December 31, 2004 and 2003

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

                                                           Percenta
                                                              ge
                                 Year Ended December       Increase
                                         31,
                                   2004        2003        (Decreas
                                                              e)
                                  ------      ------       --------
                                                             ----
      Oil production in         19,991       21,800        (8%)
      barrels
      Gas production in mcf     245,548      275,100       (11%)
      Total (BOE)               60,916       67,650        (10%)
      Average price per       $   39.43       29.69        33%
      barrel of oil
      Average price per mcf   $    5.90        4.84        22%
      of gas
      Income from net         $ 1,372,323    1,227,589     12%
      profits interests
      Partnership             $ 1,125,041    750,091       50%
      distributions
      Limited partner         $ 1,012,532    675,082       50%
      distributions
      Per unit distribution   $   50.63       33.75        50%
      to limited partners

      Number of limited         20,000       20,000
      partner units

Income from net profits

The Partnership's income from net profits interests increased to $1,372,323
from   $1,227,589  for  the  years  ended  December  31,  2004  and   2003,
respectively,  an  increase of 12%.  The principal  factors  affecting  the
comparison of the years ended December 31, 2004 and 2003 are as follows:

The average price for a barrel of oil received by the Partnership increased
during  the  year  ended December 31, 2004 as compared to  the  year  ended
December 31, 2003 by 33%, or $9.74 per barrel, resulting in an increase  of
approximately  $194,700 in income from net profits  interests.   Oil  sales
represented  35% of total oil and gas sales during the year ended  December
31, 2004 as compared to 33% during the year ended December 31, 2003.

The  average price for an mcf of gas received by the Partnership  increased
during  the same period by 22%, or $1.06 per mcf, resulting in an  increase
of approximately $260,300 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 $455,000.
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>

Oil  production decreased approximately 1,809 barrels or 8% during the year
ended  December 31, 2004 as compared to the year ended December  31,  2003,
resulting in a decrease of approximately $53,700 in income from net profits
interests.

Gas  production decreased approximately 29,552 mcf or 11% during  the  same
period,  resulting in a decrease of approximately $143,000 in  income  from
net profits interests.

The  total decrease in income from net profits interests due to the  change
in  production is approximately $196,700.  The decrease in gas  volumes  is
from sharp production decline on a new well drilled in 2003.

Lease   operating  costs  and  production  taxes  were   15%   higher,   or
approximately  $111,500 more during the year ended  December  31,  2004  as
compared  to  the  year  ended December 31, 2003.  The  increase  in  lease
operating costs includes workovers on two wells, well repairs on two  wells
and  a  pumping unit for a well.  The increase in production taxes  is  the
result of taxes on higher revenue from higher oil and gas prices.

Costs and Expenses

Total  costs and expenses decreased to $292,872 from $333,060 for the years
ended  December 31, 2004 and 2003, respectively, a decrease  of  12%.   The
decrease  is  primarily  the  result of the  lower  accretion  expense  and
depletion expense.

Depletion  expense  decreased to $101,654 for the year ended  December  31,
2004 from $130,000 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 year ended December  31,  2004,
which  was  $1.67  applied to 60,916 BOE as compared to  $1.92  applied  to
67,650  BOE for the same period in 2003.  The lower depletion rate in  2004
is due to the increase in reserves from extensions and discoveries.

Accretion expense decreased to $26,642 for the year ended December 31, 2004
from  $39,008 for the same period in 2003.  This represents a  decrease  of
32%.   The decrease in accretion is from discontinuing accretion on several
wells that reached their projected end of life in 2004.


<PAGE>

Results of Operations

General Comparison of the Years Ended December 31, 2003 and 2002

The  following  table  provides certain information  regarding  performance
factors for the years ended December 31, 2003 and 2002:

                                                           Percenta
                                                              ge
                                 Year Ended December       Increase
                                         31,
                                   2003        2002        (Decreas
                                                              e)
                                  ------      ------       --------
                                                             ----
      Oil production in         21,800       26,000        (16%)
      barrels
      Gas production in mcf     275,100      235,000       17%
      Total (BOE)               67,650       65,167        4%
      Average price per       $   29.69       24.59        21%
      barrel of oil
      Average price per mcf   $    4.84        2.95        64%
      of gas
      Income from net         $ 1,227,589    103,085       1,091%
      profits interests
      Partnership             $ 750,091      -             100%
      distributions
      Limited partner         $ 675,082      -             100%
      distributions
      Per unit distribution   $   33.75      -             100%
      to limited partners

      Number of limited         20,000       20,000
      partner units

Income from net profits

The Partnership's income from net profits interests increased to $1,227,589
from $103,085 for the years ended December 31, 2003 and 2002, respectively,
an  increase of 1,091%.  The principal factors affecting the comparison  of
the years ended December 31, 2003 and 2002 are as follows:

The average price for a barrel of oil received by the Partnership increased
during  the  year  ended December 31, 2003 as compared to  the  year  ended
December 31, 2002 by 21%, or $5.10 per barrel, resulting in an increase  of
approximately  $111,200 in income from net profits  interests.   Oil  sales
represented  33% of total oil and gas sales during the year ended  December
31, 2003 as compared to 48% during the year ended December 31, 2002.

The  average price for an mcf of gas received by the Partnership  increased
during  the same period by 64%, or $1.89 per mcf, resulting in an  increase
of approximately $519,900 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 $631,100.
The  market price for oil and gas has been extremely volatile over the past
decade and management expects a certain amount of volatility to continue in
the foreseeable future.

<PAGE>

Oil production decreased approximately 4,200 barrels or 16% during the year
ended  December 31, 2003 as compared to the year ended December  31,  2002,
resulting  in  a  decrease of approximately $103,300  in  income  from  net
profits interests.

Gas  production increased approximately 40,100 mcf or 17% during  the  same
period,  resulting in an increase of approximately $118,300 in income  from
net profits interests.

The  net  total increase in income from net profits interests  due  to  the
change   in  production  is  approximately  $15,000.   The  primary  factor
contributing to the reduction in oil volumes was a correction  in  2003  of
oil  sales  volumes incorrectly recorded on a lease in 2001 and 2002.   The
increase in gas volumes is from two new wells drilled in 2003 through farm-
out arrangements.

Lease operating costs and production taxes were 39% lower, or approximately
$476,000  less during the year ended December 31, 2003 as compared  to  the
year  ended  December  31,  2002.   Two wells  had  significant  well  work
performed in 2002 resulting in high workovers and intangible drilling cost,
partially  offset by an increase in production taxes due to an increase  in
2003 oil prices.

Costs and Expenses

Total  costs and expenses increased to $333,060 from $276,476 for the years
ended  December 31, 2003 and 2002, respectively, an increase of  20%.   The
increase  is  primarily  the result of the addition of  accretion  expense,
higher  general  and  administrative costs, and an  increase  in  depletion
expense.

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  8%   or
approximately $12,600 during the year ended December 31, 2003  as  compared
to the year ended December 31, 2002.

Depletion  expense  increased to $130,000 for the year ended  December  31,
2003  from  $125,000  for  the same period in  2002.   This  represents  an
increase  of  4%.   The  contributing factor to the increase  in  depletion
expense  is  in  relation  to the BOE depletion rate  for  the  year  ended
December  31,  2003, which was $1.92 applied to 67,650 BOE as  compared  to
$1.92 applied to 65,167 BOE for the same period in 2002.

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 December 31, 2003,  the  asset
retirement  obligation was $513,400.  The increase in the asset  retirement
obligation from January 1, 2003 is due to accretion expense of $39,008 plus
additional  wells added for $422 offset by decrease of $25,857 due  to  the
sale  of  properties.   The  pro  forma  amount  of  the  asset  retirement
obligation  as  of December 31, 2002 was approximately $499,827.   The  pro
forma  amounts  of  the  asset retirement obligation  were  measured  using
information,  assumptions and interest rates as of  the  adoption  date  of
January 1, 2003.


<PAGE>


Revenue and Distribution Comparison
Partnership net income for the years ended December 31, 2004, 2003 and 2002
was   $1,082,168,  $1,021,296  and  $358,225,  respectively.    Partnership
distributions  for the years ended December 31, 2004, 2003  and  2002  were
$1,125,041,   $750,091  and  $0,  respectively.   These   differences   are
indicative  of the changes in oil and gas prices, production and properties
during 2004, 2003 and 2002.

The  sources  for  the 2004 distributions of $1,125,041 were  oil  and  gas
operations  of  approximately $1,019,300, with the balance  from  available
cash  on  hand  at the beginning of the period.  The sources for  the  2003
distributions  of  $750,091  were oil and gas operations  of  approximately
$970,200  and  the change in oil and gas properties of approximately  $300,
resulting  in  excess  cash for contingencies or subsequent  distributions.
There were no distributions for 2002.

Total distributions during the year ended December 31, 2004 were $1,125,041
of  which  $1,012,532  ($50.63 per unit) was  distributed  to  the  limited
partners  and $112,509 to the general partner.  Total distributions  during
the  year  ended December 31, 2003 were $750,091 of which $675,082  ($33.75
per  unit)  was  distributed to the limited partners  and  $75,009  to  the
general partner.  There were no distributions due to a decrease in revenues
as  a  result of a decline in production and gas prices for the year  ended
December 31, 2002.

Cumulative cash distributions of $19,328,986 have been made to the  general
and  limited  partners as of December 31, 2004.  As of December  31,  2004,
$17,411,761 or $870.59 per limited partner unit has been distributed to the
limited partners, representing 174% of contributed capital.

Liquidity and Capital Resources
The  primary source of cash is from operations, the receipt of income  from
net profits 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
$1,019,300   in  2004  compared  to  $970,200  in  2003  and  approximately
$(114,800) in 2002.

There  were  no cash flows provided by investing activities in 2004.   Cash
flows  provided by investing activities were approximately  $300  in  2003.
There were no cash flows provided by investing activities during 2002.

Cash  flows  (used in) provided by financing activities were  approximately
$(1,125,200) on 2004 compared to $(753,600) in 2003 and approximately  $500
in  2002.   The  only use in financing activities was the distributions  to
partners.

As  of  December  31, 2004, the Partnership had approximately  $471,600  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>
Recent Accounting Pronouncements
In  December 2004, the Financial Accounting Standards Board ("FASB") issued
Statement   of  Financial  Accounting  Standards  No.  153  "Exchanges   of
Nonmonetary  Assets,  an amendment of APB Opinion  No.  29"  ("SFAS  153").
SFAS  153  specifies  the criteria required to record a  nonmonetary  asset
exchange  using  carryover  basis.  SFAS 153 is effective  for  nonmonetary
asset  exchanges occurring after July 1, 2005.  The Partnership will  adopt
this statement in the third quarter of 2005, and it is not expected to have
a material effect on the financial statements when adopted.

In  September  2004,  the Securities and Exchange Commission  issued  Staff
Accounting Bulletin No. 106 ("SAB 106"). SAB 106 expresses the SEC  staff's
views  regarding SFAS No. 143 and its impact on both the full-cost  ceiling
test and the calculation of depletion expense.  In accordance with SAB 106,
beginning in the first quarter of 2005, undiscounted abandonment costs  for
wells  to  be  drilled in the future to develop proved reserves  should  be
included in the unamortized cost of oil and gas properties, net of  related
salvage  value,  for  purposes  of computing  depreciation,  depletion  and
amortization  ("DD&A").  The effect of including  undiscounted  abandonment
costs  of  future wells to the undiscounted cost of oil and gas  properties
may  increase  DD&A  expense in future periods,  however,  the  Partnership
currently  does  not  believe SAB 106 will have a material  impact  on  our
financial statements.

Item 7A.  Quantitative and Qualitative Disclosures About Market Risk

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


<PAGE>

Item 8.   Financial Statements and Supplementary Data

                      Index to Financial Statements

                                                                       Page

Report of Independent Registered Public Accounting Firm                 20

Balance Sheets                                                          21

Statements of Operations                                                22

Statement of Changes in Partners' Equity                                23

Statements of Cash Flows                                                24

Notes to Financial Statements                                           25

<PAGE>










                     REPORT OF INDEPENDENT REGISTERED
                          PUBLIC ACCOUNTING FIRM

The Partners
Southwest Royalties, Inc. Income Fund VI
(A Tennessee Limited Partnership)


We  have  audited  the accompanying balance sheets of Southwest  Royalties,
Inc.  Income Fund VI (the "Partnership") as of December 31, 2004 and  2003,
and  the related statements of operations, partners' equity, and cash flows
for  each  of the years in the three-year period ended December  31,  2004.
These  financial  statements are the responsibility  of  the  Partnership's
management.  Our responsibility is to express an opinion on these financial
statements based on our audits.

We  conducted  our audits in accordance with the standards  of  the  Public
Company  Accounting  Oversight  Board  (United  States).   Those  standards
require  that we plan and perform the audit to obtain reasonable  assurance
about  whether  the financial statements are free of material misstatement.
An  audit  includes  examining, on a test basis,  evidence  supporting  the
amounts  and  disclosures  in  the financial  statements.   An  audit  also
includes assessing the accounting principles used and significant estimates
made  by  management, as well as evaluating the overall financial statement
presentation.   We believe that our audits provide a reasonable  basis  for
our opinion.

In  our opinion, the financial statements referred to above present fairly,
in  all  material respects, the financial position of Southwest  Royalties,
Inc.  Income Fund VI as of December 31, 2004 and 2003, and the  results  of
its  operations and its cash flows for each of the years in the  three-year
period  ended December 31, 2004, in conformity with U.S. generally accepted
accounting principles.

As discussed in Note 4 to the financial statements, the Partnership changed
its method of computing depletion in 2002.  Also, as discussed in Note 3 to
the  financial statements, the Partnership changed its method of accounting
for asset retirement obligations as of January 1, 2003.






KPMG LLP
Dallas, Texas
March 26, 2005

<PAGE>


                 Southwest Royalties, Inc. Income Fund VI
                    (a Tennessee limited partnership)
                              Balance Sheets
                        December 31, 2004 and 2003


                                           2004      2003
                                          ------    ------
Assets
---------
Current assets:
 Cash and cash equivalents            $  128,990   234,954
  Receivable  from  Managing  General    342,286   189,477
Partner
 Oklahoma withholding prepayment         313       124
                                         --------  --------
                                         ------    ------
   Total current assets                  471,589   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            6,245,11  6,143,46
                                         4         0
                                         --------  --------
                                         ------    ------
   Net oil and gas properties            2,302,20  2,403,85
                                         3         7
                                         --------  --------
                                         ------    ------
                                      $  2,773,79  2,828,41
                                         2         2
                                         ========  ========
Liabilities and Partners' Equity
-------------------------------------
---

Asset retirement obligation           $  501,653   513,400
                                         --------  --------
                                         ------    ------
Partners' equity:
 General partner                         (627,121  (622,829
                                         )         )
 Limited partners                        2,899,26  2,937,84
                                         0         1
                                         --------  --------
                                         ------    ------
   Total partners' equity                2,272,13  2,315,01
                                         9         2
                                         --------  --------
                                         ------    ------
                                      $  2,773,79  2,828,41
                                         2         2
                                         ========  ========

















                  The accompanying notes are an integral
                   part of these financial statements.
<PAGE>
                 Southwest Royalties, Inc. Income Fund VI
                    (a Tennessee limited partnership)
                         Statements of Operations
               Years ended December 31, 2004, 2003 and 2002

                                     2004      2003      2002
                                    ------    ------    ------
Revenues
-------------
   Income   from  net   profits $  1,372,32  1,227,58  103,085
interests                          3         9
 Interest from operations          1,972     1,178     1,137
 Other                             745       8,952     479
                                   --------  --------  --------
                                   -----     -----     ---
                                   1,375,04  1,237,71  104,701
                                   0         9
                                   --------  --------  --------
                                   -----     -----     ---
Expenses
-------------
  Depreciation,  depletion  and    101,654   130,000   125,000
amortization
 Accretion expense                 26,642    39,008    -
 General and administrative        164,576   164,052   151,476
                                   --------  --------  --------
                                   -----     -----     ---
                                   292,872   333,060   276,476
                                   --------  --------  --------
                                   -----     -----     ---
Net    income   (loss)   before
cumulative effects
 of accounting changes             1,082,16  904,659   (171,775
                                   8                   )

Cumulative effect of change  in
accounting
 principle - SFAS No. 143 - See    -         116,637   -
Note 3
Cumulative effect of change  in
accounting principle
 - change in depletion method -    -         -         530,000
See Note 4
                                   --------  --------  --------
                                   -----     -----     ---
Net income                      $  1,082,16  1,021,29  358,225
                                   8         6
                                   =======   =======   ======
Net income allocated to:

 Managing General Partner       $  108,217   102,130   35,822
                                   =======   =======   ======
 Limited partners               $  973,951   919,166   322,403
                                   =======   =======   ======
    Per  limited  partner  unit $    48.70              (7.73)
before cumulative effect                     40.71
     Cumulative   effects   per          -              23.85
limited partner unit                         5.25
                                   --------  --------  --------
                                   -----     -----     ---
  Per limited partner unit      $    48.70              16.12
                                             45.96
                                   =======   =======   ======












                  The accompanying notes are an integral
                   part of these financial statements.
<PAGE>
                 Southwest Royalties, Inc. Income Fund VI
                    (a Tennessee limited partnership)
                 Statement of Changes in Partners' Equity
               Years ended December 31, 2004, 2003 and 2002


                           General   Limited
                           Partner   Partners   Total
                           --------  --------  --------
                             ---      -----
Balance   at  December  $  (685,772  2,371,35  1,685,58
31, 2001                   )         4         2

 Net income                35,822    322,403   358,225

 Distributions             -         -         -
                           --------  --------  --------
                           ------    ------    ------
Balance   at  December     (649,950  2,693,75  2,043,80
31, 2002                   )         7         7

 Net income                102,130   919,166   1,021,29
                                               6

 Distributions             (75,009)  (675,082  (750,091
                                     )         )
                           --------  --------  --------
                           ------    ------    ------
Balance   at  December     (622,829  2,937,84  2,315,01
31, 2003                   )         1         2

 Net income                108,217   973,951   1,082,16
                                               8

 Distributions             (112,509  (1,012,5  (1,125,0
                           )         32)       41)
                           --------  --------  --------
                           ------    ------    ------
Balance   at  December  $  (627,121  2,899,26  2,272,13
31, 2004                   )         0         9
                           ========  ========  ========



























                  The accompanying notes are an integral
                   part of these financial statements.
<PAGE>
                 Southwest Royalties, Inc. Income Fund VI
                    (a Tennessee limited partnership)
                         Statements of Cash Flows
               Years ended December 31, 2004, 2003 and 2002

                                      2004      2003      2002
                                     ------    ------    ------
Cash   flows   from   operating
activities:
 Cash received from net profits  $  1,179,26  1,121,73  34,721
interests                           0         5
  Cash  paid for administrative
fees and general
  and administrative overhead       (162,711  (161,661  (151,123
                                    )         )         )
 Interest received                  1,972     1,178     1,137
 Other                              745       8,952     479
                                    --------  --------  --------
                                    ------    ------    -----
   Net  cash provided by  (used     1,019,26  970,204   (114,786
in) operating activities            6                   )
                                    --------  --------  --------
                                    ------    ------    -----
Cash   provided  by   investing
activities:
 Sale of oil and gas properties     -         306       -
                                    --------  --------  --------
                                    ------    ------    -----
Cash  (used  in)  provided   by
financing activities:
 Distributions to partners          (1,125,2  (753,571  519
                                    30)       )
                                    --------  --------  --------
                                    ------    ------    -----
  Net  (decrease)  increase  in     (105,964  216,939   (114,267
cash and cash equivalents           )                   )

 Beginning of year                  234,954   18,015    132,282
                                    --------  --------  --------
                                    ------    ------    -----
 End of year                     $  128,990   234,954   18,015
                                    ========  ========  =======
Reconciliation of net income to
net
  cash  provided  by  operating
activities:
Net income                       $  1,082,16  1,021,29  358,225
                                    8         6

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

  Depreciation,  depletion  and     101,654   130,000   125,000
amortization
 Accretion expense                  26,642    39,008    -
 Cumulative effect of change in     -         (116,637  (530,000
accounting principle                          )         )
 Increase in receivables            (193,063  (105,854  (68,364)
                                    )         )
 Increase in payables               1,865     2,391     353
                                    --------  --------  --------
                                    ------    ------    -----
Net  cash provided by (used in)  $  1,019,26  970,204   (114,786
operating activities                6                   )
                                    ========  ========  =======
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-    $  -         422       -
out arrangements
                                    ========  ========  =======
 Decrease in oil and gas
properties - SFAS No. 143
  sale of property               $            (25,857)  -
                                    ========  ========  =======



                  The accompanying notes are an integral
                   part of these financial statements.
<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.,  a
    wholly owned subsidiary of Clayton Williams Energy, Inc., serves as the
    Managing  General Partner.  Revenues, costs and expenses are  allocated
    as follows:

                                                    Limite  General
                                                       d
                                                    Partne  Partner
                                                      rs       s
                                                    ------  -------
                                                     -----   -----
             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    90%     10%
             (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

    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 December 31, 2004, 2003  and  2002,
    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.

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

                      Notes to Financial Statements

2.  Summary of Significant Accounting Policies - continued

    Oil and Gas Properties - continued
   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 December 31, 2004,  there
   were  no  timing  differences, which resulted in a  deficit  net  profit
   interest.

    Estimates and Uncertainties
    The  preparation of financial statements in conformity  with  generally
    accepted  accounting principles requires management to  make  estimates
    and  assumptions  that  affect  the  reported  amounts  of  assets  and
    liabilities and disclosure of contingent assets and liabilities at  the
    date  of  the financial statements and the reported amounts of revenues
    and  expenses during the reporting period.  The Partnership's depletion
    calculation and full cost ceiling test for oil and gas properties  uses
    oil  and gas reserve estimates, which are inherently imprecise.  Actual
    results could differ from those estimates.

         Syndication Costs
          Syndication costs are accounted for as a reduction of partnership
    equity.

    Environmental Costs
    The  Partnership  is  subject to extensive  federal,  state  and  local
    environmental  laws and regulations.  These laws, which are  constantly
    changing, regulate the discharge of materials into the environment  and
    may  require  the  Partnership to remove or mitigate the  environmental
    effects  of the disposal or release of petroleum or chemical substances
    at   various   sites.   Environmental  expenditures  are  expensed   or
    capitalized  depending on their future economic benefit.  Costs,  which
    improve a property as compared with the condition of the property  when
    originally  constructed  or acquired and costs,  which  prevent  future
    environmental contamination are capitalized.  Expenditures that  relate
    to  an  existing condition caused by past operations and that  have  no
    future economic benefits are expensed.  Liabilities for expenditures of
    a  non-capital nature are recorded when environmental assessment and/or
    remediation is probable, and the costs can be reasonably estimated.

    Revenue Recognition
    We  recognize  oil  and gas sales when delivery to  the  purchaser  has
    occurred  and  title has transferred.  This occurs when production  has
    been delivered to a pipeline or transport vehicle.

    Gas Balancing
    The  Partnership  utilizes  the sales method  of  accounting  for  gas-
    balancing  arrangements.  Under this method the Partnership  recognizes
    sales  revenue on all gas sold.  As of December 31, 2004 and 2003,  the
    Partnership was under produced by 5,306 and 4,075 mcf of gas.

    Income Taxes
    No   provision  for  income  taxes  is  reflected  in  these  financial
    statements, since the tax effects of the Partnership's income  or  loss
    are passed through to the individual partners.

    In   accordance  with  the  requirements  of  Statement  of   Financial
    Accounting  Standards  No.  109,  "Accounting  for  Income  Taxes"  the
    Partnership's tax basis in its net oil and gas properties  at  December
    31, 2004 and 2003 is $1,932,696 and $1,996,474, respectively, less than
    that  shown  on  the  accompanying Balance Sheets  in  accordance  with
    generally accepted accounting principles.

<PAGE>

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

                      Notes to Financial Statements

2.  Summary of Significant Accounting Policies - continued

    Cash and Cash Equivalents
    For purposes of the statements of cash flows, the Partnership considers
    all  highly liquid debt instruments purchased with a maturity of  three
    months  or less to be cash equivalents.  The Partnership maintains  its
    cash at one financial institution.

    Number of Limited Partner Units
    As  of  December  31,  2004, 2003 and 2002, there were  20,000  limited
    partner units outstanding held by 602, 667 and 669 partners.

    Concentrations of Credit Risk
    The  Partnership  is subject to credit risk through trade  receivables.
    Although  a  substantial  portion of its debtors'  ability  to  pay  is
    dependent  upon the oil and gas industry, credit risk is minimized  due
    to a large customer base.  All partnership revenues are received by the
    Managing  General Partner and subsequently remitted to the  partnership
    and  all  expenses  are  paid  by  the  Managing  General  Partner  and
    subsequently reimbursed by the partnership.

    Fair Value of Financial Instruments
    The  carrying amount of cash and accounts receivable approximates  fair
    value due to the short maturity of these instruments.

    Net Income (loss) per limited partnership unit
    The  net  income (loss) per limited partnership unit is  calculated  by
    using the number of outstanding limited partnership units.

    Recent Accounting Pronouncements
    In  December  2004, the Financial Accounting Standards  Board  ("FASB")
    issued  Statement of Financial Accounting Standards No. 153  "Exchanges
    of   Nonmonetary   Assets,  an  amendment  of  APB  Opinion   No.   29"
    ("SFAS  153").  SFAS 153 specifies the criteria required  to  record  a
    nonmonetary  asset  exchange  using  carryover  basis.   SFAS  153   is
    effective for nonmonetary asset exchanges occurring after July 1, 2005.
    The Partnership will adopt this statement in the third quarter of 2005,
    and  it  is  not  expected to have a material effect on  the  financial
    statements when adopted.

    In  September 2004, the Securities and Exchange Commission issued Staff
    Accounting  Bulletin  No. 106 ("SAB 106"). SAB 106  expresses  the  SEC
    staff's  views regarding SFAS No. 143 and its impact on both the  full-
    cost  ceiling  test  and  the calculation  of  depletion  expense.   In
    accordance  with  SAB  106, beginning in the  first  quarter  of  2005,
    undiscounted abandonment costs for wells to be drilled in the future to
    develop  proved reserves should be included in the unamortized cost  of
    oil  and gas properties, net of related salvage value, for purposes  of
    computing depreciation, depletion and amortization ("DD&A"). The effect
    of  including  undiscounted abandonment costs of future  wells  to  the
    undiscounted  cost of oil and gas properties may increase DD&A  expense
    in  future periods, however, the Partnership currently does not believe
    SAB 106 will have a material impact on our financial statements.

   Depletion Policy
   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. (See Note 4)

<PAGE>

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

                      Notes to Financial Statements

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 December 31, 2004, the asset retirement obligation  was
    $501,653.  The decrease in the asset retirement obligation from January
    1, 2004 is due to a decrease of $38,389 for wells plugged and abandoned
    offset  by accretion expense of $26,642.  The pro forma amount  of  the
    asset  retirement obligation as of December 31, 2002 was  approximately
    $499,827.   The  pro  forma amounts of the asset retirement  obligation
    were  measured using information, assumptions and interest rates as  of
    the adoption date of January 1, 2003.

                                     2002
                                    ------
Pro   forma  amounts   assuming
change is applied
 retroactively:
  Net  income before cumulative
effect
    for   change  in  depletion $  (208,562
method                             )
                                    ======
    Per  limited  partner  unit $   (9.39)
(20,000.0 units)
                                    ======
 Net income                     $  321,438
                                    ======
    Per  limited  partner  unit $    14.46
(20,000.0 units)
                                    ======

4.   Cumulative  effect  of a change in accounting principle  -  change  in
depletion method
    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.  The Partnership adopted the units-of-production
    method  through  the recording of a cumulative effect of  a  change  in
    accounting principle in the amount of $530,000 effective as of  January
    1,  2002.  The Partnership's depletion for years subsequent to 2001 has
    been calculated using the units-of-production method.

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

                      Notes to Financial Statements

5.  Commitments and Contingent Liabilities
    After  completion  of  the  Partnership's first  full  fiscal  year  of
    operations  and each year thereafter, the Managing General Partner  has
    offered  and will continue to offer to purchase each limited  partner's
    interest  in the Partnership.  The pricing mechanism used to  calculate
    the repurchase is based on tangible assets of the Partnership, plus the
    present  value  of  the  future net revenues  of  proved  oil  and  gas
    properties, minus liabilities with a risk factor discount of up to one-
    third  which may be implemented at the sole discretion of the  Managing
    General Partner.  However, the Managing General Partner's obligation to
    purchase  limited partner units is limited to an annual expenditure  of
    an  amount  not  in  excess of 10% of the total limited  partner  units
    initially subscribed for by limited partners.

    The  Partnership  is  subject  to  various  federal,  state  and  local
    environmental  laws  and  regulations, which  establish  standards  and
    requirements for protection of the environment.  The Partnership cannot
    predict the future impact of such standards and requirements, which are
    subject  to  change  and  can  have  retroactive  effectiveness.    The
    Partnership  continues  to  monitor  the  status  of  these  laws   and
    regulations.

    As  of December 31, 2004, the Partnership has not been fined, cited  or
    notified of any environmental violations and management is not aware of
    any  unasserted violations, which would have a material adverse  effect
    upon capital expenditures, earnings or the competitive position in  the
    oil  and  gas  industry.  However, the Managing  General  Partner  does
    recognize by the very nature of its business, material costs  could  be
    incurred  in  the  near  term  to  bring  the  Partnership  into  total
    compliance.  The amount of such future expenditures is not determinable
    due  to  several factors, including the unknown magnitude  of  possible
    contaminations, the unknown timing and extent of the corrective actions
    which may be required, the determination of the Partnership's liability
    in proportion to other responsible parties and the extent to which such
    expenditures  are  recoverable from insurance or indemnifications  from
    prior owners of the Partnership's properties.

6.  Related Party Transactions
    A  significant  portion  of the oil and gas  properties  in  which  the
    Partnership  has  an  interest are operated by and purchased  from  the
    Managing  General Partner.  As provided for in the operating  agreement
    for  each respective oil and gas property in which the Partnership  has
    an interest, the operator is paid an amount for administrative overhead
    attributable  to  operating  such  properties,  with  such  amounts  to
    Southwest  Royalties, Inc. as operator approximating  $85,700,  $83,000
    and  $98,600,  for the years ended December 31, 2004,  2003  and  2002,
    respectively.  The amounts for administrative overhead attributable  to
    operating the partnerships properties has been deducted from gross  oil
    and  gas  revenues  in  the determination of net  profit  interest.  In
    addition,  the  Managing  General  Partner  and  certain  officers  and
    employees  may have an interest in some of the properties in which  the
    Partnership also participates.

    Southwest  Royalties,  Inc., the Managing  General  Partner,  was  paid
    $144,000  during  2004,  2003 and 2002, as an  administrative  fee  for
    indirect   general   and   administrative   overhead   expenses.    The
    administrative fees are included in general and administrative  expense
    on the statement of operations.

    Receivables  from  Southwest  Royalties,  Inc.,  the  Managing  General
    Partner,  of approximately $342,300 and $189,500 are from oil  and  gas
    production,  net of lease operating costs and production taxes,  as  of
    December 31, 2004 and 2003, respectively.


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

                      Notes to Financial Statements

7.  Oil and Gas Reserves Information (unaudited)

    The   estimates  of  proved  oil  and  gas  reserves  utilized  in  the
    preparation  of  the financial statements were prepared by  independent
    petroleum  engineers.  Such estimates are in accordance with guidelines
    established by the Securities and Exchange Commission and the Financial
    Accounting  Standards  Board, which require  that  reserve  reports  be
    prepared  under  economic  and operating  conditions  existing  at  the
    registrant's year end with no provision for price and cost  escalations
    except  by contractual arrangements.  Future cash inflows were computed
    by  applying  year-end  prices  to the year-end  quantities  of  proved
    reserves.   Future development, abandonment and production  costs  were
    computed  by  estimating the expenditures to be incurred in developing,
    producing, and abandoning proved oil and gas reserves at the end of the
    year,  based on year-end costs.  All of the Partnership's reserves  are
    located  in the United States.  For information about the Partnership's
    results  of operations from oil and gas producing activities,  see  the
    accompanying statements of operations.

    The  Partnership's  interest  in proved oil  and  gas  reserves  is  as
    follows:

                                Oil       Gas
                               (bbls)    (mcf)
                              --------  --------
                                ----     -----
Total Proved -

January  1, 2002              138,000   5,368,00
                                        0

      Revisions of  previous  86,000    (725,000
estimates                               )
     Production               (26,000)  (235,000
                                        )
                              --------  --------
                              ----      ------
December 31, 2002             198,000   4,408,00
                                        0

      Sales  of reserves  in  (3,000)   (13,000)
place
      Revisions of  previous  12,000    1,129,00
estimates                               0
     Production               (22,000)  (275,000
                                        )
                              --------  --------
                              ----      ------
December 31, 2003             185,000   5,249,00
                                        0

       New  discoveries  and  83,000    678,000
extensions
      Revisions of  previous  23,000    200,000
estimates
     Production               (20,000)  (246,000
                                        )
                              --------  --------
                              ----      ------
December 31, 2004             271,000   5,881,00
                                        0
                              =======   ========
Proved developed reserves -
December 31, 2002             161,000   4,067,00
                                        0
                              =======   ========
December 31, 2003             138,000   4,018,00
                                        0
                              =======   ========
December 31, 2004             227,000   4,326,00
                                        0
                              =======   ========


<PAGE>

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

                      Notes to Financial Statements

7.  Oil and Gas Reserves Information (unaudited) - continued

   Oil  price  adjustments  were  made in  the  individual  evaluations  to
   reflect  oil  quality, gathering and transportation costs.  The  results
   of  the  reserve report as of December 31, 2004, 2003 and  2002  are  an
   average price of $42.02, $31.26 and $29.47 per barrel.

    Gas  price  adjustments  were  made in the  individual  evaluations  to
    reflect  BTU  content,  gathering  and  transportation  costs  and  gas
    processing  and  shrinkage.  The results of the reserve  report  as  of
    December  31, 2004, 2003 and 2002 are an average price of $5.36,  $5.31
    and $4.36 per Mcf.

    The  evaluation of oil and gas properties is not an exact  science  and
    inevitably  involves a significant degree of uncertainty,  particularly
    with  respect to the quantity of oil or gas that any given property  is
    capable  of producing.  Estimates of oil and gas reserves are based  on
    available  geological and engineering data, the extent and  quality  of
    which may vary in each case and, in certain instances, may prove to  be
    inaccurate.  Consequently, properties may be depleted more rapidly than
    the geological and engineering data have indicated.

    Unanticipated  depletion, if it occurs, will result in  lower  reserves
    than  previously  estimated; thus an ultimately lower  return  for  the
    Partnership.   Basic changes in past reserve estimates occur  annually.
    As  new data is gathered during the subsequent year, the engineer  must
    revise  his  earlier  estimates.  A year of new information,  which  is
    pertinent to the estimation of future recoverable volumes, is available
    during  the subsequent year evaluation.  In applying industry standards
    and  procedures,  the new data may cause the previous estimates  to  be
    revised.   This revision may increase or decrease the earlier estimated
    volumes.

    The  Partnership has reserves, which are classified as proved developed
    and proved undeveloped.  All of the proved reserves are included in the
    engineering reports, which evaluate the Partnership's present reserves.

    Because  the  Partnership does not engage in drilling  activities,  the
    development  of  proved undeveloped reserves is conducted  pursuant  to
    farm-out  arrangements with the Managing General Partner  or  unrelated
    third  parties.  Generally, the Partnership retains a carried  interest
    such as an overriding royalty interest under the terms of a farm-out.

<PAGE>

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

                      Notes to Financial Statements

7.  Oil and Gas Reserves Information (unaudited) - continued
    The  standardized measure of discounted future net cash flows  relating
    to  proved oil and gas reserves at December 31, 2004, 2003 and 2002  is
    presented below:

                            2004      2003      2002
                           ------    ------    ------
Future cash inflows    $  42,902,0  33,658,0  25,032,0
                          00        00        00
Production,
development
    and   abandonment     12,108,0  8,608,00  7,063,00
costs                     00        0         0
                          --------  --------  --------
                          ------    ------    ------
Future net cash flows     30,794,0  25,050,0  17,969,0
                          00        00        00
10%  annual  discount
for
  estimated timing of     16,769,0  13,629,0  9,795,00
cash flows                00        00        0
                          --------  --------  --------
                          -----     ------    ------
Standardized  measure
of
   discounted  future
net cash
 flows                 $  14,025,0  11,421,0  8,174,00
                          00        00        0
                          ========  ========  ========

     Changes  in  the  standardized measure of discounted future  net  cash
     flows  relating  to proved reserves for the years ended  December  31,
     2004, 2003 and 2002 are as follows:

                            2004      2003      2002
                            ----      ----      ----
Sales of oil and  gas
produced,
  net  of  production  $  (1,372,0  (1,228,0  (103,000
costs                     00)       00)       )
Extensions        and     2,799,00  -         -
discoveries               0
Changes in prices and
production
 costs                    185,000   1,679,00  4,041,00
                                    0         0
Changes  in estimated
future
 development cost         -         -         23,000
Changes of production
rates
 (timing) and others      (766,000  (151,000  (466,000
                          )         )         )
Sales of minerals  in     -         (18,000)  -
place
Revisions of previous
 quantities estimates     616,000   2,148,00  (305,000
                                    0         )
Accretion of discount     1,142,00  817,000   453,000
                          0
Discounted future net
cash flows -
 Beginning of year        11,421,0  8,174,00  4,531,00
                          00        0         0
                          --------  --------  --------
                          ------    ------    ----
 End of year           $  14,025,0  11,421,0  8,174,00
                          00        00        0
                          ========  ========  =======



<PAGE>

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

                      Notes to Financial Statements

8.   Selected Quarterly Financial Results - (unaudited)

                                             Quarter
                              --------------------------------------
                              --------------------------------------
                                                -
                               First     Second    Third     Fourth
                               ------   --------  -------   --------
                                          ---                  -
2004:
 Total revenues             $ 381,937   315,017   289,185   388,901
 Total expenses               77,552    82,870    76,278    56,172
                              --------  --------  --------  --------
                              ----      ----      ----      ----
 Net income                   304,385   232,147   212,907   332,729
                              =======   =======   =======   =======

  Net  income per  limited  $  13.70
partner unit                            10.45     9.58      14.97
                              =======   =======   =======   =======

                                             Quarter
                              --------------------------------------
                              --------------------------------------
                                                -
                               First     Second    Third     Fourth
                               ------   --------  -------   --------
                                          ---                  -
2003:
 Total revenues             $ 297,298   331,781   292,700   315,940
 Total expenses               75,474    97,421    87,119    73,046
  Net income (loss) before
cumulative effect
     of   a   change    in    221,824   234,360   205,581   242,894
accounting principle
 Cumulative effect of SFAS    116,637   -         -         -
No. 143
                              --------  --------  --------  --------
                              ----      ----      ----      ----
 Net income (loss)          $ 338,461   234,360   205,581   242,894
                              =======   =======   =======   =======
  Per limited partner unit
amounts:
  Net income (loss) before
cumulative effect
     of   a   change    in  $   9.98
accounting principle                    10.55     9.25      10.93
 Cumulative effect of SFAS      5.25         -         -         -
No. 143
                              --------  --------  --------  --------
                              ----      ----      ----      ----
  Net  income  (loss)  per  $  15.23
limited partner unit                    10.55     9.25      10.93
                              =======   =======   =======   =======

<PAGE>

Item 9.                                  Changes in and Disagreements  With
          Accountants on Accounting and Financial Disclosure

None

Item 9A.  Controls and Procedures

The  Managing  General  Partner  has established  disclosure  controls  and
procedures   that  are  adequate  to  provide  reasonable  assurance   that
management will be able to collect, process and disclose both financial and
non-financial information, on a timely basis, in the Partnership's  reports
to  the  SEC.   Disclosure controls and procedures  include  all  processes
necessary  to  ensure  that material information  is  recorded,  processed,
summarized  and  reported within the time periods specified  in  the  SEC's
rules  and  forms,  and  is  accumulated and  communicated  to  management,
including our chief executive and chief financial officers, to allow timely
decisions regarding required disclosures.

     With respect to these disclosure controls and procedures:

          management  has  evaluated the effectiveness  of  the  disclosure
          controls  and procedures as of the end of the period  covered  by
          this report;

          this evaluation was conducted under the supervision and with  the
          participation  of management, including the chief  executive  and
          chief financial officers of the Managing General Partner; and

          it  is  the  conclusion of chief executive  and  chief  financial
          officers  of  the Managing General Partner that these  disclosure
          controls   and   procedures  are  effective  in   ensuring   that
          information  that is required to be disclosed by the  Partnership
          in   reports  filed  or  submitted  with  the  SEC  is  recorded,
          processed,  summarized  and  reported  within  the  time  periods
          specified in the rules and forms established by the SEC.

Internal Control Over Financial Reporting
There  has  not been any change in the Partnership's internal control  over
financial  reporting that occurred during the quarter  ended  December  31,
2004  that  has materially affected, or is reasonably likely to  materially
affect, its internal control over financial reporting.

Item 9B.  Other Information

None.

<PAGE>

                                 Part III

Item 10.  Directors and Executive Officers of the Registrant

Management of the Partnership is provided by Southwest Royalties, Inc.,  as
Managing  General Partner.  Since the Managing General Partner is a  wholly
owned subsidiary of CWEI, the directors of the Managing General Partner are
elected  by management of CWEI.  Each director the Managing General Partner
serves for a term of one year.  Following is certain information concerning
each  of  the  directors  and executive officers of  the  Managing  General
Partner.

CLAYTON W. WILLIAMS, age 73, is Chairman of the Board and a director of the
Managing  General Partner, having served in this capacity since  May  2004.
Mr.  Williams  also  serves  as  Chairman of the  Board,  President,  Chief
Executive Officer and a director of CWEI.

L.  PAUL  LATHAM,  age  53,  is President, Chief Executive  Officer  and  a
director  of  the Managing General Partner, having served in this  capacity
since  May 2004.  Mr. Latham also serves as Executive Vice President, Chief
Operating Officer and a director of CWEI.

MEL G. RIGGS, age 50, is Vice President, Chief Financial Officer, Treasurer
and  a  director  of the Managing General Partner, having  served  in  this
capacity  since  May 2004.  Mr. Riggs also serves as Senior Vice  President
and Chief Financial Officer of CWEI.

JERRY  F. GRONER, age 42, is Vice President - Land and Lease Administration
of  the Managing General Partner, having served in this capacity since  May
2004.   Mr.  Groner  also  serves  as  Vice  President  -  Land  and  Lease
Administration of CWEI.

D.  GREGORY BENTON, age 43, is Vice President - Engineering of the Managing
General Partner, having served in this capacity since May 2004.  Mr. Benton
also serves as Exploitation Manager of CWEI.

ROBERT C. LYON, age 68, is Vice President - Gas Gathering and Marketing  of
the  Managing  General Partner, having served in this  capacity  since  May
2004.  Mr. Lyon also serves as Vice President - Gas Gathering and Marketing
of CWEI.

T.  MARK  TISDALE, age 48, is Vice President and Secretary of the  Managing
General  Partner,  having  served in this capacity  since  May  2004.   Mr.
Tisdale also serves as Vice President and General Counsel of CWEI.

There  are no family relationships among the directors and officers of  the
Managing  General Partner except that Mr. Groner is the son-in-law  of  Mr.
Williams.

Code of Ethics

As  a  wholly  owned  subsidiary of CWEI, the Managing General  Partner  is
subject  to  a  Code  of Conduct and Ethics ("Code") that  applies  to  all
directors,  executive  officers and employees  of  CWEI  and  the  Managing
General Partner.  This Code assists employees in complying with the law, in
resolving  ethical  issues that may arise, and in complying  with  policies
established  by CWEI.  This Code is also designed to promote,  among  other
things, ethical handling of actual or apparent conflicts of interest; full,
fair,  accurate  and timely disclosure in filings with the SEC;  compliance
with  law;  and prompt internal reporting of violations of the Code.   This
Code  is available on the website of CWEI at www.claytonwilliams.com  under
"Investor Relations/Documents".

Item 11.  Executive Compensation

The  Partnership  does  not  employ any directors,  executive  officers  or
employees.  The Managing General Partner receives an administrative fee for
the  management of the Partnership.  The Managing General Partner  received
$144,000  during 2004, 2003 and 2002 as an annual administrative fee.   The
executive officers of the Managing General Partner do not receive any  form
of  compensation, from the Partnership; instead, their compensation is paid
solely  by  Southwest.  The executive officers, however,  may  occasionally
perform administrative duties for the Partnership but receive no additional
compensation for this work.

Item 12.  Security Ownership of Certain Beneficial Owners and Management

There  are  no  limited partners who own of record, or  are  known  by  the
Managing General Partner to beneficially own, more than five percent of the
Partnership's  limited  partnership  interests,  other  than  the  Managing
General Partner.

Through  repurchase  offers to the limited partners, the  Managing  General
Partner  owns  8,271.9  limited  partner units,  a  37.2%  limited  partner
interest.   The  Managing  General  Partner's  total  percentage   interest
ownership in the Partnership is 47.2%.

No  officer or director of the Managing General Partner directly owns units
in  the  Partnership. CWEI is considered to be a beneficial  owner  of  the
limited partner units acquired by the Managing General Partner by virtue of
its  ownership  of  the Managing General Partner. Beneficial  ownership  is
determined  in  accordance with the rules of the  Securities  and  Exchange
Commission  and  includes voting or investment power with  respect  to  the
limited partner units.

Item 13.  Certain Relationships and Related Transactions

In   2004,   the   Managing  General  Partner  received  $144,000   as   an
administrative  fee.  This amount is part of the general and administrative
expenses incurred by the Partnership.

In  some instances, the Managing General Partner and its affiliates may  be
working interest owners in an oil and gas property in which the Partnership
also  has  a  net  profits  interest.   Certain  properties  in  which  the
Partnership  has an interest are operated by the Managing General  Partner,
who was paid approximately $85,700 for administrative overhead attributable
to operating such properties during 2004.

The  terms of the above transactions are similar to ones, which would  have
been  obtained  through arm's length negotiations with  unaffiliated  third
parties.

Item 14.  Principal Accounting Fees and Services

The  following table presents fees for professional audit services rendered
by  KPMG LLP for the audit of the Partnership's annual financial statements
for  the  years ended December 31, 2004 and 2003 and fees billed for  other
services rendered by KPMG during those periods.

For  the  Year Ended December    2004      2003
31,
                                ------    ------
Audit Fees                     $12,865   $
                                         8,565
Audit Related Fees                  -         -
Tax Fees                            -
                                         -
All Other Fees                      -
                                         -
                                 ------    ------
                               ---       --
    TOTAL                      $12,865   $
                                         8,565
                                =====
                                         =====

The  Audit  Committee of CWEI reviewed and approved, in advance, all  audit
and non-audit services provided by KPMG LLP.

<PAGE>
                                 Part IV


Item 15. Exhibits and Financial Statement Schedules

          (a)(1)  Financial Statements:

                  Included in Part II of this report --

                  Report of Independent Registered Public Accounting Firm
                  Balance Sheets
                  Statements of Operations
                  Statement of Changes in Partners' Equity
                  Statements of Cash Flows
                  Notes to Financial Statements

                     (2)  Schedules required by Article 12 of Regulation S-
                  X  are either omitted because they are not applicable  or
                  because  the  required  information  is  shown   in   the
                  financial statements or the notes thereto.

                    (3)  Exhibits:

                                       4      (a)         Certificate   and
                          Agreement  of  Limited Partnership  of  Southwest
                          Royalties, Inc. Income Fund VI, dated December 4,
                          1986.     (Incorporated   by    reference    from
                          Partnership's Form 10-K for the fiscal year ended
                          December 31, 1986.)

                                           (b)        First  Amendment   to
                          Certificate  and Agreement of Limited Partnership
                          of  Southwest  Royalties, Inc.  Income  Fund  VI,
                          dated   January   16,1987.    (Incorporated    by
                          reference  from Partnership's Form 10-K  for  the
                          fiscal year ended December 31, 1987.)

                                            (c)          Corrected   Second
                          Amendment to Certificate and Agreement of Limited
                          Partnership  of Southwest Royalties, Inc.  Income
                          Fund  VI,  dated  May 6, 1987.  (Incorporated  by
                          reference  from Partnership's Form 10-K  for  the
                          fiscal year ended December 31, 1987.)

                                           (d)        Third  Amendment   to
                          Certificate  and Agreement of Limited Partnership
                          of  Southwest  Royalties, Inc.  Income  Fund  VI,
                          dated February 3, 1988 (Incorporated by reference
                          from  Partnership's Form 10-K for the fiscal year
                          ended December 31, 1988.)

                                           (e)        Fourth  Amendment  to
                          Certificate  and Agreement of Limited Partnership
                          of  Southwest  Royalties, Inc.  Income  Fund  VI,
                          dated  June  30, 1988 (Incorporated by  reference
                          from  Partnership's Form 10-K for the fiscal year
                          ended December 31, 1988.)

                                           (f)        Fifth  Amendment   to
                          Certificate  and Agreement of Limited Partnership
                          of  Southwest  Royalties, Inc.  Income  Fund  VI,
                          dated   December   30,  1988   (Incorporated   by
                          reference  from the Partnership's Form  10-K  for
                          the fiscal year ended December 31, 1988.)

                                           (g)        Sixth  Amendment   to
                          Certificate  and Agreement of Limited Partnership
                          of  Southwest  Royalties, Inc.  Income  Fund  VI,
                          dated  as  of  March 19, 1990.  (Incorporated  by
                          reference  from the Partnership's Form  10-K  for
                          the fiscal year ended December 31, 1990.)

                                          (h)        Seventh  Amendment  to
                          Certificate  and Agreement of Limited Partnership
                          of  Southwest  Royalties, Inc.  Income  Fund  VI,
                          dated as of December 31, 1990.  (Incorporated  by
                          reference  from the Partnership's Form  10-K  for
                          the fiscal year ended December 31, 1990.)
<PAGE>
                                           (i)        Eighth  Amendment  to
                          Certificate  and Agreement of Limited Partnership
                          of  Southwest  Royalties, Inc.  Income  Fund  VI,
                          dated as of September 30, 1991.  (Incorporated by
                          reference  from the Partnership's Form  10-K  for
                          the fiscal year ended December 31, 1991.)

                                           (j)        Ninth  Amendment   to
                          Certificate  and Agreement of Limited Partnership
                          of  Southwest  Royalties, Inc.  Income  Fund  VI,
                          dated as of December 31, 1991.  (Incorporated  by
                          reference  from the Partnership's Form  10-K  for
                          the fiscal year ended December 31, 1992.)

                                           (k)        Tenth  Amendment   to
                          Certificate  and Agreement of Limited Partnership
                          of  Southwest  Royalties, Inc.  Income  Fund  VI,
                          dated  as  of  March 31, 1992.  (Incorporated  by
                          reference  from the Partnership's Form  10-K  for
                          the fiscal year ended December 31, 1992.)

                                          (l)        Eleventh Amendment  to
                          Certificate  and Agreement of Limited Partnership
                          of  Southwest  Royalties, Inc.  Income  Fund  VI,
                          dated  as  of  June  30, 1992.  (Incorporated  by
                          reference  from the Partnership's Form  10-K  for
                          the fiscal year ended December 31, 1992.)

                                          (m)        Twelfth  Amendment  to
                          Certificate  and Agreement of Limited Partnership
                          of  Southwest  Royalties, Inc.  Income  Fund  VI,
                          dated as of November 23, 1992.  (Incorporated  by
                          reference  from the Partnership's Form  10-K  for
                          the fiscal year ended December 31, 1992.)

                                          (n)       Thirteenth Amendment to
                          Certificate  and Agreement of Limited Partnership
                          of  Southwest  Royalties, Inc.  Income  Fund  VI,
                          dated  as  of  April 22, 1993.  (Incorporated  by
                          reference  from the Partnership's Form  10-K  for
                          the fiscal year ended December 31, 1993.)

                                          (o)       Fourteenth Amendment to
                          Certificate  and Agreement of Limited Partnership
                          of  Southwest  Royalties, Inc.  Income  Fund  VI,
                          dated as of September 30, 1993.  (Incorporated by
                          reference  from the Partnership's Form  10-K  for
                          the fiscal year ended December 31, 1993.)

                                          (p)       Fifteenth Amendment  to
                          Certificate  and Agreement of Limited Partnership
                          of  Southwest  Royalties, Inc.  Income  Fund  VI,
                          dated as of December 31, 1993.  (Incorporated  by
                          reference  from the Partnership's Form  10-K  for
                          the fiscal year ended December 31, 1993.)

                                          (q)       Sixteenth Amendment  to
                          Certificate  and Agreement of Limited Partnership
                          of  Southwest  Royalties, Inc.  Income  Fund  VI,
                          dated  as  of  July  26, 1994.  (Incorporated  by
                          reference  from the Partnership's Form  10-K  for
                          the fiscal year ended December 31, 1994.)

                                         (r)       Seventeenth Amendment to
                          Certificate  and Agreement of Limited Partnership
                          of  Southwest  Royalties, Inc.  Income  Fund  VI,
                          dated  as of January 18, 1995.  (Incorporated  by
                          reference  from the Partnership's Form  10-K  for
                          the fiscal year ended December 31, 1994.)

                                          (s)       Eighteenth Amendment to
                          Certificate  and Agreement of Limited Partnership
                          of  Southwest  Royalties, Inc.  Income  Fund  VI,
                          dated as of July 26, 1995.

                                          (t)       Nineteenth Amendment to
                          Certificate  and Agreement of Limited Partnership
                          of  Southwest  Royalties, Inc.  Income  Fund  VI,
                          dated as of January 29, 1996.

                                          (u)       Twentieth Amendment  to
                          Certificate  and Agreement of Limited Partnership
                          of  Southwest  Royalties, Inc.  Income  Fund  VI,
                          dated as of April 30, 1996.

                                          (v)        Twenty First Amendment
                          to   Certificate   and   Agreement   of   Limited
                          Partnership  of Southwest Royalties, Inc.  Income
                          Fund VI, dated as of September 30, 1996.

<PAGE>

                                          (w)       Twenty Second Amendment
                          to   Certificate   and   Agreement   of   Limited
                          Partnership  of Southwest Royalties, Inc.  Income
                          Fund VI, dated as of January 15, 1997.

                                          (x)        Twenty Third Amendment
                          to   Certificate   and   Agreement   of   Limited
                          Partnership of Southwest Royalties, Inc.   Income
                          Fund VI, dated as of May 10, 1997.

                          (y)   Twenty Fourth Amendment to Certificate  and
                          Agreement  of  Limited Partnership  of  Southwest
                          Royalties,  Inc.  Income Fund  VI,  dated  as  of
                          January 30, 1998.

                          (z)   Twenty  Fifth Amendment to Certificate  and
                          Agreement of
                          Limited Partnership of Southwest Royalties,  Inc.
                          Income Fund VI, dated as of July 27, 1998.

                                          (aa)  Twenty  Sixth Amendment  to
                          Certificate  and Agreement of Limited Partnership
                          of  Southwest  Royalties, Inc.  Income  Fund  VI,
                          dated as of December 22, 1998.

                                          (bb) Twenty Seventh Amendment  to
                          Certificate  and Agreement of Limited Partnership
                          of  Southwest  Royalties, Inc.  Income  Fund  VI,
                          dated as of February 25, 1999.

                                          (cc)  Twenty Eighth Amendment  to
                          Certificate  and Agreement of Limited Partnership
                          of  Southwest  Royalties, Inc.  Income  Fund  VI,
                          dated as of July 27, 1999.

                                          (dd)  Twenty  Ninth Amendment  to
                          Certificate  and Agreement of Limited Partnership
                          of  Southwest  Royalties, Inc.  Income  Fund  VI,
                          dated as of February 10, 2000.

                                           (ee)   Thirtieth  Amendment   to
                          Certificate  and Agreement of Limited Partnership
                          of  Southwest  Royalties, Inc.  Income  Fund  VI,
                          dated as of April 26, 2000.

                                          (ff)       Thirty First Amendment
                          to   Certificate   and   Agreement   of   Limited
                          Partnership  of Southwest Royalties, Inc.  Income
                          Fund VI, dated as of September 13, 2000.

                                          (gg)  Thirty Second Amendment  to
                          Certificate  and Agreement of Limited Partnership
                          of  Southwest  Royalties, Inc.  Income  Fund  VI,
                          dated as of February 20, 2001.

                                          (hh)  Thirty  Third Amendment  to
                          Certificate  and Agreement of Limited Partnership
                          of  Southwest  Royalties, Inc.  Income  Fund  VI,
                          dated as of July 16, 2001.

<PAGE>

                                               (ii) Thirty Fourth Amendment
                          to   Certificate   and   Agreement   of   Limited
                          Partnership  of Southwest Royalties, Inc.  Income
                          Fund VI, dated as of January 11, 2002.

                                               (jj)  Thirty Fifth Amendment
                          to   Certificate   and   Agreement   of   Limited
                          Partnership  of Southwest Royalties, Inc.  Income
                          Fund VI, dated as of June 3, 2002.

                                               (kk)  Thirty Sixth Amendment
                          to   Certificate   and   Agreement   of   Limited
                          Partnership  of Southwest Royalties, Inc.  Income
                          Fund VI, dated as of July 30, 2002.

                                              (ll) Thirty Seventh Amendment
                          to   Certificate   and   Agreement   of   Limited
                          Partnership  of Southwest Royalties, Inc.  Income
                          Fund VI, dated as of February 20, 2003.

                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  and
Chief Financial Officer
                           Pursuant  to 18 U.S.C. Section 1350, as  adopted
                    Pursuant to Section
                          906 of the Sarbanes-Oxley Act of 2002
<PAGE>
                                Signatures


Pursuant  to  the  requirements of Section 13 or 15(d)  of  the  Securities
Exchange  Act  of 1934, the Partnership 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/ L. Paul Latham
                                 L. Paul Latham
                                 President and Chief Executive Officer

                          Date:  March 31, 2005


In  accordance with the Exchange Act, this report has been signed below  by
the following persons on behalf of the Registrant and in the capacities and
on the dates indicated.


/s/ Clayton W Williams                       /s/ L. Paul Latham
Clayton     W.    Williams,                  L.      Paul     Latham,
Chairman of the Board                        President and a Director
and a Director

Date:     March 31, 2005                     Date:     March 31, 2005




/s/ Mel G. Riggs
Mel    G.    Riggs,    Vice
President - Finance,
Treasurer and a Director

Date:     March 31, 2005



<PAGE>
                    SECTION 302 CERTIFICATION                Exhibit 31.1


I, L. Paul Latham, certify that:

1.        I  have  reviewed this annual report on Form  10-K  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:  March 31, 2005              /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

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                    SECTION 302 CERTIFICATION                Exhibit 31.2


I, Mel G. Riggs, certify that:

1.        I  have  reviewed this annual report on Form  10-K  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:  March 31, 2005              /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

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                                                               Exhibit 32.1

               CERTIFICATION OF CHIEF EXECUTIVE OFFICER AND
                          CHIEF FINANCIAL OFFICER

Pursuant to 18 U.S.C.  1350 and in connection with the accompanying  report
on  Form  10-K for the period ended December 31, 2004 that is  being  filed
concurrently with the Securities and Exchange Commission on the date hereof
(the  "Report"),  each of the undersigned officers of Southwest  Royalties,
Inc. Income Fund VI (the "Company"), hereby certifies 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.


                                   /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

                                   March 31, 2005


                                   /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

                                   March 31, 2005

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