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                                FORM 10-Q

                    SECURITIES AND EXCHANGE COMMISSION
                         WASHINGTON, D.C.  20549

(Mark One)

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

For the quarterly period ended March 31, 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 20.

<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-month  period
ended March 31, 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


                                           March   December
                                            31,       31,
                                           2005      2004
                                          ------    ------
                                         (unaudit
                                            ed)
Assets
---------
Current assets:
 Cash and cash equivalents            $  158,522   128,990
  Receivable  from  Managing  General    347,655   342,286
Partner
 Oklahoma withholding prepayment         368       313
                                         --------  --------
                                         ------    ------
   Total current assets                  506,545   471,589
                                         --------  --------
                                         ------    ------
Oil  and  gas properties - using  the
full-
 cost method of accounting               8,549,33  8,547,31
                                         2         7
  Less accumulated depreciation,
   depletion and amortization            6,270,22  6,245,11
                                         7         4
                                         --------  --------
                                         ------    ------
   Net oil and gas properties            2,279,10  2,302,20
                                         5         3
                                         --------  --------
                                         ------    ------
                                      $  2,785,65  2,773,79
                                         0         2
                                         ========  ========
Liabilities and Partners' Equity
-------------------------------------
---

Current liability:
 Distribution payable                 $  8,598     -
                                         --------  --------
                                         ------    ------

Asset retirement obligation              509,557   501,653
                                         --------  --------
                                         ------    ------
Partners' equity (deficit):
 General partner                         (627,585  (627,121
                                         )         )
 Limited partners                        2,895,08  2,899,26
                                         0         0
                                         --------  --------
                                         ------    ------
   Total partners' equity                2,267,49  2,272,13
                                         5         9
                                         --------  --------
                                         ------    ------
                                      $  2,785,65  2,773,79
                                         0         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
                                        March 31,
                                      2005      2004
                                     ------    ------
Revenues
-------------
Income    from   net    profits  $  565,429   381,225
interests
Interest                            844       462
Other                               856       250
                                    --------  --------
                                    ---       ---
                                    567,129   381,937
                                    --------  --------
                                    ---       ---
Expenses
-------------
Depreciation,   depletion   and     25,113    27,000
amortization
Accretion expense                   5,889     10,268
General and administrative          40,771    40,284
                                    --------  --------
                                    ---       ---
                                    71,773    77,552
                                    --------  --------
                                    ---       ---
Net income                       $  495,356   304,385
                                    ======    ======
Net income allocated to:

 Managing General Partner        $  49,536    30,438
                                    ======    ======
 Limited partners                $  445,820   273,947
                                    ======    ======
  Per limited partner unit       $   22.29
                                              13.70
                                    ======    ======





















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

                                      Three Months Ended
                                          March 31,
                                        2005      2004
                                       ------    ------
Cash    flows   from    operating
activities:

  Cash received from income  from
net profits
  interests                        $  560,005   324,799
 Cash paid to suppliers               (40,771)  (40,284)
 Interest received                    844       462
 Other                                856       250
                                      --------  --------
                                      --        --
   Net cash provided by operating     520,934   285,227
activities
                                      --------  --------
                                      --        --
Cash    flows   from    financing
activities:

 Distributions to partners            (500,000  (325,000
                                      )         )
 Increase in distribution payable     8,598     -
                                      --------  --------
                                      --        --
Net   cash   used  in   financing     (491,402  (325,000
activities                            )         )
                                      --------  --------
                                      --        --
Net  (decrease) increase in  cash     29,532    (39,773)
and cash equivalents

 Beginning of period                  128,990   234,954
                                      --------  --------
                                      --        --
 End of period                     $  158,522   195,181
                                      ======    ======
Reconciliation of net  income  to
net
    cash  provided  by  operating
activities:

Net income                         $  495,356   304,385

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

   Depreciation,  depletion   and     25,113    27,000
amortization
  Accretion  of asset  retirement     5,889     10,268
obligation
 Increase in receivables              (5,424)   (56,426)
 Increase in payables                 -         -
                                      --------  --------
                                      --        --
Net  cash  provided by  operating  $  520,934   285,227
activities
                                      ======    ======
Noncash  investing and  financing
activities:

Increase   in   oil    and    gas
properties - SFAS No. 143
 additional wells                  $  2,015     -
                                      ======    ======





                 The accompanying notes are an integral
                   part of these financial statements.
                 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 costs (1)     100%      -
Amortization of organization costs      100%      -
Property acquisition costs              100%      -
Gain/loss on property disposition       90%       10%
Operating and administrative costs (2)  90%       10%
Depreciation,      depletion       and
amortization
  of oil and gas properties             90%       10%
All other costs                         90%       10%

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

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

2.   Summary of Significant Accounting Policies
     The interim financial information as of March 31, 2005, and for the
     three   months  ended  March  31,  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 decline 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 March 31, 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 March 31, 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 Partnership's reserve
estimates are prepared by outside consultants.

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

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

<PAGE>
Results of Operations

General Comparison of the Quarters Ended March 31, 2005 and 2004

The  following table provides certain information regarding  performance
factors for the quarters ended March 31, 2005 and 2004:

                          Three Months
                             Ended         Percenta
                                              ge
                           March 31,       Increase
                         2005      2004    (Decreas
                                              e)
                        -----     -----    --------
                                              --
Oil production  in     5,453     5,880     (7%)
barrels
Gas production  in     70,712    58,800    20%
mcf
Total BOE              17,238              10%
                                 15,680
Average price  per  $   51.92              57%
barrel of oil                    33.10
Average price  per  $    5.79              2%
mcf of gas                       5.67
Income  from   net  $  565,429   381,225   48%
profits interests
Partnership         $  500,000   325,000   54%
distributions
Limited    partner  $  450,000   292,500   54%
distributions
Per           unit
distribution    to
limited
 partners           $   22.50              54%
                                 14.63

Number  of limited     20,000    20,000
partner units

Income from net profits

The  Partnership's  income  from  net  profits  interests  increased  to
$565,429  from $381,225 for the quarters ended March 31, 2005 and  2004,
respectively,  an increase of 48%.  The principal factors affecting  the
comparison of the quarters ended March 31, 2005 and 2004 are as follows:

The  average  price  for  a barrel of oil received  by  the  Partnership
increased  during the quarter ended March 31, 2005 as  compared  to  the
quarter ended March 31, 2004 by 57%, or $18.82 per barrel, resulting  in
an  increase  of  approximately $102,600  in  income  from  net  profits
interests.  Oil sales represented 41% of total oil and gas sales  during
the  quarter ended March 31, 2005 as compared to 37% during the  quarter
ended March 31, 2004.

The  average  price  for  an  mcf of gas  received  by  the  Partnership
increased during the same period by 2%, or $.12 per mcf, resulting in an
increase of approximately $8,500 in income from net profits interests.

The  total  increase  in income from net profits interests  due  to  the
change  in  prices received from oil and gas production is approximately
$111,100.  The market price for oil and gas has been extremely  volatile
over  the  past  decade,  and management expects  a  certain  amount  of
volatility to continue in the foreseeable future.

<PAGE>
Oil  production  decreased approximately 427 barrels or  7%  during  the
quarter ended March 31, 2005 as compared to the quarter ended March  31,
2004,  resulting in a decrease of approximately $14,100 in  income  from
net profits interests.

Gas production increased approximately 11,912 mcf or 20% during the same
period, resulting in an increase of approximately $67,500 in income from
net profits interests.

The  net total increase in income from net profits interests due to  the
change  in  production is approximately $53,400.  The  increase  in  gas
volumes  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 competed in the
first quarter 2005.

Lease   operating  costs  and  production  taxes  were  13%  lower,   or
approximately $19,600 less during the quarter ended March  31,  2005  as
compared to the quarter ended March 31, 2004.  Lease operating costs are
lower due to well pulling expenses on several wells in 2004.

Costs and Expenses

Total  costs  and  expenses decreased to $71,773 for the  quarter  ended
March  31,  2005  from  $77,552  for the  same  period  in  2004.   This
represents  a  decrease  of  7%.  The decrease  is  theresult  of  lower
accretion expense and depletion expense, partially offset by an increase
in general and administrative expense.

General  and administrative costs consist of independent accounting  and
engineering  fees,  computer  services, postage,  and  Managing  General
Partner personnel costs.  General and administrative costs increased  1%
or  approximately  $500  during the quarter  ended  March  31,  2005  as
compared to the quarter ended March 31, 2004.

Depletion  expense decreased to $25,113 for the quarter ended March  31,
2005  from  $27,000  for  the same period in 2004.   This  represents  a
decrease  of  7%.  The contributing factor to the decrease in  depletion
expense  is in relation to the BOE depletion rate for the quarter  ended
March  31,  2005, which was $1.46 applied to 17,238 BOE as  compared  to
$1.72  applied  to 15,680 BOE for the same period in  2004.   The  lower
depletion  rate  in  2005  is  due to the  upward  revision  in  reserve
estimates resulting from higher oil and gas prices.

Accretion  expense decreased to $5,889 for the quarter ended  March  31,
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>
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 $520,900
in  the  quarter  ended  March  31, 2005 as  compared  to  approximately
$285,200 in the quarter ended March 31, 2004.

Cash  flows used in financing activities were approximately $491,400  in
the  quarter ended March 31, 2005 as compared to approximately  $325,000
in  the  quarter  ended  March 31, 2004.   The  only  use  in  financing
activities was the distributions to partners.

Total  distributions  during  the quarter  ended  March  31,  2005  were
$500,000  of  which  $450,000 ($22.50 per unit) was distributed  to  the
limited   partners   and   $50,000  to  the  general   partner.    Total
distributions during the quarter ended March 31, 2004 were  $325,000  of
which $292,500 ($14.63 per unit) was distributed to the limited partners
and $32,500 to the general partner.

The  source  for  the 2005 distributions of $500,000  was  oil  and  gas
operations  of  approximately $520,900, resulting  in  excess  cash  for
contingencies  or  subsequent distributions. The  source  for  the  2004
distributions  of  $325,000 was oil and gas operations of  approximately
$285,200,  with the balance from available cash on hand at the beginning
of the period.

Cumulative  cash  distributions of $19,828,986 have  been  made  to  the
general  and  limited  partners.  As of March 31, 2005,  $17,861,791  or
$893.09  per  limited partner unit has been distributed to  the  limited
partners, representing a 179% return of the capital contributed.

As  of  March  31, 2005, the Partnership had approximately  $497,900  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 quarter  ended  March  31,
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:  May 16, 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:  May 16, 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:  May 16, 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 March 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

                                   May 16, 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

                                   May 16, 2005