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, 2005

                                    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 if the registrant is a well-known seasoned  issuer,
as defined in Rule 405 of the Securities Act.       Yes     No  X

Indicate  by  check mark if the registrant is not required to file  reports
pursuant to Section 13 or Section 15(d) of the Act.   Yes     No  X

Indicate  by  check mark whether the registrant (1) has filed  all  reports
required to be filed by Section 13 or 15(d) of the Securities Exchange  Act
of 1934 during the preceding 12 months (or for such shorter period that the
registrant was required to file such reports), and (2) has been subject  to
such filing requirements for the past 90 days.     Yes X  No

Indicate by check mark 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 a large accelerated filer,
an  accelerated  filer,  or  a non-accelerated filer.   See  definition  of
"accelerated  filer  and large accelerated filer"  in  Rule  12b-2  of  the
Exchange Act.

 Large  accelerated filer [   ]      Accelerated  filer   [    ]       Non-
 accelerated filer  [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

1B.  Unresolved Staff Comments                                           8

 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         15

 8.  Financial Statements and Supplementary Data                        16

 9.  Changes in and Disagreements with Accountants
     on Accounting and Financial Disclosure                             31

9A.  Controls and Procedures                                            31

9B.  Other Information                                                  31

                                 Part III

10.  Directors and Executive Officers of the Registrant                 32

11.  Executive Compensation                                             32

12.  Security Ownership of Certain Beneficial Owners and Management     33

13.  Certain Relationships and Related Transactions                     33

14.  Principal Accountant Fees and Services                             33

                                 Part IV

15.  Exhibits and Financial Statement Schedules                         34

     Signatures                                                         38

<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.

     Standardized  measure  of discounted future net  cash  flows.  Present
value  of  proved reserves, as adjusted to give effect to estimated  future
abandonment costs, net of the estimated salvage value of related equipment.

<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.

During  2005,  the  Partnership entered into farmout  agreements  with  the
Managing General Partner through which the Managing General Partner drilled
seven  wells  and performed workovers on three wells. The partnership  paid
none  of the cost to drill and complete or workover these wells. The  wells
involved and interest retained are as follows:

Drill   Barnett          10%
        Amacker #4
Drill   JS Lane #6       10%
Drill   Middleton 124    12.5
        C #9             %
Drill   Elizabeth        10%
        Windham #6
Drill   RS Windham #4    10%
Drill   RS Windham B     10%
        #2
Drill   RS Windham B     10%
        #3
Workov  Mary Shirk #1    30%
er
Workov  Mary Shirk #2    20%
er
Workov  RS Windham #1    10%
er


<PAGE>
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 2005, 38% of the Partnership's revenues were derived  from
the  sale of oil production and 62% 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.

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.

<PAGE>
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 2006.  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.

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 1B.  Unresolved Staff Comments

     Not applicable.

Item 2.   Properties

As  of December 31, 2005, the Partnership possessed an interest in oil  and
gas  properties located in Garvin, Leflore, McClain and Noble  Counties  of
Oklahoma;  Brazos, Burleson, Fayette, Lee, Nolan, Pecos,  Upton,  Ward  and
Winkler  Counties of Texas.  These properties consist of various  interests
in approximately 171 wells and units.

Reserves

The  following table sets forth certain information as of December 31, 2005
with  respect  to the Partnership's estimated proved oil and  gas  reserves
pursuant  to  SEC guidelines and standardized measure of discounted  future
net cash flows.

                       Proved Developed      Proved      Total
                      -------------------    -------    -------
                      -------------------    -------      ----
                           ---------          ----
                      Produci    Nonprod     Undevel     Proved
                         ng       ucing       oped
                      -------    -------     -------    -------
                      -------    -------     -------      ----
                       -----       ----       ----
Oil (Bbls)            149,000     95,000      23,000      267,000
Gas (Mcf)             3,881,00    325,000     915,000     5,121,00
                      0                                 0
Total (BOE)           796,000     149,000     176,000     1,121,00
                                                        0

Standardized  measure
of discounted
   future  net   cash                                     $20,599
flows                                                   ,000

The  following table sets forth certain information as of December 31, 2005
regarding  the  Partnership's  proved oil  and  gas  reserves  for  certain
significant fields.

                  Proved Reserves
              ------------------------
              ------------------------
                      --------
                                Total     Percen
                                 Oil       t of
               Oil      Gas     Equiva    Total
                                 lent      Oil
              (Bbls    (Mcf)    (BOE)     Equiva
                )                          lent
              -----    ------   ------    ------
              -----    -----    ------    ------
               ---               ---       ---
              76,00    4,551,   834,00    74.4%
Amacker/Wilsh 0        000      0
ire
 Rhoda Walker 154,0    471,00   233,00    20.8%
              00       0        0
 Other        37,00    99,000   54,000    4.8%
              0
              -----    ------   ------    ------
              -----    ------   ------    ------
              --                --        --
 Total        267,0    5,121,   1,121,    100.0%
              00       000      000
              =====    ======   ======    ======
              ==       =        ==        ==

The  estimates of proved reserves at December 31, 2005 and the standardized
measure  of  discounted future net cash flows 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.

In  accordance with applicable financial accounting and reporting standards
of  the  SEC,  the estimates of the Partnership's proved reserves  and  the
standardized  measure of discounted future net cash flows 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  standardized measure of discounted future net cash  flows  as  of
December  31, 2005 were $59.69 per Bbl of oil and natural gas  liquids  and
$10.43  per Mcf of gas, as compared to $42.02 per Bbl of oil and $5.36  per
Mcf of gas as of December 31, 2004.

<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  standardized measure 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 2005 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, 2005 there were 559 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 2005, distributions were made  totaling
$2,000,000,  with $1,800,000 ($90.00 per unit) distributed to  the  limited
partners and $200,000 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 2005.

                Total
               Number
              of Units       Average
                              Price
   Period     Purchase      Paid Per
                  d           Unit
------------- --------      --------
------------- --------      --------
     --           -            --
January 2005      20         $460.54
February 2005      -              -
 March 2005        -              -
 April 2005        -              -
  May 2005         -              -
  June 2005        -              -
  July 2005   826.50         528.15
 August 2005       -              -
  September        -              -
    2005
October 2005                      -
November 2005      -              -
December 2005      -              -
              --------        -------
              -             ---
   TOTALS      846.5         $526.55
               =====         ======

<PAGE>
Item 6.   Selected Financial Data

The  following  selected financial data for the years  ended  December  31,
2005,  2004,  2003,  2002 and 2001 should be read in conjunction  with  the
financial statements included in Item 8:

                                   Years ended December 31,
                        2005       2004       2003      2002       2001
                       ------     ------     ------    ------     ------
Revenues            $ 2,310,70    1,375,0   1,237,7    104,701    964,152
                      0           40        19

Net  income (loss)
before
 cumulative effect
of
 accounting change    2,033,48    1,082,1   904,659    (171,77    571,669
                      9           68                   5)

Net income            2,033,48    1,082,1   1,021,2    358,225    571,669
                      9           68        96

Partners' share
 of net income:

General partners      203,349     108,217   102,130    35,822     57,167

Limited partners      1,830,14    973,951   919,166    322,403    514,502
                      0

Limited partners'
 net income (loss)
per unit
 before cumulative
effect
   of   accounting     91.51       48.70    40.71      (7.73)     25.73
change

Limited partners'
  net  income  per     91.51       48.70    45.96      16.12      25.73
unit

Limited partners'
              cash
distributions
 per unit              90.00       50.63    33.75      -          50.74

Total assets        $ 2,816,45    2,773,7   2,828,4    2,047,1    1,688,4
                      4           92        12         63         19



<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>
Supplemental Information
The following unaudited information is intended to supplement the financial
statements  included  in  this Form 10-K with  data  that  is  not  readily
available from those statements.

                               Year Ended December 31,
                               2005      2004      2003
                              ------    ------   --------
                                                  -----
Oil production in            21,708    19,991    21,800
barrels
Gas production in mcf        262,245   245,548   275,100
Total (BOE)                  65,416    60,916    67,650
Average price per barrel  $    56.14     39.43
of oil                                           29.69
Average price per mcf of  $     7.62      5.90
gas                                              4.84
Partnership               $  2,000,00  1,125,04  750,091
distributions                0         1
Limited partner           $  1,800,00  1,012,53  675,082
distributions                0         2
Per unit distribution to  $    90.00     50.63
limited partners                                 33.75
Number of limited            20,000    20,000    20,000
partner units

Operating Results
The  following discussion compares our results for the year ended  December
31,  2005 to the two previous years.  All references to 2005, 2004 and 2003
within this section refer to the respective annual periods.

Income from net profits
Oil  and  gas  prices continued to climb to record levels compared  to  the
previous  two  years.  Comparing 2005 to 2004, oil and gas sales  increased
$981,100,  of  which price variances accounted for a $814,900 increase  and
production variances accounted for a $166,200 increase.  Comparing 2004  to
2003,  oil  and  gas  sales increased $256,200, of  which  price  variances
accounted for a $453,100 increase and production variances accounted for  a
$196,900 decrease.

Production  in 2005 (on a BOE basis) was 7% higher than 2004 and  3%  lower
than  2003.  We increased our oil and gas production in 2005 due  primarily
to production from new wells.

In  2005,  our realized oil price was 42% higher than 2004 and  89%  higher
than  2003, while our realized gas price was 29% higher than 2004  and  57%
higher  than  2003.  Historically, the markets for oil and  gas  have  been
volatile,  and they are likely to continue to be volatile.   We  have  very
little  control  over  the  prices we receive for  our  production  at  the
wellhead  since  most  of our physical marketing arrangements  are  market-
sensitive.

Oil  and gas production costs on a BOE basis decreased from $14.18 per  BOE
in  2004  and increased from $11.12 per BOE in 2003 to $13.95  per  BOE  in
2005.   Oil  and  gas production costs per BOE decreased primarily  due  to
increased  production  from  new  wells.   Oil  and  gas  production  costs
increased in 2005 over 2004 primarily due to an increase in production  tax
costs  due to higher product prices.  It is likely that these factors  will
continue to contribute to higher production costs in future periods.

Expenses
Depletion  on  a  BOE  basis decreased 13% from 2004  and  25%  from  2003.
Comparing  2005 to 2004, depletion expense decreased $7,200, of which  rate
variances  accounted  for  a  $14,700  decrease  and  production  variances
accounted for a $7,500 increase.  Comparing 2004 to 2003, depletion expense
decreased $28,300, of which rate variances accounted for a $15,400 decrease
and production variances accounted for a $12,900 decrease.  Depletion rates
are  a  function of net capitalized costs and estimated reserve quantities.
The rates for 2006 are expected to be similar to the 2005 rates.

General and administrative ("G&A") expenses were 6% lower than 2004 and  5%
lower  than  2003 due primarily to lower engineering fees and lower  annual
report printing costs.

Liquidity and Capital Resources
Partnership  distributions during the year ended  December  31,  2005  were
$2,000,000, of which $1,800,000 was distributed to the limited partners and
$200,000  to  the  general  partners.  Cumulative  cash  distributions   of
$21,328,986  have  been  made to the general and  limited  partners  as  of
December  31,  2005.  As of December 31, 2005, $19,211,791 or  $960.59  per
limited  partner  unit  has  been  distributed  to  the  limited  partners,
representing 192% of contributed capital.

<PAGE>
Our  primary  source of cash from operating activities is our oil  and  gas
sales, net of production costs.  Cash flow provided by operating activities
for  2005 was 110% higher than 2004 due to the combined effects of  several
drivers.   The  positive benefits of a 44% increase in oil and  gas  sales,
driven  primarily  by higher oil and gas prices, were  offset  in  part  by
increases in production costs.  Our only use in financing activities is the
distribution to partners which was 78% higher than 2004.

As  of  December  31, 2005, the Partnership had approximately  $624,400  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 adopted this
statement  in the third quarter of 2005, and it did not have an  effect  on
the financial statements.

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 are 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 implementation of SAB 106 did not 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                 17

Balance Sheets                                                          18

Statements of Operations                                                19

Statement of Changes in Partners' Equity                                20

Statements of Cash Flows                                                21

Notes to Financial Statements                                           23

<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, 2005 and  2004,
and  the related statements of operations, partners' equity, and cash flows
for  each  of the years in the three-year period ended December  31,  2005.
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, 2005 and 2004, and the  results  of
its  operations and its cash flows for each of the years in the  three-year
period  ended December 31, 2005, in conformity with U.S. generally accepted
accounting principles.

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 30, 2006

<PAGE>


                 Southwest Royalties, Inc. Income Fund VI
                    (a Tennessee limited partnership)
                              Balance Sheets
                        December 31, 2005 and 2004


                                           2005      2004
                                          ------    ------
Assets
---------
Current assets:
 Cash and cash equivalents            $  271,508   128,990
  Receivable  from  Managing  General    352,550   342,286
Partner
 Other                                   522       313
                                         --------  --------
                                         ------    ------
   Total current assets                  624,580   471,589
                                         --------  --------
                                         ------    ------
Oil  and  gas properties - using  the
full-
 cost method of accounting               8,531,46  8,547,31
                                         7         7
  Less accumulated depreciation,
   depletion and amortization            6,339,59  6,245,11
                                         3         4
                                         --------  --------
                                         ------    ------
   Net oil and gas properties            2,191,87  2,302,20
                                         4         3
                                         --------  --------
                                         ------    ------
                                      $  2,816,45  2,773,79
                                         4         2
                                         ========  ========
Liabilities and Partners' Equity
-------------------------------------
---

Current   liability  -   distribution $  180       -
payable
                                         --------  --------
                                         ------    ------

Asset retirement obligation              510,646   501,653
                                         --------  --------
                                         ------    ------
Partners' equity (deficit):
 General partner                         (623,772  (627,121
                                         )         )
 Limited partners                        2,929,40  2,899,26
                                         0         0
                                         --------  --------
                                         ------    ------
   Total partners' equity                2,305,62  2,272,13
                                         8         9
                                         --------  --------
                                         ------    ------
                                      $  2,816,45  2,773,79
                                         4         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, 2005, 2004 and 2003

                                     2005      2004      2003
                                    ------    ------    ------
Revenues
-------------
   Income   from  net   profits $  2,304,45  1,372,32  1,227,58
interests                          6         3         9
 Interest income                   5,399     1,972     1,178
 Other                             845       745       8,952
                                   --------  --------  --------
                                   ------    -----     -----
                                   2,310,70  1,375,04  1,237,71
                                   0         0         9
                                   --------  --------  --------
                                   ------    -----     -----
Expenses
-------------
  Depreciation,  depletion  and    94,479    101,654   130,000
amortization
 Accretion expense                 27,488    26,642    39,008
 General and administrative        155,244   164,576   164,052
                                   --------  --------  --------
                                   ------    -----     -----
                                   277,211   292,872   333,060
                                   --------  --------  --------
                                   ------    -----     -----
Net  income  before  cumulative
effect
 of accounting change              2,033,48  1,082,16  904,659
                                   9         8

Cumulative effect of change  in
accounting
 principle - SFAS No. 143 - See    -         -         116,637
Note 3
                                   --------  --------  --------
                                   ------    -----     -----
Net income                      $  2,033,48  1,082,16  1,021,29
                                   9         8         6
                                   ========  =======   =======
Net income allocated to:

 Managing General Partner       $  203,349   108,217   102,130
                                   ========  =======   =======
 Limited partners               $  1,830,14  973,951   919,166
                                   0
                                   ========  =======   =======
    Per  limited  partner  unit $    91.51     48.70
before cumulative effect                               40.71
     Cumulative   effects   per          -         -
limited partner unit                                   5.25
                                   --------  --------  --------
                                   ------    -----     -----
  Per limited partner unit      $    91.51     48.70
                                                       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, 2005, 2004 and 2003


                           General   Limited
                           Partner   Partners   Total
                           --------  --------  --------
                             ---      -----
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

 Net income                203,349   1,830,14  2,033,48
                                     0         9

 Distributions             (200,000  (1,800,0  (2,000,0
                           )         00)       00)
                           --------  --------  --------
                           ------    ------    ------
Balance   at  December  $  (623,772  2,929,40  2,305,62
31, 2005                   )         0         8
                           ========  ========  ========



























                  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, 2005, 2004 and 2003

                                      2005      2004      2003
                                     ------    ------    ------
Cash   flows   from   operating
activities:

 Cash received from net profits  $  2,291,33  1,180,93  1,124,00
interests                           8         6         2
  Cash  paid for administrative
fees and general
  and administrative overhead       (155,244  (164,576  (164,052
                                    )         )         )
 Interest received                  5,399     1,972     1,178
 Other                              845       745       8,952
                                    --------  --------  --------
                                    ------    ------    ------
     Net   cash   provided   by     2,142,33  1,019,07  970,080
operating activities                8         7
                                    --------  --------  --------
                                    ------    ------    ------
Cash   flows   from   investing
activities:

 Sale of oil and gas properties     -         -         306
                                    --------  --------  --------
                                    ------    ------    ------
Cash   flows   from   financing
activities:

 Distributions to partners          (2,000,0  (1,125,0  (750,091
                                    00)       41)       )
    Increase   (decrease)    in     180       -         (3,356)
distributions payable
                                    --------  --------  --------
                                    ------    ------    ------
   Net  cash  used in financing     (1,999,8  (1,125,0  (753,447
activities                          20)       41)       )
                                    --------  --------  --------
                                    ------    ------    ------
  Net  increase  (decrease)  in     142,518   (105,964  216,939
cash and cash equivalents                     )

 Beginning of year                  128,990   234,954   18,015
                                    --------  --------  --------
                                    ------    ------    ------
 End of year                     $  271,508   128,990   234,954
                                    ========  ========  ========
                                                        (continu
                                                        ed)
                 Southwest Royalties, Inc. Income Fund VI
                    (a Tennessee limited partnership)
                         Statements of Cash Flows
               Years ended December 31, 2005, 2004 and 2003

                                      2005      2004      2003
                                     ------    ------    ------
Reconciliation of net income to
net
  cash  provided  by  operating
activities:
Net income                       $  2,033,48  1,082,16  1,021,29
                                    9         8         6

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

  Depreciation,  depletion  and     94,479    101,654   130,000
amortization
 Accretion expense                  27,488    26,642    39,008
  Settlement  of  ARO  for  P&A     (2,645)   (38,389)  -
wells
 Cumulative effect of change in     -         -         (116,637
accounting principle                                    )
 Increase in receivables            (10,473)  (152,998  (103,587
                                              )         )
                                    --------  --------  --------
                                    ------    ------    ------
Net  cash provided by operating  $  2,142,33  1,019,07  970,080
activities                          8         7
                                    ========  ========  ========
Noncash investing and financing
activities:
 Increase in oil and properties
- Adoption
  of SFAS No. 143                $  -         -         616,464
                                    ========  ========  ========
 (Decrease) increase in oil and
gas properties -
  SFAS No. 143                   $  (15,850)  -         422
                                    ========  ========  ========



























                  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, 2005, 2004  and  2003,
    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, 2005,  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
    The  Partnership  recognizes 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, 2005 and 2004,  the
    Partnership  was  under  produced  by  5,312  and  5,306  mcf  of  gas,
    respectively.

    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, 2005 and 2004 is $1,880,677 and $1,932,696, 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,  2005, 2004 and 2003, there were  20,000  limited
    partner units outstanding held by 559, 602 and 667 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 per limited partnership unit
    The  net income 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 adopted this statement in the third quarter  of  2005,
    and it did not have an effect on the financial statements.

    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 are 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  implementation
    of SAB 106 did not have a material impact on our financial statements.

3.  Asset Retirement Obligations
    On  January  1,  2003, the Partnership adopted Statement  of  Financial
    Accounting   Standards  No.  143,  Accounting  for   Asset   Retirement
    Obligations ("SFAS No. 143").  The 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  $616,464,  a  long  term  liability  of
    $499,827  and  a  gain  of  $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.


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

                      Notes to Financial Statements

3.  Asset Retirement Obligation - continued

    Changes in abandonment obligations for 2005 and 2004 are as follows:

                                        2005     2004
                                       -------  -------
Beginning of year                   $  501,653  513,400
Additional abandonment obligations     3,934    -
from new wells
Reduction  of obligations  due  to     (32,811  -
farmouts                               )
Reduction  of obligations  due  to     (2,645)  (38,389
wells plugged and abandoned                     )
Accretion expense                      27,488   26,642
Revisions of previous estimates        13,027   -
                                       -------  -------
                                       -------  -----
End of year                         $  510,646  501,653
                                       =======  =======
                                       =

4.  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, 2005, 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.

5.  Related Party Transactions
    A  significant  portion  of the oil and gas  properties  in  which  the
    Partnership  has  an interest are purchased from and  operated  by  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  $92,700,  $85,700
    and  $83,000,  for the years ended December 31, 2005,  2004  and  2003,
    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  2005,  2004 and 2003, 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.

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

                      Notes to Financial Statements

5.  Related Party Transactions - continued
    Receivables  from  Southwest  Royalties,  Inc.,  the  Managing  General
    Partner,  of approximately $352,600 and $342,300 are from oil  and  gas
    production,  net of lease operating costs and production taxes,  as  of
    December 31, 2005 and 2004, respectively.

6.  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, 2003              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

       New  discoveries  and  2,000     15,000
extensions
      Revisions of  previous  16,000    (513,000
estimates                               )
     Production               (22,000)  (262,000
                                        )
                              --------  --------
                              ----      ------
December 31, 2005             267,000   5,121,00
                                        0
                              =======   ========
Proved developed reserves -
December 31, 2003             138,000   4,018,00
                                        0
                              =======   ========
December 31, 2004             227,000   4,326,00
                                        0
                              =======   ========
December 31, 2005             243,000   4,206,00
                                        0
                              =======   ========

    Net  revisions of 70,000 BOE in 2005 consisted of approximately  44,000
    BOE  of  upward revisions attributable to the effects of higher product
    prices  on the estimated quantities of proved reserves, net of downward
    revisions of approximately 114,000 BOE attributable to well performance
    primarily from properties in the Amacker/Wilshire field of West Texas.

<PAGE>

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

                      Notes to Financial Statements

6.  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
   standardized measure as of December 31, 2005, 2004 and 2003 reflects  an
   average oil price of $59.69, $42.02 and $31.26 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 standardized measure as of December  31,
    2005,  2004  and 2003 reflects an average natural gas price of  $10.43,
    $5.36 and $5.31 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

6.  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, 2005, 2004 and 2003  is
    presented below:

                            2005      2004      2003
                           ------    ------    ------
Future cash inflows    $  69,358,0  42,902,0  33,658,0
                          00        00        00
Production,
development
    and   abandonment     18,482,0  12,108,0  8,608,00
costs                     00        00        0
                          --------  --------  --------
                          ------    ------    ------
Future net cash flows     50,876,0  30,794,0  25,050,0
                          00        00        00
10%  annual  discount
for
  estimated timing of     30,277,0  16,769,0  13,629,0
cash flows                00        00        00
                          --------  --------  --------
                          ------    -----     ------
Standardized  measure
of
   discounted  future
net cash
 flows                 $  20,599,0  14,025,0  11,421,0
                          00        00        00
                          ========  ========  ========

     Changes  in  the  standardized measure of discounted future  net  cash
     flows  relating  to proved reserves for the years ended  December  31,
     2005, 2004 and 2003 are as follows:

                            2005      2004      2003
                            ----      ----      ----
Sales of oil and  gas
produced,
  net  of  production  $  (2,304,0  (1,372,0  (1,228,0
costs                     00)       00)       00)
Extensions        and     118,000   2,799,00  -
discoveries                         0
Changes in prices and
production
 costs                    10,253,0  185,000   1,679,00
                          00                  0
Changes of production
rates
 (timing) and others      (1,618,0  (766,000  (151,000
                          00)       )         )
Sales of minerals  in     -         -         (18,000)
place
Revisions of previous
 quantities estimates     (1,278,0  616,000   2,148,00
                          00)                 0
Accretion of discount     1,403,00  1,142,00  817,000
                          0         0
Discounted future net
cash flows -
 Beginning of year        14,025,0  11,421,0  8,174,00
                          00        00        0
                          --------  --------  --------
                          ------    ------    ------
 End of year           $  20,599,0  14,025,0  11,421,0
                          00        00        00
                          ========  ========  ========



<PAGE>

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

                      Notes to Financial Statements

7.   Selected Quarterly Financial Results - (unaudited)

                                             Quarter
                              --------------------------------------
                              --------------------------------------
                                                -
                               First     Second    Third     Fourth
                               ------   --------  -------   --------
                                          ---                  -
2005:
 Total revenues             $ 567,129   533,681   655,046   554,844
 Total expenses               71,773    72,428    63,457    69,553
                              --------  --------  --------  --------
                              ----      ----      ----      ----
 Net income                   495,356   461,253   591,589   485,291
                              =======   =======   =======   =======

  Net  income per  limited  $  22.29
partner unit                            20.76     26.62     21.84
                              =======   =======   =======   =======


                                             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
                              =======   =======   =======   =======


<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,
2005  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 74, 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  54,  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 51, 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.

RANDY  HOWARD, age 50, is Vice President - of the Managing General Partner,
having served in this capacity since March 2006.

ROBERT C. LYON, age 69, 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 49, 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.

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 2005, 2004 and 2003 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  9,118.4  limited  partner units,  a  41.0%  limited  partner
interest.   The  Managing  General  Partner's  total  percentage   interest
ownership in the Partnership is 51.0%.

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   2005,   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 $92,700 for administrative overhead attributable
to operating such properties during 2005.

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 Accountant 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, 2005 and 2004 and fees billed for  other
services rendered by KPMG during those periods.

For  the  Year Ended December    2005      2004
31,
                                ------    ------
Audit Fees                     $13,303   $
                                         12,865
Audit Related Fees                  -         -
Tax Fees                            -
                                         -
All Other Fees                      -
                                         -
                                 ------    ------
                               ---       --
    TOTAL                      $13,303   $
                                         12,865
                                =====
                                         =====

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 30, 2006


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 30, 2006                     Date:     March 30, 2006




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

Date:     March 30, 2006



<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 30, 2006              /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

<PAGE>
                    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 30, 2006              /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

<PAGE>
                                                               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, 2005 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 30, 2006


                                   /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 30, 2006

<PAGE>