FORM 10-K405

                 SECURITIES AND EXCHANGE COMMISSION
                       Washington, D.C.  20549

          Annual Report Pursuant to Section 13 or 15(d) of
                 the Securities Exchange Act of 1934

For the fiscal year ended December 31, 1999

Commission File Number 0-12052

                   DYCO OIL AND GAS PROGRAM 1983-1
                       (A LIMITED PARTNERSHIP)
       (Exact name of registrant as specified in its charter)

           Minnesota                                  41-1451945
(State or other jurisdiction of                    (I.R.S. Employer
incorporation or organization)                   Identification Number)

         Samson Plaza
   Two West Second Street
        Tulsa, Oklahoma                                  74103
     (Address of principal                             (Zip Code)
      executive offices)

Registrant's telephone number, including area code: (918) 583-1791

Securities registered pursuant to Section 12(b) of the Act:  None.

Securities registered pursuant to Section 12(g) of the Act:
      Units of limited partnership interest

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

      Indicate by check mark if disclosure of delinquent filers pursuant to Item
405 of Regulation S-K is not contained herein, and will not be contained, to the
best of registrant's  knowledge,  in definitive proxy or information  statements
incorporated  by reference in Part III of this Form 10-K405 or any  amendment to
this Form 10-K405. [X]

      The units of  limited  partnership  are not  publicly  traded,  therefore,
registrant cannot compute the aggregate market value of the voting units held by
non-affiliates of the registrant.

      DOCUMENTS INCORPORATED BY REFERENCE:  None.




                                      -1-
<PAGE>





                            FORM 10-K405

                   DYCO OIL AND GAS PROGRAM 1983-1
                  (a Minnesota limited partnership)


                          TABLE OF CONTENTS


PART I.........................................................................3
      ITEM 1.   BUSINESS.......................................................3
      ITEM 2.   PROPERTIES.....................................................7
      ITEM 3.   LEGAL PROCEEDINGS.............................................11
      ITEM 4.   SUBMISSION OF MATTERS TO A VOTE OF LIMITED PARTNERS...........11

PART II.......................................................................11
      ITEM 5.   MARKET FOR THE REGISTRANT'S LIMITED PARTNERSHIP UNITS
                AND RELATED LIMITED PARTNER MATTERS. .........................11
      ITEM 6.   SELECTED FINANCIAL DATA.......................................12
      ITEM 7.   MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION
                AND RESULTS OF OPERATIONS.....................................14
      ITEM 7A.  QUANTITATIVE AND QUALITATIVE DISCLOSURES
                ABOUT MARKET RISK.............................................18
      ITEM 8.   FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA...................19
      ITEM 9.   CHANGES IN AND DISAGREEMENTS WITH ACCOUNTANTS ON
                ACCOUNTING AND FINANCIAL DISCLOSURE...........................30

PART III......................................................................30
      ITEM 10.  DIRECTORS AND EXECUTIVE OFFICERS OF THE REGISTRANT............30
      ITEM 11.  EXECUTIVE COMPENSATION........................................31
      ITEM 12.  SECURITY OWNERSHIP OF CERTAIN BENEFICIAL OWNERS
                AND MANAGEMENT................................................35
      ITEM 13.  CERTAIN RELATIONSHIPS AND RELATED TRANSACTIONS................35

PART IV.......................................................................37
      ITEM 14.  EXHIBITS, FINANCIAL STATEMENT SCHEDULES, AND REPORTS
                ON FORM 8-K ..................................................37
SIGNATURES....................................................................39





                                      -2-
<PAGE>






                                     PART I


ITEM 1.    BUSINESS

      General

      The Dyco Oil and Gas Program 1983-1 Limited Partnership (the "Program") is
a Minnesota  limited  partnership  engaged in the production of oil and gas. The
Program  commenced  operations  on July  1,  1983  with  the  primary  financial
objective of investing its limited  partners'  subscriptions  in the drilling of
oil  and gas  prospects  and  then  distributing  to its  limited  partners  all
available  cash flow from the Program's  on-going  production  operations.  Dyco
Petroleum Corporation ("Dyco") serves as the General Partner of the Program. See
"Item 2. Properties" for a description of the Program's reserves and properties.

      The  limited   partnership   agreement   for  the  Program  (the  "Program
Agreement")  provides  that limited  partners are  allocated  99% of all Program
costs and revenues and Dyco, as General Partner,  is allocated 1% of all Program
costs and  revenues.  Included in such costs is the Program's  reimbursement  to
Dyco of the Program's proportionate share of Dyco's geological, engineering, and
general and administrative expenses.

      Dyco  currently  serves as General  Partner  of 31  limited  partnerships,
including the Program.  Dyco is a wholly-owned  subsidiary of Samson  Investment
Company.  Samson  Investment  Company  and its various  corporate  subsidiaries,
including Dyco, (collectively, "Samson") are primarily engaged in the production
and  development of and exploration for oil and gas reserves and the acquisition
and  operation of  producing  properties.  At December  31,  1999,  Samson owned
interests in approximately  14,000 oil and gas wells located in 17 states of the
United States and the countries of Canada,  Venezuela,  and Russia.  At December
31, 1999,  Samson operated  approximately  3,400 oil and gas wells located in 15
states of the United States, as well as Canada, Venezuela, and Russia.

      As a limited  partnership,  the Program  has no  officers,  directors,  or
employees. It relies instead on the personnel of Dyco and Samson. As of March 1,
2000,  Samson employed  approximately  920 persons.  No employees are covered by
collective bargaining agreements, and management believes that Samson provides a
sound employee relations  environment.  For information  regarding the executive
officers  of Dyco,  see  "Item  10.  Directors  and  Executive  Officers  of the
Registrant."

      Dyco's and the Program's  principal place of business is located at Samson
Plaza, Two West Second Street, Tulsa, Oklahoma 74103, and their telephone number
is (918) 583-1791 or (800) 283-1791.



                                      -3-
<PAGE>




      Funding

      Although the Program  Agreement  permits the Program to incur  borrowings,
the Program's  operations and expenses are currently funded out of the Program's
revenues from oil and gas sales. Dyco may, but is not required to, advance funds
to  the  Program  for  the  same  purposes  for  which  Program  borrowings  are
authorized.


      Principal Products Produced and Services Rendered

      The Program's sole business is the  development  and production of oil and
gas with a  concentration  on gas.  The  Program  does  not  hold  any  patents,
trademarks,  licenses,  or  concessions  and is not a  party  to any  government
contracts.  The  Program  has no backlog of orders and does not  participate  in
research and development  activities.  The Program is not presently encountering
shortages of oilfield tubular goods, compressors,  production material, or other
equipment.


      Oil, Gas, and Environmental Control Regulations

      Regulation  of Production  Operations -- The  production of oil and gas is
subject to  extensive  federal and state laws and  regulations  governing a wide
variety of matters, including the drilling and spacing of wells, allowable rates
of  production,  prevention  of  waste  and  pollution,  and  protection  of the
environment.  In  addition  to the direct  costs  borne in  complying  with such
regulations,  operations and revenues may be impacted to the extent that certain
regulations limit oil and gas production to below economic levels.

      Regulation  of Sales and  Transportation  of Oil and Gas -- Sales of crude
oil and  condensate are made by the Program at market prices and are not subject
to price controls. The sale of gas may be subject to both federal and state laws
and  regulations.  The provisions of these laws and  regulations are complex and
affect all who  produce,  resell,  transport,  or purchase  gas,  including  the
Program.  Although  virtually all of the Program's gas production is not subject
to  price  regulation,   other  regulations   affect  the  availability  of  gas
transportation services and the ability of gas consumers to continue to purchase
or use gas at current levels. Accordingly,  such regulations may have a material
effect  on the  Program's  operations  and  projections  of  future  oil and gas
production and revenues.

      Future  Legislation --  Legislation  affecting the oil and gas industry is
under  constant  review  for  amendment  or  expansion.  Because  such  laws and
regulations  are frequently  amended or  reinterpreted,  management is unable to
predict what  additional  energy  legislation  may be proposed or enacted or the
future cost and impact of complying with existing or future regulations.



                                      -4-
<PAGE>




      Regulation of the  Environment -- The Program's  operations are subject to
numerous laws and  regulations  governing  the  discharge of materials  into the
environment or otherwise relating to environmental  protection.  Compliance with
such  laws  and  regulations,   together  with  any  penalties   resulting  from
noncompliance,  may increase the cost of the Program's  operations or may affect
the  Program's  ability  to  timely  complete  existing  or  future  activities.
Management  anticipates  that various local,  state,  and federal  environmental
control agencies will have an increasing impact on oil and gas operations.


      Significant Customers

      Purchases of gas by El Paso Energy Marketing Company ("El Paso") accounted
for  approximately  92.2% of the Program's oil and gas revenues  during the year
ended  December  31,  1999.  In the event of  interruption  of purchases by this
significant  customer or the  cessation or material  change in  availability  of
open-access  transportation by the Program's pipeline transporters,  the Program
may encounter  difficulty in marketing its gas and in maintaining historic sales
levels. Alternative purchasers or transporters may not be readily available.

      The Program's  principal  customers for crude oil  production are refiners
and other companies which have pipeline facilities near the producing properties
of the Program. In the event pipeline facilities are not conveniently  available
to  production  areas,  crude oil is usually  trucked by  purchasers  to storage
facilities.


      Competition and Marketing

      The  domestic  oil and gas  industry is highly  competitive,  with a large
number of companies and  individuals  engaged in the exploration and development
of oil and gas properties.  The ability of the Program to produce and market oil
and gas profitably depends on a number of factors that are beyond the control of
the Program.  These factors include worldwide political instability  (especially
in oil-producing regions), United Nations export embargoes, the supply and price
of foreign  imports of oil and gas, the level of consumer  product demand (which
can be heavily  influenced  by weather  patterns),  government  regulations  and
taxes,  the price and  availability of alternative  fuels,  the overall economic
environment,  and the availability and capacity of transportation and processing
facilities.  The effect of these  factors on future oil and gas industry  trends
cannot be accurately predicted or anticipated.

      The most important variable affecting the Program's revenues is the prices
received for the sale of oil and gas.  Predicting future prices is not possible.
Concerning past trends, average




                                      -5-
<PAGE>




yearly  wellhead  gas prices in the United  States have been  volatile  for many
years.  Over the past ten years such average  prices have  generally been in the
$1.40 to $2.40 per Mcf range.  Gas prices are currently in the upper end of this
range.

      Substantially  all of the  Program's  gas  reserves  are being sold on the
"spot  market."  Prices on the spot  market  are  subject to wide  seasonal  and
regional pricing  fluctuations due to the highly  competitive nature of the spot
market. In addition,  such spot market sales are generally  short-term in nature
and are dependent  upon the  obtaining of  transportation  services  provided by
pipelines.  Spot prices for the Program's gas increased from approximately $1.93
per Mcf at December  31,  1998 to  approximately  $2.24 per Mcf at December  31,
1999.  Such prices  were on an MMBTU  basis and differ from the prices  actually
received  by  the  Program  due  to  transportation  and  marketing  costs,  BTU
adjustments, and regional price and quality differences.

      For the past ten years,  average  oil prices  have  generally  been in the
$16.00 to $24.00 per barrel  range,  but have been  extremely  volatile over the
past two  years.  Due to  global  consumption  and  supply  trends  as well as a
slowdown in Asian energy demand,  oil prices in late 1997 and early 1998 reached
historically low levels,  dropping to as low as approximately  $9.00 per barrel.
However,  production  curtailment  agreements among major oil producing  nations
have  caused  recent  oil  prices  to climb to over  $30.00  per  barrel in some
markets.  It is not known  whether  this  trend  will  continue.  Prices for the
Program's oil increased from approximately $9.50 per barrel at December 31, 1998
to approximately $22.75 per barrel at December 31, 1999.

      Future  prices  for both oil and gas will  likely  be  different  from the
prices in effect on December 31, 1999.  Management is unable to predict  whether
future oil and gas prices will (i) stabilize, (ii) increase, or (iii) decrease.


      Insurance Coverage

      The Program is subject to all of the risks inherent in the exploration for
and production of oil and gas, including blowouts,  pollution,  fires, and other
casualties.  The  Program  maintains  insurance  coverage  as is  customary  for
entities of a similar size engaged in operations similar to that of the Program,
but losses can occur from uninsurable  risks or in amounts in excess of existing
insurance  coverage.  The  occurrence  of an event which is not fully covered by
insurance  could have a material  adverse effect on the financial  condition and
results of operations.




                                      -6-
<PAGE>




ITEM 2.         PROPERTIES

      Well Statistics

      The  following  table sets forth the  numbers of gross and net  productive
wells of the Program as of December 31, 1999.

                         Well Statistics(1)
                       As of December 31, 1999

               Gross productive wells(2):
                 Oil                               1
                 Gas                              18
                                                  --
                   Total                          19

               Net productive wells(3):
                 Oil                             .08
                 Gas                            2.77
                                                ----
                   Total                        2.85
----------
(1)   The designation of a well as an oil well or gas well is made by Dyco based
      on the relative amount of oil and gas reserves for the well. Regardless of
      a well's oil or gas designation,  it may produce oil, gas, or both oil and
      gas.
(2)   As used  throughout  this Annual  Report on Form 10-K  ("Annual  Report"),
      "Gross  Well" refers to a well in which a working  interest is owned.  The
      number  of gross  wells is the  total  number  of wells in which a working
      interest is owned.
(3)   As used throughout this Annual Report, "Net Well" refers to the sum of the
      fractional  working  interests  owned in gross wells.  For example,  a 15%
      working interest in a well represents one Gross Well, but 0.15 Net Well.


      Drilling Activities

      The  Program  participated  in no drilling  activities  for the year ended
December 31, 1999.


      Oil and Gas Production, Revenue, and Price History

      The following table sets forth certain historical  information  concerning
the oil  (including  condensates)  and  gas  production,  net of all  royalties,
overriding royalties, and other third party interests, of the Program,  revenues
attributable to such production, and certain price and cost information.



                                      -7-
<PAGE>



                         Net Production Data

                                   Year Ended December 31,
                              ---------------------------------
                                1999         1998        1997
                              --------    ---------   ---------
Production:
   Oil (Bbls)(1)                  385          349         483
   Gas (Mcf)(2)               231,266      355,374     463,318

Oil and gas sales:
   Oil                       $  6,533     $  4,493    $  9,503
   Gas                        455,514      666,457     961,249
                              -------      -------     -------

     Total                   $462,047     $670,950    $970,752
                              =======      =======     =======

Total direct operating
   Expenses(3)               $148,255     $177,230    $249,406

Direct operating expenses
   as a percentage of oil
   and gas sales                32.1%        26.4%       25.7%

Average sales price:
   Per barrel of oil           $16.97       $12.87      $19.67
   Per Mcf of gas                1.97         1.88        2.07

Direct operating expenses
   per equivalent Mcf of
   gas(4)                      $  .63       $  .50      $  .53

----------

(1)   As used throughout this Annual Report, "Bbls" refers to barrels of 42 U.S.
      gallons and  represents  the basic unit for  measuring  the  production of
      crude oil and condensate oil.
(2)   As used  throughout  this Annual  Report,  "Mcf" refers to volume of 1,000
      cubic feet under  prescribed  conditions of pressure and  temperature  and
      represents the basic unit for measuring the production of gas.
(3)   Includes lease operating expenses and production taxes.
(4)   Oil production is converted to gas  equivalents at the rate of six Mcf per
      barrel, representing the estimated relative energy content of gas and oil,
      which rate is not  necessarily  indicative of the  relationship of oil and
      gas prices.  The  respective  prices of oil and gas are affected by market
      and other factors in addition to relative energy content.




                                      -8-
<PAGE>



      Proved Reserves and Net Present Value

      The following table sets forth the Program's  estimated proved oil and gas
reserves and net present value  therefrom as of December 31, 1999.  The schedule
of  quantities of proved oil and gas reserves was prepared by Dyco in accordance
with the rules prescribed by the Securities and Exchange Commission (the "SEC").
Certain reserve  information was reviewed by Ryder Scott Company,  L.P.  ("Ryder
Scott"),  an independent  petroleum  engineering  firm. As used  throughout this
Annual Report,  "proved reserves" refers to those estimated  quantities of crude
oil, gas, and gas liquids which geological and engineering data demonstrate with
reasonable  certainty to be  recoverable  in future years from known oil and gas
reservoirs under existing economic and operating conditions.

      Net present  value  represents  estimated  future gross cash flow from the
production and sale of proved reserves,  net of estimated oil and gas production
costs (including  production  taxes, ad valorem taxes, and operating  expenses),
and estimated future development costs, discounted at 10% per annum. Net present
value  attributable to the Program's proved reserves was calculated on the basis
of current costs and prices at December 31, 1999. Such prices were not escalated
except in  certain  circumstances  where  escalations  were  fixed  and  readily
determinable in accordance with applicable contract provisions.  The prices used
by Dyco in  calculating  the net present  value  attributable  to the  Program's
proved  reserves  do not  necessarily  reflect  market  prices  for  oil and gas
production  subsequent to December 31, 1999.  There can be no assurance that the
prices  used in  calculating  the net  present  value  of the  Program's  proved
reserves at December 31, 1999 will actually be realized for such production.

      The process of  estimating  oil and gas  reserves  is  complex,  requiring
significant  subjective  decisions in the  evaluation  of available  geological,
engineering,  and  economic  data  for  each  reservoir.  The  data  for a given
reservoir may change substantially over time as a result of, among other things,
additional development activity, production history, and viability of production
under varying economic conditions;  consequently, it is reasonably possible that
material  revisions to existing reserve  estimates may occur in the near future.
Although  every  reasonable  effort has been made to ensure  that these  reserve
estimates represent the most accurate assessment  possible,  the significance of
the  subjective  decisions  required and variances in available data for various
reservoirs  make these  estimates  generally  less precise than other  estimates
presented in connection with financial statement disclosures.




                                      -9-
<PAGE>



                               Proved Reserves and
                                Net Present Value
                              From Proved Reserves

                           As of December 31, 1999(1)

           Estimated proved reserves:
             Gas (Mcf)                         1,170,297
             Oil and liquids (Bbls)                3,185

           Net present value
             (discounted at 10% per annum)    $  906,220

----------------
(1)   Includes certain gas balancing adjustments which cause the gas volumes and
      net present value to differ from the reserve reports  prepared by Dyco and
      reviewed by Ryder Scott.

      No estimates  of the proved  reserves of the Program  comparable  to those
included  herein have been included in reports to any federal  agency other than
the SEC.  Additional  information  relating to the Program's  proved reserves is
contained in Note 4 to the Program's financial statements, included in Item 8 of
this Annual Report.


      Significant Properties

      As of December 31, 1999,  the Program's  properties  consisted of 19 gross
(2.85 net) productive wells. The Program also owned a non-working interest in an
additional  4 wells.  Affiliates  of the  Program  operate 17 (74%) of its total
wells.  All of the Program's  properties are located  onshore in the continental
United States.  Substantially  all of the Program's  reserves are located in the
Anadarko  Basin  of  western  Oklahoma  and the  Texas  panhandle,  which  is an
established oil and gas producing basin.

      As of December 31, 1999,  the Program's  properties in the Anadarko  Basin
consisted  of 18 gross (2.52 net) wells.  The Program  also owned a  non-working
interest in an  additional  4 wells in the  Anadarko  Basin.  Affiliates  of the
Program  operate 16 (73%) of its total Anadarko Basin wells.  As of December 31,
1999, the Program had estimated  total proved  reserves in the Anadarko Basin of
approximately 1,148,402 Mcf of gas and approximately 3,185 barrels of crude oil,
with a present value  (discounted at 10% per annum) of estimated future net cash
flow of approximately $893,510.


      Title to Oil and Gas Properties

      Management believes that the Program has satisfactory title to its oil and
gas properties. Record title to substantially all of the Program's properties is
held by Dyco as nominee.




                                      -10-
<PAGE>





      Title  to the  Program's  properties  is  subject  to  customary  royalty,
overriding  royalty,   carried,   working,   and  other  similar  interests  and
contractual  arrangements  customary in the oil and gas  industry,  to liens for
current taxes not yet due, and to other  encumbrances.  Management believes that
such burdens do not materially detract from the value of such properties or from
the Program's  interest  therein or materially  interfere  with their use in the
operation of the Program's business.


ITEM 3.    LEGAL PROCEEDINGS

      To the knowledge of the management of Dyco and the Program,  neither Dyco,
the Program,  nor the Program's  properties are subject to any  litigation,  the
results  of which  would  have a  material  effect  on the  Program's  or Dyco's
financial condition or operations.


ITEM 4.    SUBMISSION OF MATTERS TO A VOTE OF LIMITED PARTNERS

      There were no matters  submitted to a vote of the limited  partners during
1999.


                                    PART II

ITEM 5.    MARKET FOR THE REGISTRANT'S LIMITED PARTNERSHIP UNITS AND
           RELATED LIMITED PARTNER MATTERS

      The Program does not have an  established  trading market for its units of
limited  partnership  interest  ("Units").  Pursuant to the terms of the Program
Agreement, Dyco, as General Partner, is obligated to annually issue a repurchase
offer which is based on the  estimated  future net revenues  from the  Program's
reserves and is calculated pursuant to the terms of the Program Agreement.  Such
repurchase offer is recalculated  monthly in order to reflect cash distributions
made to the limited partners and extraordinary  events. The following table sets
forth,  for the  periods  indicated,  Dyco's  repurchase  offer per Unit and the
amount of the Program's  cash  distributions  per Unit for the same period.  For
purposes of this Annual Report,  a Unit  represents an initial  subscription  of
$5,000 to a Program.



                                      -11-
<PAGE>




                            Repurchase         Cash
                               Price       Distributions
                            ----------     -------------
        1998:
          First Quarter       $ 98              $35
          Second Quarter        63                -
          Third Quarter        136               40
          Fourth Quarter        96                -

        1999:
          First Quarter       $ 96              $20
          Second Quarter        76                -
          Third Quarter        100                -
          Fourth Quarter       100               20

        2000:
          First Quarter       $ 80              $ -

----------

      As of  March  1,  2000,  the  Program  has  7,600  Units  outstanding  and
approximately 2,350 Limited Partners of record.


ITEM 6.    SELECTED FINANCIAL DATA


      The following table presents selected financial data for the Program. This
data should be read in conjunction with the financial statements of the Program,
and the respective notes thereto,  included elsewhere in this Annual Report. See
"Item 8. Financial Statements and Supplementary Data."





                                      -12-
<PAGE>

<TABLE>
<CAPTION>


                                                        December 31,
                                -----------------------------------------------------------
                                  1999          1998        1997        1996         1995
                                ---------    ----------  ----------  ----------   ----------
<S>                             <C>          <C>         <C>         <C>          <C>
Summary of Operations:
   Oil and gas sales            $462,047     $670,950    $970,752    $1,518,645   $  596,733
   Total revenues                467,513      680,566     981,003     1,530,215      605,334

   Lease operating
     expenses                    114,199      129,506     176,430       180,175      236,512
   Production taxes               34,056       47,724      72,976       111,260       47,823
   General and administrative
     expenses                     88,144       88,278      94,713        90,624       92,351
   Depreciation, depletion,
     and amortization of oil
     and gas properties           66,877      122,695     195,461       213,951      116,583

   Net income                    164,237      292,363     441,423       934,205      112,065
     per Unit                      21.40        38.09       57.51        121.70        14.60
   Cash distributions            307,040      575,700     729,220       767,600      230,280
     per Unit                         40           75          95           100           30

Summary Balance Sheet Data:
   Total assets                  462,450      608,912     912,798     1,228,713    1,141,415
   Partners' capital             313,647      456,450     739,787     1,027,584      860,979

</TABLE>


                                      -13-
<PAGE>



ITEM 7.    MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION
           AND RESULTS OF OPERATIONS

      Use of Forward-Looking Statements and Estimates

      This Annual Report contains certain forward-looking  statements. The words
"anticipate,"  "believe,"  "expect,"  "plan," "intend,"  "estimate,"  "project,"
"could," "may," and similar expressions are intended to identify forward-looking
statements.  Such statements reflect  management's current views with respect to
future  events and  financial  performance.  This Annual  Report  also  includes
certain information which is, or is based upon, estimates and assumptions.  Such
estimates and assumptions  are  management's  efforts to accurately  reflect the
condition and operation of the Program.

      Use of  forward-looking  statements and estimates and assumptions  involve
risks and uncertainties which include, but are not limited to, the volatility of
oil and gas prices, the uncertainty of reserve  information,  the operating risk
associated with oil and gas properties  (including the risk of personal  injury,
death, property damage, damage to the well or producing reservoir, environmental
contamination,  and other  operating  risks),  the  prospect of changing tax and
regulatory laws, the availability and capacity of processing and  transportation
facilities,  the  general  economic  climate,  the  supply  and price of foreign
imports of oil and gas, the level of consumer product demand,  and the price and
availability  of  alternative  fuels.  Should  one or more  of  these  risks  or
uncertainties  occur  or  should  estimates  or  underlying   assumptions  prove
incorrect,  actual  conditions or results may vary materially and adversely from
those stated, anticipated, believed, estimated, or otherwise indicated.


      General Discussion

      The following  general  discussion  should be read in conjunction with the
analysis of results of operations  provided below.  The most important  variable
affecting the Program's  revenues is the prices received for the sale of oil and
gas. Predicting future prices is not possible.  Concerning past trends,  average
yearly  wellhead  gas prices in the United  States have been  volatile  for many
years.  Over the past ten years such average  prices have  generally been in the
$1.40 to $2.40 per Mcf range.  Gas prices are currently in the upper end of this
range.

      Substantially  all of the  Program's  gas  reserves  are being sold on the
"spot  market."  Prices on the spot  market  are  subject to wide  seasonal  and
regional pricing  fluctuations due to the highly  competitive nature of the spot
market. In addition,  such spot market sales are generally  short-term in nature
and are dependent  upon the  obtaining of  transportation  services  provided by
pipelines.  Spot prices for the Program's gas increased from approximately $1.93
per Mcf at December 31, 1998 to approximately



                                      -14-
<PAGE>



$2.24 per Mcf at  December  31,  1999.  Such  prices  were on an MMBTU basis and
differ from the prices  actually  received by the Program due to  transportation
and  marketing  costs,   BTU   adjustments,   and  regional  price  and  quality
differences.

      For the past ten years,  average  oil prices  have  generally  been in the
$16.00 to $24.00 per barrel  range,  but have been  extremely  volatile over the
past two  years.  Due to  global  consumption  and  supply  trends  as well as a
slowdown in Asian energy demand,  oil prices in late 1997 and early 1998 reached
historically low levels,  dropping to as low as approximately  $9.00 per barrel.
However,  production  curtailment  agreements among major oil producing  nations
have  caused  recent  oil  prices  to climb to over  $30.00  per  barrel in some
markets.  It is not known  whether  this  trend  will  continue.  Prices for the
Program's oil increased from approximately $9.50 per barrel at December 31, 1998
to approximately $22.75 per barrel at December 31, 1999.

      Future  prices  for both oil and gas will  likely  be  different  from the
prices in effect on December 31, 1999.  Management is unable to predict  whether
future oil and gas prices will (i) stabilize, (ii) increase, or (iii) decrease.

      Results of Operations

                      Year Ended December 31, 1999 Compared
                         to Year Ended December 31, 1998
                      -------------------------------------

      Total oil and gas sales decreased  $208,903 (31.1%) in 1999 as compared to
1998.  Of this  decrease,  approximately  $233,000  was related to a decrease in
volumes of gas sold. This decrease was partially offset by approximately $22,000
related to an  increase in the  average  price of gas sold.  Volumes of oil sold
increased 36 barrels, while volumes of gas sold decreased 124,108 Mcf in 1999 as
compared to 1998.  The decrease in volumes of gas sold was  primarily due to the
curtailment of sales during 1999 on two wells due to the Program's  overproduced
gas balancing  position in those wells.  Average oil and gas prices increased to
$16.97  per  barrel  and $1.97 per Mcf,  respectively,  in 1999 from  $12.87 per
barrel and $1.88 per Mcf, respectively, in 1998.

      Oil and gas production  expenses  (including lease operating  expenses and
production  taxes)  decreased  $28,975 (16.3%) in 1999 as compared to 1998. This
decrease  was  primarily  due to (i) a  decrease  in  lease  operating  expenses
associated  with the  decrease  in  volumes  of gas  sold,  (ii) a  decrease  in
production  taxes  associated with the decrease in oil and gas sales,  and (iii)
workover  expenses  incurred  on two wells  during  1998 in order to improve the
recovery of reserves.  These decreases were partially  offset by new compression
expenses  incurred on one well in 1999.  As a  percentage  of oil and gas sales,
these expenses  increased to 32.1% in 1999 from 26.4% in 1998.  This  percentage
increase was primarily due to the 1999 compression expenses.




                                      -15-
<PAGE>





      Depreciation,  depletion,  and  amortization  of oil  and  gas  properties
decreased  $55,818  (45.5%)  in 1999 as  compared  to 1998.  This  decrease  was
primarily  due to (i) the  decrease in volumes of gas sold,  (ii) an increase in
the gas price used in the valuation of reserves at December 31, 1999,  and (iii)
an upward  revision in the  estimate of  remaining  gas reserves at December 31,
1999. As a percentage of oil and gas sales,  this expense  decreased to 14.5% in
1999 from 18.3% in 1998.  This  percentage  decrease  was  primarily  due to the
dollar decrease in depreciation, depletion, and amortization.

      General and administrative  expenses remained  relatively constant in 1999
as  compared  to 1998.  As a  percentage  of oil and gas sales,  these  expenses
increased  to 19.1% in 1999 from 13.2% in 1998.  This  percentage  increase  was
primarily due to the decrease in oil and gas sales.


                      Year Ended December 31, 1998 Compared
                         to Year Ended December 31, 1997
                      -------------------------------------

      Total oil and gas sales decreased  $299,802 (30.9%) in 1998 as compared to
1997. Of this decrease,  approximately $224,000 was related to a decrease in the
volumes of gas sold and  approximately  $71,000 was related to a decrease in the
average price of gas sold. Volumes of oil and gas sold decreased 134 barrels and
107,944 Mcf, respectively,  in 1998 as compared to 1997. The decrease in volumes
of  gas  sold  resulted  primarily  from  (i) a  positive  prior  period  volume
adjustment  made by the purchaser  during 1997 on one well, (ii) normal declines
in production, and (iii) the shutting-in of one well during a portion of 1998 to
perform a workover in order to improve the recovery of reserves. Average oil and
gas prices  decreased to $12.87 per barrel and $1.88 per Mcf,  respectively,  in
1998 from $19.67 per barrel and $2.07 per Mcf, respectively, in 1997.

      Oil and gas production  expenses  (including lease operating  expenses and
production  taxes)  decreased  $72,176 (28.9%) in 1998 as compared to 1997. This
decrease  resulted  primarily from (i) workover  expenses  incurred on two wells
during 1997 in order to improve the  recovery of reserves and (ii) a decrease in
production  taxes  associated  with the  decrease  in oil and gas  sales.  These
decreases were partially offset by workover expenses incurred on two other wells
during 1998. As a percentage of oil and gas sales,  these expenses  increased to
26.4% in 1998  from  25.7% in  1997.  This  increase  was  primarily  due to the
decreases  in the  average  prices  of oil and gas sold  and the  1998  workover
expenses, which increase was partially offset by the 1997 workover expenses.




                                      -16-
<PAGE>



      Depreciation,  depletion,  and  amortization  of oil  and  gas  properties
decreased  $72,766 (37.2%) in 1998 as compared to 1997.  This decrease  resulted
primarily  from (i) the  decrease  in  volumes  of gas  sold and (ii) an  upward
revision in the  estimate of remaining  gas reserves at December 31, 1998.  As a
percentage  of oil and gas sales,  this expense  decreased to 18.3% in 1998 from
20.1% in 1997.  This  percentage  decrease  resulted  primarily  from the dollar
decrease in depreciation, depletion, and amortization.

      General and  administrative  expenses  decreased  $6,435 (6.8%) in 1998 as
compared to 1997. As a percentage of oil and gas sales, these expenses increased
to 13.2% in 1998 from 9.8% in 1997. This  percentage  increase was primarily due
to the decrease in oil and gas sales.


      Liquidity and Capital Resources

      Net  proceeds  from  operations  less  necessary   operating  capital  are
distributed to the limited  partners on a quarterly  basis.  See "Item 5. Market
for the  Registrant's  Limited  Partnership  Units and Related  Limited  Partner
Matters."  The net proceeds  from  production  are not  reinvested in productive
assets, except to the extent that producing wells are improved, or where methods
are employed to permit more efficient recovery of reserves, thereby resulting in
a positive  economic impact.  Assuming 1999 production  levels for future years,
the  Program's  proved  reserve  quantities  at  December  31,  1999  would have
remaining  lives of  approximately  5.1 years for gas reserves and 8.3 years for
oil reserves.  However,  since the Program's  reserve estimates are based on oil
and gas prices at December 31, 1999, it is possible that a significant  decrease
in oil and gas prices from  December  31, 1999 levels will reduce such  reserves
and their corresponding life-span.

      The Program's  available capital from the limited partners'  subscriptions
has been spent on oil and gas drilling activities and there should be no further
material capital resource commitments in the future.  Occasional expenditures by
the Program for well completions or workovers,  however, may reduce or eliminate
cash available for a particular quarterly cash distribution.  The Program has no
debt commitments.  Cash for operational  purposes has generally been provided by
current  oil and gas  production.  Management  believes  that cash for  ordinary
operational purposes will be provided by current oil and gas production.

      The Program's  Statements  of Cash Flows for the years ended  December 31,
1999,  1998, and 1997 include  proceeds from the sale of oil and gas properties.
These proceeds were included in the Program's first cash distribution  following
receipt of the proceeds. It is possible that the Program's repurchase values and
the amount or  likelihood  of future  cash  distributions  could be reduced as a
result of the disposition of these properties.



                                      -17-
<PAGE>



There  can  be no  assurance  as to the  amount  of the  Program's  future  cash
distributions.   The  Program's  ability  to  make  cash  distributions  depends
primarily  upon the level of  available  cash flow  generated  by the  Program's
operating  activities,  which will be affected (either positively or negatively)
by many factors  beyond the control of the Program,  including  the price of and
demand for oil and gas and other market and economic conditions.  Even if prices
and costs remain  stable,  the amount of cash available for  distributions  will
decline  over  time (as the  volume  of  production  from  producing  properties
declines) since the Program is not replacing  production through acquisitions of
producing properties and drilling.


      Inflation and Changing Prices

      Prices obtained for oil and gas production  depend upon numerous  factors,
including the extent of domestic and foreign production, foreign imports of oil,
market  demand,  domestic  and  foreign  economic  conditions  in  general,  and
governmental  regulations  and tax laws.  The general  level of inflation in the
economy did not have a material effect on the operations of the Program in 1999.
Oil and gas prices have  fluctuated  during recent years and generally  have not
followed the same pattern as  inflation.  See "Item 2.  Properties - Oil and Gas
Production, Revenue, and Price History."


      Year 2000 Computer Issues

      The year  2000  issue  refers  to the  inability  of  computer  and  other
information  technology  systems to properly process date and time  information,
stemming from the earlier  programming  practice of using two digits rather than
four to represent the year in a date.  To the knowledge of the General  Partner,
the Program has not experienced  any material  effects from the year 2000 issue.
Costs  incurred by the Program in order to ensure year 2000  compatibility  were
not material to the Program.


ITEM 7A.   QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET
           RISK.

      The Program does not hold any market risk sensitive instruments.



                                      -18-
<PAGE>



ITEM 8.    FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA



                  REPORT OF INDEPENDENT ACCOUNTANTS



TO THE PARTNERS

DYCO OIL AND GAS PROGRAM 1983-1 LIMITED PARTNERSHIP


      In our opinion, the accompanying balance sheets and the related statements
of operations,  changes in partners'  capital and cash flows present fairly,  in
all material  respects,  the financial  position of the Dyco Oil and Gas Program
1983-1 Limited  Partnership,  a Minnesota limited  partnership,  at December 31,
1999 and 1998,  and the results of its operations and its cash flows for each of
the three years in the period  ended  December  31,  1999,  in  conformity  with
accounting  principles  generally accepted in the United States. These financial
statements   are  the   responsibility   of  the   Program's   management;   our
responsibility  is to express an opinion on these financial  statements based on
our audits. We conducted our audits of these financial  statements in accordance
with auditing standards  generally accepted in the United States,  which require
that we plan and perform the audit to obtain reasonable  assurance about whether
the financial  statements are free of material  misstatement.  An audit includes
examining,  on a test basis,  evidence supporting the amounts and disclosures in
the  financial   statements,   assessing  the  accounting  principles  used  and
significant  estimates made by management,  and evaluating the overall financial
statement  presentation.  We believe that our audits provide a reasonable  basis
for the opinion expressed above.





                               PricewaterhouseCoopers LLP







Tulsa, Oklahoma
March 24, 2000



                                      -19-
<PAGE>



                      DYCO OIL AND GAS PROGRAM
                     1983-1 LIMITED PARTNERSHIP
                           Balance Sheets
                     December 31, 1999 and 1998

                               ASSETS
                               ------
                                               1999        1998
                                             --------    --------
CURRENT ASSETS:
   Cash and cash equivalents                 $ 76,244    $133,429
   Accrued oil and gas sales                   86,041      70,919
                                              -------     -------
     Total current assets                    $162,285    $204,348

NET OIL AND GAS PROPERTIES, utilizing
   the full cost method                       276,130     367,820

DEFERRED CHARGE                                24,035      36,744
                                              -------     -------
                                             $462,450    $608,912
                                              =======     =======

                  LIABILITIES AND PARTNERS' CAPITAL
                  ---------------------------------

CURRENT LIABILITIES:
   Accounts payable                          $  5,739    $  5,774
   Gas imbalance payable                       20,865       7,689
                                              -------     -------
     Total current liabilities               $ 26,604    $ 13,463

ACCRUED LIABILITY                            $122,199    $138,999

PARTNERS' CAPITAL:
   General Partner, 76 general partner
     Units                                   $  3,137    $  4,565
   Limited Partners, issued and
     outstanding, 7,600 Units                 310,510     451,885
                                              -------     -------
     Total Partners' capital                 $313,647    $456,450
                                              -------     -------

                                             $462,450    $608,912
                                              =======     =======







                     The accompanying notes are an integral
                      part of these financial statements.




                                      -20-
<PAGE>




                      DYCO OIL AND GAS PROGRAM
                     1983-1 LIMITED PARTNERSHIP
                      Statements of Operations
        For the Years Ended December 31, 1999, 1998, and 1997


                                     1999      1998      1997
                                   --------  --------  --------
REVENUES:
   Oil and gas sales               $462,047  $670,950  $970,752
   Interest                           5,466     9,616    10,251
                                    -------   -------   -------
                                   $467,513  $680,566  $981,003

COSTS AND EXPENSES:
   Lease operating                 $114,199  $129,506  $176,430
   Production taxes                  34,056    47,724    72,976
   Depreciation, depletion,
     and amortization of oil
     and gas properties              66,877   122,695   195,461
   General and administrative        88,144    88,278    94,713
                                    -------   -------   -------

                                   $303,276  $388,203  $539,580
                                    -------   -------   -------

NET INCOME                         $164,237  $292,363  $441,423
                                    =======   =======   =======

GENERAL PARTNER (1%) -
   NET INCOME                      $  1,642  $  2,924  $  4,414
                                    =======   =======   =======

LIMITED PARTNERS (99%) -
   NET INCOME                      $162,595  $289,439  $437,009
                                    =======   =======   =======

NET INCOME per Unit                $  21.40  $  38.09  $  57.51
                                    =======   =======   =======

UNITS OUTSTANDING                     7,676     7,676     7,676
                                    =======   =======   =======


                     The accompanying notes are an integral
                      part of these financial statements.




                                      -21-
<PAGE>




                            DYCO OIL AND GAS PROGRAM
                           1983-1 LIMITED PARTNERSHIP
                   Statements of Changes in Partners' Capital
             For the Years Ended December 31, 1999, 1998, and 1997


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

Balances at Dec. 31, 1996     $10,276     $1,017,308    $1,027,584
   Cash distributions        (  7,292)   (   721,928)  (   729,220)
   Net income                   4,414        437,009       441,423
                               ------      ---------     ---------

Balances at Dec. 31, 1997     $ 7,398     $  732,389    $  739,787
   Cash distributions        (  5,757)   (   569,943)  (   575,700)
   Net income                   2,924        289,439       292,363
                               ------      ---------     ---------

Balances at Dec. 31, 1998     $ 4,565     $  451,885    $  456,450
   Cash distributions        (  3,070)   (   303,970)  (   307,040)
   Net income                   1,642        162,595       164,237
                               ------      ---------     ---------

Balances at Dec. 31, 1999     $ 3,137    $  310,510     $  313,647
                               ======      =========     =========




                     The accompanying notes are an integral
                      part of these financial statements.




                                      -22-
<PAGE>




                           DYCO OIL AND GAS PROGRAM
                          1983-1 LIMITED PARTNERSHIP
                           Statements of Cash Flows
             For the Years Ended December 31, 1999, 1998, and 1997

                                            1999        1998        1997
                                         ----------  ----------  ----------
CASH FLOWS FROM OPERATING ACTIVITIES:
   Net income                            $ 164,237    $292,363    $441,423
   Adjustments to reconcile net
     income to net cash provided
     by operating activities:
     Depreciation, depletion, and
       amortization of oil and gas
       properties                           66,877     122,695     195,461
     (Increase) decrease in accrued
       oil and gas sales                 (  15,122)     72,406      94,505
     (Increase) decrease in
       deferred charge                      12,709   (  10,039)      4,497
     Decrease in accounts payable        (      35)  (   2,262)  (   9,493)
     Increase (decrease) in gas
       imbalance payable                    13,176   (  15,345)  (  34,487)
     Increase (decrease) in accrued
       liability                         (  16,800)  (   2,942)     15,862
                                           -------     -------     -------
   Net cash provided by operating
     activities                           $225,042    $456,876    $707,768
                                           -------     -------     -------
CASH FLOWS FROM INVESTING ACTIVITIES:
   Proceeds from the sale of oil
     and gas properties                   $ 28,104    $  6,594    $  3,778
   Additions to oil and gas properties   (   3,291)  (  10,832)  (     752)
                                           -------     -------     -------
   Net cash provided (used) by
     investing activities                 $ 24,813   ($  4,238)   $  3,026
                                           -------     -------     -------
CASH FLOWS FROM FINANCING ACTIVITIES:
   Cash distributions                    ($307,040)  ($575,700)  ($729,220)
                                           -------     -------     -------
   Net cash used by financing
     activities                          ($307,040)  ($575,700)  ($729,220)
                                           -------     -------     -------
NET DECREASE IN CASH AND CASH
   EQUIVALENTS                           (  57,185)  ($123,062)  ($ 18,426)

CASH AND CASH EQUIVALENTS AT
   BEGINNING OF PERIOD                     133,429     256,491     274,917
                                           -------     -------     -------
CASH AND CASH EQUIVALENTS AT
   END OF PERIOD                          $ 76,244    $133,429    $256,491
                                           =======     =======     =======



                     The accompanying notes are an integral
                      part of these financial statements.




                                      -23-
<PAGE>




               DYCO OIL AND GAS PROGRAM 1983-1 LIMITED PARTNERSHIP
                          Notes to Financial Statements
              For the Years Ended December 31, 1999, 1998, and 1997

1.    ORGANIZATION AND SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES

      Organization and Nature of Operations

           The  Dyco  Oil  and  Gas  Program  1983-1  Limited  Partnership  (the
      "Program"), a Minnesota limited partnership,  commenced operations on July
      1, 1983. Dyco Petroleum Corporation ("Dyco") is the General Partner of the
      Program.  Affiliates of Dyco owned 3,516 (46.3%) of the Program's Units at
      December 31, 1999.

           The Program's sole business is the  development and production of oil
      and gas with a concentration  on gas.  Substantially  all of the Program's
      gas reserves are being sold  regionally  in the "spot  market." Due to the
      highly  competitive  nature of the spot market,  prices on the spot market
      are  subject  to wide  seasonal  and  regional  pricing  fluctuations.  In
      addition,  such spot market sales are  generally  short-term in nature and
      are dependent upon the obtaining of  transportation  services  provided by
      pipelines.  The prices  received for the Program's oil and gas are subject
      to influences such as global consumption and supply trends.


      Cash and Cash Equivalents

           The Program  considers all highly liquid  investments with a maturity
      of three  months  or less  when  purchased  to be cash  equivalents.  Cash
      equivalents  are not  insured,  which  cause the  Program to be subject to
      risk.


      Credit Risk

           Accrued oil and gas sales which are due from a variety of oil and gas
      purchasers  subject the Program to a concentration of credit risk. Some of
      these purchasers are discussed in Note 3 - Major Customers.


      Oil and Gas Properties

           Oil and gas  operations  are accounted for using the full cost method
      of accounting. All productive and non-productive costs associated with the
      acquisition,  exploration,  and  development  of oil and gas  reserves are
      capitalized.  Capitalized  costs are depleted on a composite gross revenue
      method using  estimates  of proved  reserves.  The full cost  amortization
      rates per equivalent  Mcf of gas produced  during the years ended December
      31, 1999, 1998, and 1997 were $0.29,



                                      -24-
<PAGE>



      $0.34, and $0.42, respectively. The Program's calculation of depreciation,
      depletion,  and amortization  includes estimated future expenditures to be
      incurred in developing  proved  reserves and estimated  dismantlement  and
      abandonment  costs,  net of  estimated  salvage  values.  In the event the
      unamortized  cost of oil and gas properties  being  amortized  exceeds the
      full cost ceiling (as defined by the  Securities  and Exchange  Commission
      ("SEC"))  the excess is charged to expense in the year  during  which such
      excess occurs.  Sales and  abandonments of properties are accounted for as
      adjustments of capitalized  costs with no gain or loss recognized,  unless
      such  adjustments  would  significantly  alter  the  relationship  between
      capitalized costs and proved oil and gas reserves.


      Deferred Charge

           The Deferred  Charge at December 31, 1999 and 1998  represents  costs
      deferred for lease  operating  expenses  incurred in  connection  with the
      Program's  underproduced  gas  imbalance  positions.   The  rate  used  in
      calculating  the deferred  charge is the average of the annual  production
      costs per Mcf. At December 31, 1999,  cumulative  total gas sales  volumes
      for  underproduced  wells were less than the Program's  pro-rata  share of
      total gas production from these wells by 67,779 Mcf,  resulting in prepaid
      lease  operating  expenses of $24,035.  At December 31,  1998,  cumulative
      total  gas  sales  volumes  for  underproduced  wells  were  less than the
      Program's  pro-rata  share of total gas  production  from  these  wells by
      108,583 Mcf, resulting in prepaid lease operating expenses of $36,744.


      Accrued Liability

           The  Accrued  Liability  at  December  31,  1999 and 1998  represents
      charges accrued for lease operating  expenses  incurred in connection with
      the  Program's  overproduced  gas  imbalance  positions.  The rate used in
      calculating the accrued  liability is the average of the annual production
      costs per Mcf. At December 31, 1999,  cumulative  total gas sales  volumes
      for overproduced  wells exceeded the Program's pro-rata share of total gas
      production  from these wells by 344,610 Mcf,  resulting  in accrued  lease
      operating expenses of $122,199. At December 31, 1998, cumulative total gas
      sales volumes for overproduced wells exceeded the Program's pro-rata share
      of total gas  production  from these wells by 410,754  Mcf,  resulting  in
      accrued lease operating expenses of $138,999.




                                      -25-
<PAGE>




      Oil and Gas Sales and Gas Imbalance Payable

           The Program's oil and  condensate  production is sold,  title passed,
      and revenue  recognized  at or near the Program's  wells under  short-term
      purchase  contracts at prevailing  prices in accordance with  arrangements
      which are  customary in the oil industry.  Sales of gas  applicable to the
      Program's interest in producing oil and gas leases are recorded as revenue
      when the gas is metered  and title  transferred  pursuant to the gas sales
      contracts  covering the Program's  interest in gas  reserves.  During such
      times as the  Program's  sales of gas exceed its pro rata  ownership  in a
      well,  such sales are recorded as revenue unless total sales from the well
      have  exceeded  the  Program's  share  of  estimated  total  gas  reserves
      underlying  the  property  at which  time  such  excess is  recorded  as a
      liability. The rates per Mcf used to calculate this liability are based on
      the  average  gas  prices  received  for  the  volumes  at  the  time  the
      overproduction  occurred.  At December 31, 1999,  total sales exceeded the
      Program's  share of  estimated  total gas  reserves on one well by $20,865
      (13,910 Mcf).  These  amounts were  recorded as gas imbalance  payables in
      accordance  with the sales  method.  At  December  31,  1998,  total sales
      exceeded the Program's  share of estimated  total gas reserves on one well
      by $7,689 (5,126 Mcf).


      Use of Estimates in Financial Statements

           The preparation of financial  statements in conformity with generally
      accepted  accounting  principles requires management to make estimates and
      assumptions that affect the reported amounts of assets and liabilities and
      disclosure  of  contingent  assets  and  liabilities  at the  date  of the
      financial  statements  and the  reported  amounts of revenues and expenses
      during the  reporting  period.  Actual  results  could  differ  from those
      estimates.  Further,  the deferred charge, the gas imbalance payable,  and
      the accrued  liability all involve estimates which could materially differ
      from the actual amounts ultimately  realized or incurred in the near term.
      Oil and gas reserves (see Note 4) also involve significant estimates which
      could materially differ from the actual amounts ultimately realized.


      Income Taxes

           Income or loss for income tax  purposes is  includable  in the income
      tax returns of the partners. Accordingly, no recognition has been given to
      income taxes in the accompanying financial statements.



                                      -26-
<PAGE>



2.    TRANSACTIONS WITH RELATED PARTIES

           Under the terms of the Program Agreement, Dyco is entitled to receive
      a reimbursement  for all direct  expenses and general and  administrative,
      geological,  and engineering  expenses it incurs on behalf of the Program.
      During the years ended December 31, 1999,  1998,  and 1997,  such expenses
      totaled $88,144, $88,278, and $94,713,  respectively, of which $71,280 was
      paid each year to Dyco and its affiliates.

           Affiliates   of  the  Program   operate   certain  of  the  Program's
      properties.  Their policy is to bill the Program for all customary charges
      and cost  reimbursements  associated with these activities,  together with
      any  compressor  rentals,  consulting,  or other services  provided.  Such
      charges are  comparable to third party charges in the area where the wells
      are located and are the same as charged to other working  interest  owners
      in the wells.


3.    MAJOR CUSTOMERS

           The following purchaser individually accounted for 10% or more of the
      combined oil and gas revenues of the Program for the years ended  December
      31, 1999, 1998, and 1997:


           Purchaser              1999     1998     1997
           ---------              -----    -----    -----

           El Paso Energy
             Marketing Company    92.2%    95.0%    95.4%

           In the  event  of  interruption  of  purchases  by  this  significant
      customer  or  the  cessation  or  material   change  in   availability  of
      open-access  transportation by the Program's  pipeline  transporters,  the
      Program may encounter  difficulty in marketing its gas and in  maintaining
      historic sales levels.  Alternative  purchasers or transporters may not be
      readily available.


4.    SUPPLEMENTAL OIL AND GAS INFORMATION

           The  following  supplemental  information  regarding  the oil and gas
      activities  of  the  Program  is  presented  pursuant  to  the  disclosure
      requirements promulgated by the SEC.


      Capitalized Costs

           The  Program's   capitalized  costs  and  accumulated   depreciation,
      depletion,  amortization, and valuation allowance at December 31, 1999 and
      1998 were as follows:



                                      -27-
<PAGE>




                                               December 31,
                                      ----------------------------
                                          1999           1998
                                      -------------  -------------

      Proved properties                $35,503,605    $35,528,418

      Less accumulated depre-
        ciation, depletion,
        amortization, and
        valuation allowance           ( 35,227,475)  ( 35,160,598)
                                        ----------     ----------

      Net oil and gas properties       $   276,130    $   367,820
                                        ==========     ==========


      Costs Incurred

           The  Program  incurred  no  oil  and  gas  property   acquisition  or
      exploration  costs  during 1999,  1998,  and 1997.  Costs  incurred by the
      Program in connection with its oil and gas property development activities
      during 1999, 1998, and 1997 were as follows:

                                           December 31,
                                    -------------------------
                                      1999     1998     1997
                                     ------   ------   ------

      Development costs             $ 3,291  $10,832    $752
                                     ======   ======     ===

      Quantities of Proved Oil and Gas Reserves - Unaudited

           Set forth below is a summary of the changes in the net  quantities of
      the  Program's  proved  crude oil and gas  reserves  for the  years  ended
      December 31, 1999,  1998,  and 1997.  Proved  reserves  were  estimated by
      petroleum  engineers  employed  by  affiliates  of Dyco.  Certain  reserve
      information  was reviewed by Ryder Scott  Company,  L.P.,  an  independent
      petroleum  engineering firm. All of the Program's  reserves are located in
      the  United  States.  The  following   information  includes  certain  gas
      balancing  adjustments  which  cause the gas  volumes  to differ  from the
      reserve information prepared by Dyco and reviewed by Ryder Scott.





                                      -28-
<PAGE>



<TABLE>
<CAPTION>



                                       1999                   1998                    1997
                               --------------------   --------------------    --------------------
                                 Oil        Gas         Oil        Gas          Oil        Gas
                               (Bbls)      (Mcf)      (Bbls)      (Mcf)       (Bbls)      (Mcf)
                               -------  -----------   -------  -----------    -------  -----------
<S>                            <C>      <C>           <C>      <C>            <C>      <C>
Proved reserves,
   beginning of year            1,862    1,303,728     3,077    1,301,980      4,547    1,524,633

Revisions of previous
   estimates                    1,708      100,157    (  866)     377,447     (  987)     230,448

Sale of reserves                  -     (    2,322)     -      (   20,325)      -            -

Extensions and
   discoveries                    -            -        -            -          -          10,217

Production                     (  385)  (  231,266)   (  349)  (  355,374)    (  483)  (  463,318)
                                -----    ---------     -----    ---------      -----    ---------

Proved reserves,
   end of year                  3,185    1,170,297     1,862    1,303,728      3,077    1,301,980
                                =====    =========     =====    =========      =====    =========

Proved developed reserves:
   Beginning of year            1,862    1,303,728     3,077    1,301,980      4,547    1,524,633
                                -----    ---------     -----    ---------      -----    ---------
   End of year                  3,185    1,170,297     1,862    1,303,728      3,077    1,301,980
                                =====    =========     =====    =========      =====    =========

</TABLE>



                                      -29-
<PAGE>




           The process of estimating oil and gas reserves is complex,  requiring
      significant   subjective   decisions  in  the   evaluation   of  available
      geological,  engineering,  and economic data for each reservoir.  The data
      for a given reservoir may change  substantially  over time as a result of,
      among other things,  additional development activity,  production history,
      and  viability  of   production   under   varying   economic   conditions;
      consequently,  it  is  reasonably  possible  that  material  revisions  to
      existing  reserve  estimates may occur in the near future.  Although every
      reasonable  effort  has been made to  ensure  that the  reserve  estimates
      reported  herein  represent the most  accurate  assessment  possible,  the
      significance  of  the  subjective  decisions  required  and  variances  in
      available data for various reservoirs make these estimates  generally less
      precise  than other  estimates  presented  in  connection  with  financial
      statement disclosures.  The Program's reserves were determined at December
      31,  1999 using oil and gas prices of $22.75 per barrel and $2.24 per Mcf,
      respectively.


ITEM 9.    CHANGES IN AND DISAGREEMENTS WITH ACCOUNTANTS ON ACCOUNTING
           AND FINANCIAL DISCLOSURE

      None.


                                    PART III


ITEM 10.   DIRECTORS AND EXECUTIVE OFFICERS OF THE REGISTRANT

      The Program is a limited  partnership  and has no  directors  or executive
officers.  The following  individuals  are  directors and executive  officers of
Dyco, the General Partner.  The business address of such directors and executive
officers is Two West Second Street, Tulsa, Oklahoma 74103.

            NAME         AGE            POSITION WITH DYCO
      ----------------   ---     --------------------------------
      Dennis R. Neill     48     President and Director

      Patrick M. Hall     41     Chief Financial Officer

      Judy K. Fox         49     Secretary

      The  director   will  hold  office  until  the  next  annual   meeting  of
shareholders of Dyco or until his successor has been duly elected and qualified.
All executive officers serve at the discretion of the Board of Directors.

      Dennis R. Neill joined Samson in 1981, was named Senior Vice President and
Director of Dyco on June 18, 1991,  and was named  President of Dyco on June 30,
1996. Prior to joining Samson, he




                                      -30-
<PAGE>




was associated  with a Tulsa law firm,  Conner and Winters,  where his principal
practice was in the  securities  area.  He received a Bachelor of Arts degree in
political  science from Oklahoma State  University and a Juris Doctorate  degree
from the University of Texas.  Mr. Neill also serves as Senior Vice President of
Samson  Investment  Company and as President  and Director of Samson  Properties
Incorporated,  Samson Hydrocarbons Company, Berry Gas Company, Circle L Drilling
Company, Compression, Inc., and Geodyne Resources, Inc. and its subsidiaries.

      Patrick M. Hall joined Samson in 1983,  was named a Vice President of Dyco
on June 18,  1991,  and was named  Chief  Financial  Officer of Dyco on June 30,
1996. Prior to joining Samson he was a senior  accountant with Peat Marwick Main
& Co. in Tulsa.  He holds a  Bachelor  of  Science  degree  in  accounting  from
Oklahoma State  University and is a Certified Public  Accountant.  Mr. Hall also
serves as Senior Vice President - Controller of Samson Investment Company.

      Judy K. Fox joined Samson in 1990 and was named  Secretary of Dyco on June
30, 1996.  Prior to joining Samson,  she served as Gas Contract  Manager for Ely
Energy  Company.  Ms.  Fox is also  Secretary  of Berry  Gas  Company,  Circle L
Drilling  Company,  Compression,   Inc.,  Samson  Hydrocarbons  Company,  Samson
Properties Incorporated, and Geodyne Resources, Inc. and its subsidiaries.


      Section 16(a) Beneficial Ownership Reporting Compliance

      To the best  knowledge  of the Program and Dyco,  there were no  officers,
directors,  or ten  percent  owners who were  delinquent  filers  during 1999 of
reports required under Section 16(a) of the Securities and Exchange Act of 1934.


ITEM 11.   EXECUTIVE COMPENSATION

      The Program is a limited  partnership and,  therefore,  has no officers or
directors.  The following  table  summarizes  the amounts paid by the Program as
compensation and  reimbursements  to Dyco and its affiliates for the three years
ended December 31, 1999:





                                      -31-
<PAGE>




        Compensation/Reimbursement to Dyco and its affiliates
                 Three Years Ended December 31, 1999

Type of Compensation/Reimbursement(1)              Expense
-------------------------------------     -------------------------
                                           1999     1998     1997
                                          -------  -------  -------
Compensation:
   Operations                               (2)      (2)      (2)

Reimbursements:
   General and Administrative,
     Geological, and Engineering
     Expenses and Direct Expenses(3)      $71,280  $71,280  $71,280

----------

(1)   The  authority  for  all of such  compensation  and  reimbursement  is the
      Program Agreement.  With respect to the Operations activities noted in the
      table, management believes that such compensation is equal to or less than
      that  charged by  unaffiliated  persons in the same  geographic  areas and
      under the same conditions.
(2)   Affiliates of the Program serve as operator of a majority of the Program's
      wells.  Dyco,  as General  Partner,  contracts  with such  affiliates  for
      services  as operator  of the wells.  As  operator,  such  affiliates  are
      compensated  at rates  provided in the operating  agreements in effect and
      charged  to all  parties  to such  agreement.  The  dollar  amount of such
      compensation  paid by the  Program to such  affiliates  is  impossible  to
      quantify as of the date of this Annual Report.
(3)   The  Program  reimburses  Dyco  and  its  affiliates  for  reasonable  and
      necessary general and administrative, geological, and engineering expenses
      and direct  expenses  incurred in  connection  with their  management  and
      operation of the Program. The directors,  officers,  and employees of Dyco
      and its  affiliates  receive no direct  remuneration  from the Program for
      their services to the Program. See "Salary Reimbursement Table" below. The
      allocable general and administrative, geological, and engineering expenses
      are apportioned on a reasonable  basis between the Program's  business and
      all other oil and gas  activities  of Dyco and its  affiliates,  including
      Dyco's  management  and  operation  of  affiliated  oil  and  gas  limited
      partnerships. The allocation to the Program of these costs is made by Dyco
      as General Partner.


      As noted in the  Compensation/Reimbursement  Table above,  the  directors,
officers,  and  employees  of  Dyco  and  their  affiliates  receive  no  direct
remuneration  from the Program for their services.  However,  to the extent such
services  represent direct  involvement with the Program,  as opposed to general
corporate functions, such persons' salaries are allocated to and reimbursed



                                      -32-
<PAGE>



by the Program.  Such  allocation to the Program's  general and  administrative,
geological, and engineering expenses of the salaries of directors, officers, and
employees of Dyco and its affiliates is based on internal records  maintained by
Dyco and its affiliates,  and represents investor relations,  legal, accounting,
data  processing,  management,  gas  marketing,  and  other  functions  directly
attributable  to the Program's  operations.  When actual costs incurred  benefit
other  partnerships  and  affiliates,  the  allocation  of costs is based on the
relationship  of the  Program's  reserves  to the  total  reserves  owned by all
partnerships  and  affiliates.  The following  table  indicates the  approximate
amount of general and administrative  expense reimbursement  attributable to the
salaries of the  directors,  officers,  and employees of Dyco and its affiliates
for the three years ended December 31, 1999:



                                      -33-
<PAGE>


<TABLE>
<CAPTION>

                                    Salary Reimbursement

                              Three Years Ended December 31, 1999

                                                           Long Term Compensation
                                                       -------------------------------
                             Annual Compensation              Awards            Payouts
                          -------------------------    ---------------------    -------
                                                                     Securi-
                                              Other                   ties                  All
     Name                                     Annual   Restricted    Under-                Other
      and                                    Compen-     Stock       lying       LTIP     Compen-
   Principal              Salary     Bonus   sation     Award(s)    Options/    Payouts   sation
   Position        Year     ($)       ($)      ($)        ($)        SARs(#)      ($)       ($)
---------------    ----   -------   -------  -------   ----------   --------    -------   -------
<S>                <C>    <C>       <C>        <C>       <C>          <C>         <C>       <C>
Dennis R. Neill,
President(1)       1997     -         -        -         -            -           -         -
                   1998     -         -        -         -            -           -         -
                   1999     -         -        -         -            -           -         -
All Executive
Officers,
Directors,
and Employees
as a group(2)      1997   $42,583     -        -         -            -           -         -
                   1998   $42,184     -        -         -            -           -         -
                   1999   $43,538     -        -         -            -           -         -
----------
(1)   The  general  and  administrative   expenses  paid  by  the  Program  and  attributable  to  salary
      reimbursements do not include any salary or other compensation attributable to Mr. Neill.
(2)   No  officer  or  director  of Dyco or its  affiliates  provides  full-time
      services to the Program and no individual's  salary or other  compensation
      reimbursement from the Program equals or exceeds $100,000 per annum.
</TABLE>




                                      -34-
<PAGE>




      Samson  maintains  necessary  inventories of new and used field equipment.
Samson may have provided  some of this  equipment for wells in which the Program
has an interest. This equipment was provided at prices or rates equal to or less
than  those  normally  charged  in the  same or  comparable  geographic  area by
unaffiliated  persons or companies  dealing at arm's  length.  The  operators of
these  wells  bill the  Program  for a  portion  of such  costs  based  upon the
Program's interest in the well.


ITEM 12.   SECURITY OWNERSHIP OF CERTAIN BENEFICIAL OWNERS AND MANAGEMENT

      The following table provides information as to the beneficial ownership of
the Program's Units as of March 1, 2000, by each  beneficial  owner of more than
5% of the issued  and  outstanding  Units and by the  directors,  officers,  and
affiliates  of Dyco.  The address of each of such persons is Samson  Plaza,  Two
West Second Street, Tulsa, Oklahoma 74103.


                                                Number of
                                                  Units
                                               Beneficially
                                              Owned (Percent
             Beneficial Owner                 of Outstanding)
      -------------------------------        -----------------

      Samson Resources Company                3,518    ( 46.3%)

      All directors, officers, and
        affiliates of Dyco as a group
        and Dyco (5 persons)                  3,518    ( 46.3%)


ITEM 13.   CERTAIN RELATIONSHIPS AND RELATED TRANSACTIONS

      Certain affiliates of Dyco engage in oil and gas activities  independently
of the Program  which  result in  conflicts  of interest  that cannot be totally
eliminated.  The allocation of acquisition  and drilling  opportunities  and the
nature of the compensation  arrangements between the Program and such affiliates
also create potential conflicts of interest.  An affiliate of the Program owns a
significant  amount of the  Program's  Units and  therefore  has an  identity of
interest  with other  limited  partners  with respect to the  operations  of the
Program.

      In order to attempt to assure  limited  liability for limited  partners as
well as an orderly  conduct of business,  management of the Program is exercised
solely by Dyco. The Program Agreement grants Dyco broad discretionary  authority
with  respect  to  the  Program's   participation  in  drilling   prospects  and
expenditure and control of funds,  including  borrowings.  These  provisions are
similar to those contained in prospectuses and partnership



                                      -35-
<PAGE>



agreements  for other public oil and gas  partnerships.  Broad  discretion as to
general  management  of  the  Program  involves  circumstances  where  Dyco  has
conflicts  of  interest  and  where it must  allocate  costs  and  expenses,  or
opportunities, among the Program and other competing interests.

      Dyco does not devote all of its time, efforts,  and personnel  exclusively
to the  Program.  Furthermore,  the  Program  does not have any  employees,  but
instead relies on the personnel of Samson. The Program thus competes with Samson
(including  other  oil and gas  programs)  for the  time and  resources  of such
personnel.  Samson  devotes  such time and  personnel to the  management  of the
Program as are indicated by the  circumstances and as are consistent with Dyco's
fiduciary duties.

      Affiliates  of the Program  are solely  responsible  for the  negotiation,
administration,  and  enforcement of oil and gas sales  agreements  covering the
Program's  leasehold  interests.  Because  affiliates of the Program who provide
services to the  Program  have  fiduciary  or other  duties to other  members of
Samson,  contract  amendments and  negotiating  positions taken by them in their
effort to enforce  contracts with purchasers may not  necessarily  represent the
positions that the Program would take if it were to administer its own contracts
without involvement with other members of Samson. On the other hand,  management
believes that the Program's  negotiating strength and contractual positions have
been enhanced by virtue of its affiliation with Samson.


      Samson  Resources  Company,  an  affiliate  of  Dyco,  ("Resources")  owns
approximately  46% of the Program's  outstanding  Units as of March 1, 2000. The
Program Agreement permits Resources to independently vote its Units.  Resources'
significant  Unit ownership will therefore  likely  determine the outcome of any
matter submitted for a vote of the Limited Partners.



                                      -36-
<PAGE>



                                    PART IV

ITEM 14.   EXHIBITS, FINANCIAL STATEMENT SCHEDULES, AND REPORTS ON FORM 8-K

      (a)  Financial Statements, Financial Statement Schedules, and Exhibits.

           (1)  Financial Statements: The following financial statements for the
                Program as of December 31, 1999 and 1998 and for the years ended
                December  31,  1999,  1998,  and 1997 are  filed as part of this
                report:

                     Report of Independent Accountants
                     Balance Sheets
                     Statements of Operations
                     Statements of Changes in Partners' Capital
                     Statements of Cash Flows
                     Notes to Financial Statements

           (2)  Financial Statement Schedules:

                     None.

           (3)  Exhibits:

                4.1  Program  Agreement dated March 1, 1983 for Dyco Oil and Gas
                     Program  1983-1 by and between Dyco  Petroleum  Corporation
                     and the participants. Filed as Exhibit 4.1 to Annual Report
                     on Form 10-K for the year ended  December 31, 1991 on April
                     6, 1992 and is hereby incorporated by reference.

                4.2  Drilling  Agreement  dated March 1, 1983 for Dyco  Drilling
                     Program  1983-1  by and  between  Dyco Oil and Gas  Program
                     1983-1, Dyco Petroleum Corporation, and Jaye F. Dyer. Filed
                     as Exhibit  4.2 to Annual  Report on Form 10-K for the year
                     ended  December  31,  1991 on April 6,  1992 and is  hereby
                     incorporated by reference.

                4.3  Amendment to Program Agreement for Dyco Oil and Gas Program
                     1983-1  dated  February  9, 1989.  Filed as Exhibit  4.3 to
                     Annual Report on Form 10-K for the year ended  December 31,
                     1991  on  April  6,  1992  and is  hereby  incorporated  by
                     reference.

                4.4  Certificate of Limited Partnership, as amended,for Dyco Oil
                     and  Gas  Program  1983-1  Limited  Partnership.  Filed  as
                     Exhibit 4.4 to



                                      -37-
<PAGE>



                     Annual Report on Form 10-K for the year ended  December 31,
                     1991  on  April  6,  1992  and is  hereby  incorporated  by
                     reference.

               *23.1 Consent of Ryder Scott  Company,  L.P. for Dyco Oil and Gas
                     Program 1983-1 Limited Partnership.

               *27.1 Financial  Data  Schedule   containing   summary  financial
                     information  extracted  from the  Dyco Oil and Gas  Program
                     1983-1  Limited  Partnership's  financial  statements as of
                     December 31, 1999 and for the year ended December 31, 1999.

                All other Exhibits are omitted as inapplicable.


                ------------------
                *  Filed herewith.


      (b)  Reports on Form 8-K filed during the fourth quarter of 1999:

                None.




                                      -38-
<PAGE>



                                   SIGNATURES

Pursuant to the requirements of Sections 13 or 15(d) 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 organized.

                               DYCO OIL AND GAS PROGRAM 1983-1
                               LIMITED PARTNERSHIP

                               By:  DYCO PETROLEUM CORPORATION
                                    General Partner

                                    March 28, 2000


                               By:   //s// Dennis R. Neill
                                    ------------------------------
                                    Dennis R. Neill
                                    President

Pursuant to the requirements of the Securities Exchange Act of 1934, this report
has been signed below by the following  persons on behalf of the  registrant and
in the capacities on the dates indicated.

By:   //s// Dennis R. Neill  President and           March 28, 2000
      -------------------    Director (Principal
         Dennis R. Neill     Executive Officer)

      //s// Patrick M. Hall  Chief Financial         March 28, 2000
      -------------------    Officer (Principal
         Patrick M. Hall     Financial and
                             Accounting Officer)

       //s// Judy K. Fox     Secretary               March 28, 2000
      -------------------
         Judy K. Fox




                                      -39-
<PAGE>



                          INDEX TO EXHIBITS


Exhibit
Number     Description
-------    -----------

4.1        Program  Agreement  dated  March 1, 1983 for Dyco Oil and Gas Program
           1983-1  by  and   between   Dyco   Petroleum   Corporation   and  the
           participants.  Filed as Exhibit 4.1 to Annual Report on Form 10-K for
           the year  ended  December  31,  1991 on April 6,  1992 and is  hereby
           incorporated by reference.

4.2        Drilling  Agreement  dated  March 1, 1983 for Dyco  Drilling  Program
           1983-1 by and between Dyco Oil and Gas Program 1983-1, Dyco Petroleum
           Corporation,  and Jaye F. Dyer. Filed as Exhibit 4.2 to Annual Report
           on Form 10-K for the year ended  December  31,  1991 on April 6, 1992
           and is hereby incorporated by reference.

4.3        Amendment to Program  Agreement  for Dyco Oil and Gas Program  1983-1
           dated February 9, 1989. Filed as Exhibit 4.3 to Annual Report on Form
           10-K for the year  ended  December  31,  1991 on April 6, 1992 and is
           hereby incorporated by reference.

4.4        Certificate of Limited Partnership,  as amended, for Dyco Oil and Gas
           Program  1983-1 Limited  Partnership.  Filed as Exhibit 4.4 to Annual
           Report on Form 10-K for the year ended  December 31, 1991 on April 6,
           1992 and is hereby incorporated by reference.

*23.1      Consent  of  Ryder  Scott Company, L.P. for  Dyco Oil and Gas Program
           1983-1 Limited Partnership.

*27.1      Financial  Data Schedule  containing  summary  financial  information
           extracted   from  the  Dyco  Oil  and  Gas  Program   1983-1  Limited
           Partnership's  financial  statements  as of December 31, 1999 and for
           the year ended December 31, 1999.


------------------
*  Filed herewith.


                                      -40-