22

                           FORM 10-Q


               SECURITIES AND EXCHANGE COMMISSION
                    WASHINGTON, D.C.  20549

(Mark One)

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

For the quarterly period ended June 30, 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 of                 (I.R.S. Employer
incorporation or organization)               Identification No.)

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

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

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

                              Yes X No ___

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

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

   The total number of pages contained in this report is 22.

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

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

     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.

<PAGE>

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

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

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

     Proved  developed  oil and gas reserves. Proved 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 and 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. - FINANCIAL INFORMATION


Item 1.   Financial Statements

The  unaudited  condensed financial statements included  herein  have  been
prepared  by  the Registrant (herein also referred to as the "Partnership")
in  accordance  with generally accepted accounting principles  for  interim
financial information and with the instructions to Form 10-Q and Rule 10-01
of Regulation S-X.  Accordingly, they do not include all of the information
and  footnotes  required  by generally accepted accounting  principles  for
complete   financial  statements.   In  the  opinion  of  management,   all
adjustments necessary for a fair presentation have been included and are of
a  normal  recurring nature.  The financial statements should  be  read  in
conjunction with the audited financial statements and the notes thereto for
the  year ended December 31, 2004, which are found in the Registrant's Form
10-K  Report  for  2004 filed with the Securities and Exchange  Commission.
The December 31, 2004 balance sheet included herein has been taken from the
Registrant's  2004 Form 10-K Report.  Operating results for the  three  and
six month periods ended June 30, 2005 are not necessarily indicative of the
results that may be expected for the full year.

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


                                         June 30,  December
                                                      31,
                                           2005      2004
                                          ------    ------
                                         (unaudit
                                            ed)
Assets
---------
Current assets:
 Cash and cash equivalents            $  162,737   128,990
  Receivable  from  Managing  General    337,338   342,286
Partner
 Oklahoma withholding prepayment         411       313
                                         --------  --------
                                         ------    ------
   Total current assets                  500,486   471,589
                                         --------  --------
                                         ------    ------
Oil  and  gas properties - using  the
full-
 cost method of accounting               8,532,69  8,547,31
                                         5         7
  Less accumulated depreciation,
   depletion and amortization            6,295,89  6,245,11
                                         6         4
                                         --------  --------
                                         ------    ------
   Net oil and gas properties            2,236,79  2,302,20
                                         9         3
                                         --------  --------
                                         ------    ------
                                      $  2,737,28  2,773,79
                                         5         2
                                         ========  ========
Liabilities and Partners' Equity
-------------------------------------
---

Current liability:
 Distribution payable                 $  9,722     -
                                         --------  --------
                                         ------    ------

Asset retirement obligation              498,815   501,653
                                         --------  --------
                                         ------    ------
Partners' equity (deficit):
 General partner                         (631,460  (627,121
                                         )         )
 Limited partners                        2,860,20  2,899,26
                                         8         0
                                         --------  --------
                                         ------    ------
   Total partners' equity                2,228,74  2,272,13
                                         8         9
                                         --------  --------
                                         ------    ------
                                      $  2,737,28  2,773,79
                                         5         2
                                         ========  ========











                  The accompanying notes are an integral
                    part of these financial statements.
<PAGE>
                 Southwest Royalties, Inc. Income Fund VI
                         Statements of Operations
                                (unaudited)

                                 Three Months Ended  Six Months Ended
                                      June 30,           June 30,
                                   2005      2004      2005     2004
                                  -----     -----     -----    -----
    Revenues
    -------------
    Income  from net profits  $  532,579   314,554   1,098,0  695,779
    interests                                        09
    Interest                     1,100     463       1,957    925
    Other                        2         -         845      250
                                 --------  --------  -------  -------
                                 --        --        ------   ---
                                 533,681   315,017   1,100,8  696,954
                                                     11
                                 --------  --------  -------  -------
                                 --        --        ------   ---
    Expenses
    ------------
    Depreciation,  depletion     25,669    29,000    50,782   56,000
    and amortization
    Accretion expense            5,894     10,268    11,783   20,535
    General              and     40,865    43,602    81,637   83,886
    administrative
                                 --------  --------  -------  -------
                                 --        --        ------   ---
                                 72,428    82,870    144,202  160,421
                                 --------  --------  -------  -------
                                 --        --        ------   ---
    Net income                $  461,253   232,147   956,609  536,533
                                 ======    ======    =======  ======
    Net income allocated to:
    Managing         General  $  46,125    23,215    95,661   53,653
    Partner
                                 ======    ======    =======  ======
    Limited Partners          $  415,128   208,932   860,948  482,880
                                 ======    ======    =======  ======
       Per  limited  partner  $    20.76
    unit                                   10.45     43.05    24.14
                                 ======    ======    =======  ======





















                  The accompanying notes are an integral
                    part of these financial statements.
<PAGE>
                 Southwest Royalties, Inc. Income Fund VI
                         Statements of Cash Flows
                                (unaudited)

                                       Six Months Ended
                                           June 30,
                                        2005      2004
                                       -----     -----
Cash    flows   from    operating
activities:

  Cash received from income  from
net
  profits interests                $  1,102,86  594,553
                                      0
 Cash paid to suppliers               (81,637)  (83,886)
 Interest received                    1,957     925
 Other                                845       250
                                      --------  --------
                                      -----     ----
   Net cash provided by operating     1,024,02  511,842
activities                            5
                                      --------  --------
                                      -----     ----
Cash    flows   from    financing
activities:
 Distributions to partners            (1,000,0  (575,000
                                      00)       )
 Increase in distribution payable     9,722     -
                                      --------  --------
                                      -----     ----
   Net  cash  used  in  financing     (990,278  (575,000
activities                            )         )
                                      --------  --------
                                      -----     ----

Net  increase (decrease) in  cash     33,747    (63,158)
and cash equivalents

Beginning of period                   128,990   234,954
                                      --------  --------
                                      -----     ----
End of period                      $  162,737   171,796
                                      =======   =======
Reconciliation of net  income  to
net
   cash   provided  by  operating
activities:

Net income                         $  956,609   536,533

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

   Depreciation,  depletion   and     50,782    56,000
amortization
 Accretion expense                    11,783    20,535
     Decrease    (increase)    in     4,851     (101,226
receivables                                     )
                                      --------  --------
                                      -----     ----
Net  cash  provided by  operating  $  1,024,02  511,842
activities                            5
                                      =======   =======
Noncash  investing and  financing
activities:

   Increase   in  oil   and   gas
properties - SFAS No. 143
  Additional wells                 $  2,259     -
                                      =======   =======
   Decrease working interest from  $  (16,881)  -
farm-out
                                      =======   =======

                  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:
                              Limited   General
                              Partners  Partners
                              --------  --------
Interest  income on  capital  100%      -
contributions
Oil and gas sales             90%       10%
All other revenues            90%       10%
Organization  and   offering  100%      -
costs (1)
Amortization of organization  100%      -
costs
Property acquisition costs    100%      -
Gain/loss    on     property  90%       10%
disposition
Operating and administrative  90%       10%
costs (2)
Depreciation, depletion  and
amortization
 of oil and gas properties    90%       10%
All other costs               90%       10%

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

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

2.   Summary of Significant Accounting Policies
     The  interim  financial information as of June 30, 2005, and  for  the
     three  and  six  months  ended June 30, 2005, is  unaudited.   Certain
     information  and footnote disclosures normally included  in  financial
     statements  prepared in accordance with generally accepted  accounting
     principles  have been condensed or omitted in this Form 10-Q  pursuant
     to   the   rules  and  regulations  of  the  Securities  and  Exchange
     Commission.  However,  in  the opinion of  management,  these  interim
     financial  statements include all the necessary adjustments to  fairly
     present  the  results of the interim periods and all such  adjustments
     are  of a normal recurring nature.  The interim consolidated financial
     statements should be read in conjunction with the Partnership's Annual
     Report on Form 10-K for the year ended December 31, 2004.

     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.

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

General

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

The Partnership was formed to acquire royalty and net profits interests  in
producing  oil  and  gas properties, to produce and market  crude  oil  and
natural  gas  produced  from such properties, and  to  distribute  the  net
proceeds from operations to the limited and general partners.  Net revenues
from  producing  oil  and gas properties will not be  reinvested  in  other
revenue  producing  assets except to the extent that production  facilities
and wells are improved or reworked or where methods are employed to improve
or  enable  more efficient recovery of oil and gas reserves.  The  economic
life  of  the  partnership  thus  depends on  the  period  over  which  the
Partnership's oil and gas reserves are economically recoverable.

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

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

Oil and Gas Properties

Oil  and  gas  properties  are accounted for at cost  under  the  full-cost
method.  Under this method, all productive and nonproductive costs incurred
in  connection with the acquisition, exploration and development of oil and
gas  reserves  are capitalized.  Gain or loss on the sale of  oil  and  gas
properties  is not recognized unless significant oil and gas  reserves  are
sold.

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 June 30, 2005, the net capitalized costs  did  not
exceed the estimated present value of oil and gas reserves.

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

The  Partnership recognizes income from its net profits interest in oil and
gas property on an accrual basis, while the quarterly cash distributions of
the net profits interest are based on a calculation of actual cash received
from  oil  and  gas sales, net of expenses incurred during  that  quarterly
period.   If  the  net  profits interest calculation  results  in  expenses
incurred  exceeding the oil and gas income received during  a  quarter,  no
cash  distribution is due to the Partnership's net profits  interest  until
the  deficit is recovered from future net profits.  The Partnership accrues
a quarterly loss on its net profits interest provided there is a cumulative
net  amount  due for accrued revenue as of the balance sheet date.   As  of
June  30,  2005,  there were no timing differences,  which  resulted  in  a
deficit net profit interest.

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

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

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

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


<PAGE>
Results of Operations

General Comparison of the Quarters Ended June 30, 2005 and 2004

The  following  table  provides certain information  regarding  performance
factors for the quarters ended June 30, 2005 and 2004:

                                         Three Months
                                            Ended         Percenta
                                                             ge
                                           June 30,       Increase
                                        2005      2004    (Decreas
                                                             e)
                                       -----     -----    --------
                                                             --
Oil production in barrels             5,828     4,870     20%
Gas production in mcf                 69,227    67,325    3%
Total BOE                             17,366              8%
                                                16,091
Average price per barrel of oil    $  52.77               42%
                                                37.24
Average price per mcf of gas       $   7.20               25%
                                                5.77
Income from net profits interests  $  532,579   314,554   69%
Partnership distributions          $  500,000   250,000   100%
Limited partner distributions      $  450,000   225,000   100%
Per unit distribution to limited
 partners                          $  22.50               100%
                                                11.25
Number of limited partner units       20,000    20,000

Income from net profits

The  Partnership's income from net profits interests increased to  $532,579
from  $314,554 for the quarters ended June 30, 2005 and 2004, respectively,
an  increase of 69%.  The principal factors affecting the comparison of the
quarters ended June 30, 2005 and 2004 are as follows:

The average price for a barrel of oil received by the Partnership increased
during  the  quarter ended June 30, 2005 as compared to the  quarter  ended
June  30,  2004 by 42%, or $15.53 per barrel, resulting in an  increase  of
approximately  $90,500  in income from net profits  interests.   Oil  sales
represented  38% of total oil and gas sales during the quarter  ended  June
30, 2005 as compared to 32% during the quarter ended June 30, 2004.

The  average price for an mcf of gas received by the Partnership  increased
during  the same period by 25%, or $1.43 per mcf, resulting in an  increase
of approximately $99,000 in income from net profits interests.

The  total increase in income from net profits interests due to the  change
in  prices  received from oil and gas production is approximately $189,500.
The  market price for oil and gas has been extremely volatile over the past
decade,  and management expects a certain amount of volatility to  continue
in the foreseeable future.

<PAGE>
Oil  production  increased  approximately 958 barrels  or  20%  during  the
quarter ended June 30, 2005 as compared to the quarter ended June 30, 2004,
resulting  in  an  increase of approximately $35,700  in  income  from  net
profits interests.

Gas  production  increased approximately 1,902 mcf or 3%  during  the  same
period,  resulting in an increase of approximately $11,000 in  income  from
net profits interests.

The  total increase in income from net profits interests due to the  change
in  production is approximately $46,700.  The increase in oil production is
due  to  a reactivated well and due to activity under farm-out arrangements
including  a  well with new zones developed and new wells  drilled  in  the
first quarter of 2005.

Lease operating costs and production taxes were 7% higher, or approximately
$17,900  more  during the quarter ended June 30, 2005 as  compared  to  the
quarter ended June 30, 2004.

Costs and Expenses

Total costs and expenses decreased to $72,428 from $82,870 for the quarters
ended  June  30,  2005  and 2004, respectively, a  decrease  of  13%.   The
decrease  is  the  result  of  lower general  and  administrative  expense,
depletion expense and accretion expense.

General  and administrative costs consist of independent accounting,  legal
and  engineering  fees, computer services, postage,  and  Managing  General
Partner personnel costs.  General and administrative costs decreased 6%  or
approximately $2,700 during the quarter ended June 30, 2005 as compared  to
the quarter ended June 30, 2004.

Depletion expense decreased to $25,669 for the quarter ended June 30,  2005
from  $29,000 for the same period in 2004.  This represents a  decrease  of
11%.   The contributing factor to the decrease in depletion expense  is  in
relation  to  the BOE depletion rate for the quarter ended June  30,  2005,
which  was  $1.48  applied to 17,366 BOE as compared to  $1.80  applied  to
16,091  BOE  for the same period in 2004.  The lower depreciation  rate  in
2005  is  due  to  the upward revision in reserve estimates resulting  from
higher oil and gas prices.

Accretion expense decreased to $5,894 for the quarter ended June  30,  2005
from  $10,268 for the same period in 2004.  This represents a  decrease  of
43%.   The decrease in accretion is from discontinuing accretion on several
wells that reached their projected end of life in 2004.


<PAGE>
General Comparison of the Six Month Periods Ended June 30, 2005 and 2004

The  following  table  provides certain information  regarding  performance
factors for the six month periods ended June 30, 2005 and 2004:

                                     Six Months
                                       Ended         Percenta
                                                        ge
                                      June 30,       Increase
                                   2005      2004    (Decreas
                                                        e)
                                  -----     -----    --------
                                                        --
Oil production in barrels        11,281    10,750    5%
Gas production in mcf            139,939   126,125   11%
Total BOE                        34,604    31,771    9%
Average price per barrel  of  $    52.36             50%
oil                                        34.98
Average price per mcf of gas  $     6.49             13%
                                           5.73
Income   from  net   profits  $  1,098,00  695,779   58%
interests                        9
Partnership distributions     $  1,000,00  575,000   74%
                                 0
Limited              partner  $  900,000   517,500   74%
distributions
Per  unit  distribution   to  $    45.00             74%
limited partners                           25.88
Number  of  limited  partner     20,000    20,000
units

Income from net profits

The Partnership's income from net profits interests increased to $1,098,009
from   $695,779  for  the  six  months  ended  June  30,  2005  and   2004,
respectively,  an  increase of 58%.  The principal  factors  affecting  the
comparison of the six months ended June 30, 2005 and 2004 are as follows:

The average price for a barrel of oil received by the Partnership increased
during  the  six months ended June 30, 2005 as compared to the  six  months
ended  June 30, 2004 by 50%, or $17.38 per barrel, resulting in an increase
of  approximately $196,100 in income from net profits interests.  Oil sales
represented 39% of total oil and gas sales during the six months ended June
30, 2005 as compared to 34% during the six months ended June 30, 2004.

The  average  price for a mcf of gas received by the Partnership  increased
during the same period by 13%, or $.76 per mcf, resulting in an increase of
approximately $106,400 in income from net profits interests.

The  total increase in income from net profits interests due to the  change
in  prices  received from oil and gas production is approximately $302,500.
The  market price for oil and gas has been extremely volatile over the past
decade,  and management expects a certain amount of volatility to  continue
in the foreseeable future.

<PAGE>
Oil  production  increased approximately 531 barrels or 5% during  the  six
months  ended  June 30, 2005 as compared to the six months ended  June  30,
2004, resulting in an increase of approximately $18,600 in income from  net
profits interests.

Gas  production increased approximately 13,814 mcf or 11% during  the  same
period,  resulting in an increase of approximately $79,200 in  income  from
net profits interests.

The  total increase in income from net profits interests due to the  change
in  production is approximately $97,800.  The increase in gas production is
from improved production on a gas well after a formation stimulation.  Also
adding to the increase is production from three new gas wells drilled under
farm-out arrangements that were completed in the first quarter 2005.

Lease  operating  costs and production taxes were less than  1%  lower,  or
approximately  $1,700 less during the six months ended  June  30,  2005  as
compared to the six months ended June 30, 2004.

Costs and Expenses

Total  costs and expenses decreased to $144,202 from $160,421 for  the  six
months ended June 30, 2005 and 2004, respectively, a decrease of 10%.   The
decrease  is  the  result  of  a  lower  depletion  expense,  general   and
administrative expense and accretion expense.

General and administrative costs consists of independent accounting,  legal
and  engineering  fees, computer services, postage,  and  Managing  General
Partner personnel costs.  General and administrative costs decreased 3%  or
approximately $2,200 during the six months ended June 30, 2005 as  compared
to the six months ended June 30, 2004.

Depletion  expense decreased to $50,782 for the six months ended  June  30,
2005  from $56,000 for the same period in 2004.  This represents a decrease
of  9%.  The contributing factor to the decrease in depletion expense is in
relation to the BOE depletion rate for the six months ended June 30,  2005,
which  was  $1.47  applied to 34,604 BOE as compared to  $1.76  applied  to
31,771  BOE  for the same period in 2004.  The lower depreciation  rate  in
2005  is  due  to  the upward revision in reserve estimates resulting  from
higher oil and gas prices.

Accretion  expense decreased to $11,783 for the six months ended  June  30,
2005  from $20,535 for the same period in 2004.  This represents a decrease
of  43%.  The  decrease  in  accretion is from discontinuing  accretion  on
several wells that reached their projected end of life in 2004.

<PAGE>
Liquidity and Capital Resources

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

Cash  flows  provided by operating activities were approximately $1,024,000
in the six months ended June 30, 2005 as compared to approximately $511,800
in the six months ended June 30, 2004.

Cash flows used in financing activities were approximately $990,300 in  the
six months ended June 30, 2005 as compared to approximately $575,000 in the
six  months ended June 30, 2004.  The only use in financing activities  was
the distributions to partners.

Total  distributions  during  the  six months  ended  June  30,  2005  were
$1,000,000  of  which  $900,000 ($45.00 per unit) was  distributed  to  the
limited  partners and $100,000 to the general partner. Total  distributions
during  the six months ended June 30, 2004 were $575,000 of which  $517,500
was  ($25.88 per unit) distributed to the limited partners and  $57,500  to
the general partner.

The  sources  for  the 2005 distributions of $1,000,000 were  oil  and  gas
operations  of  approximately  $1,024,000, resulting  in  excess  cash  for
contingencies  or  subsequent distributions.   The  sources  for  the  2004
distributions  of  $575,000  were oil and gas operations  of  approximately
$511,800, with the balance from available cash on hand at the beginning  of
the period.

Cumulative cash distributions of $20,328,986 have been made to the  general
and  limited  partners.  As of June 30, 2005, $18,3111,791 or  $915.59  per
limited  partner  unit  has  been  distributed  to  the  limited  partners,
representing 183% of contributed capital.

As  of June 30, 2005, the Partnership had approximately $490,800 in working
capital.   The  Managing  General Partner knows of no  unusual  contractual
commitments.   Although the partnership held many long-lived properties  at
inception,  because of the restrictions on property development imposed  by
the partnership agreement, the Partnership cannot develop its non-producing
properties, if any.  Without continued development, the producing  reserves
continue  to  deplete.  Accordingly, as the Partnership's  properties  have
matured  and  depleted,  the  net  cash  flows  from  operations  for   the
partnership  has  steadily  declined, except in  periods  of  substantially
increased  commodity pricing.  Maintenance of properties and administrative
expenses for the Partnership are increasing relative to production.  As the
properties   continue   to   deplete,   maintenance   of   properties   and
administrative costs as a percentage of production are expected to continue
to increase.

<PAGE>

Recent Accounting Pronouncements

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

In  September  2004,  the Securities and Exchange Commission  issued  Staff
Accounting Bulletin No. 106 ("SAB 106"). SAB 106 expresses the SEC  staff's
views  regarding SFAS No. 143 and its impact on both the full-cost  ceiling
test and the calculation of depletion expense.  In accordance with SAB 106,
beginning in the first quarter of 2005, undiscounted abandonment costs  for
wells  to  be drilled in the future to develop proved reserves 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.


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

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

Item 4.   Controls and Procedures

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 six months ended June 30, 2005
that has materially affected, or is reasonably likely to materially affect,
its internal control over financial reporting.



<PAGE>



                       PART II. - OTHER INFORMATION


Item 1.   Legal Proceedings

          None

Item 2.   Changes in Securities

          None

Item 3.   Defaults Upon Senior Securities

          None

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

          None

Item 5.   Other Information

          None

Item 6.   Exhibits and Reports on Form 8-K

               (a)  Exhibits:

               31.1 Rule 13a-14(a)/15d-14(a) Certification
               31.2 Rule 13a-14(a)/15d-14(a) Certification
               32.1 Certification of Chief Executive Officer
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 the Securities Exchange Act of  1934,  the
registrant  has duly caused this report to be signed on its behalf  by  the
undersigned thereunto duly authorized.

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


                          By:    Southwest Royalties, Inc., Managing
                                 General Partner


                          By:    /s/ L. Paul Latham
                                 L. Paul Latham
                                 President and Chief Executive Officer


Date:  August 12, 2005

<PAGE>

                    SECTION 302 CERTIFICATION                Exhibit 31.1


I, L. Paul Latham, certify that:

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

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

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

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

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

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

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

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

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

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


Date:  August 12, 2005             /s/ L. Paul Latham
                                   L. Paul Latham
                                   President and Chief Executive Officer
                                   of Southwest Royalties, Inc., the
                                   Managing General Partner of
                                   Southwest Royalties, Inc. Income Fund VI

<PAGE>
                    SECTION 302 CERTIFICATION                Exhibit 31.2


I, Mel G. Riggs, certify that:

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

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

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

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

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

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

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

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

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

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


Date:  August 12, 2005             /s/ Mel G. Riggs
                                   Mel G. Riggs
                                     Vice  President  and  Chief  Financial
Officer of
                                   Southwest Royalties, Inc., the
                                   Managing General Partner of
                                   Southwest Royalties, Inc. Income Fund VI

<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-Q  for  the period ended June 30, 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

                                   August 12, 2005


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

                                   August 12, 2005