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 0-10478

                   DYCO OIL AND GAS PROGRAM 1981-2
                       (A LIMITED PARTNERSHIP)
       (Exact name of registrant as specified in its charter)

           Minnesota                          41-1411952
(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 1981-2
                  (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..........................31
PART III.....................................................................31
      ITEM 10.  DIRECTORS AND EXECUTIVE OFFICERS OF THE REGISTRANT...........31
      ITEM 11.  EXECUTIVE COMPENSATION.......................................32
      ITEM 12.  SECURITY OWNERSHIP OF CERTAIN BENEFICIAL OWNERS AND
                MANAGEMENT...................................................36
      ITEM 13.  CERTAIN RELATIONSHIPS AND RELATED TRANSACTIONS...............36
PART IV......................................................................38
      ITEM 14.  EXHIBITS, FINANCIAL STATEMENT SCHEDULES, AND REPORTS ON
                FORM 8-K.....................................................38
      SIGNATURES.............................................................40




                                      -2-
<PAGE>



                                     PART I


ITEM 1.    BUSINESS

      General

      The Dyco Oil and Gas Program 1981-2 Limited Partnership (the "Program") is
a Minnesota  limited  partnership  engaged in the production of oil and gas. The
Program  commenced  operations  on June  1,  1981  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 94.0% of the Program's oil and gas sales 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                            16
                                                 --
                     Total                       17

                Net productive wells(3):
                  Oil                           .27
                  Gas                          1.93
                                               ----
                     Total                     2.20

----------
(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 did not participate in any drilling activities during 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)                        781         814      1,129
   Gas (Mcf)(2)                     159,015     147,505    197,003

Oil and gas sales:
   Oil                             $ 11,156    $  8,525   $ 20,190
   Gas                              332,512     277,276    454,796
                                    -------     -------    -------
      Total                        $343,668    $285,801   $474,986
                                    =======     =======    =======
Total direct operating
  expenses (3)                     $123,529    $167,970   $183,139
                                    =======     =======    =======

Direct operating expenses as a
   percentage of oil and gas sales    35.9%       58.8%      38.6%

Average sales price:
   Per barrel of oil                 $14.28      $10.47     $17.88
   Per Mcf of gas                      2.09        1.88       2.31

Direct operating expenses per
   equivalent Mcf of gas(4)          $  .75      $ 1.10     $  .90

----------
(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 Values
                        From Proved Reserves

                     As of December 31, 1999 (1)

           Estimated proved reserves:
             Gas (Mcf)                         1,183,265
             Oil and liquids (Bbls)                3,466

           Net present value
             (discounted at 10% per annum)     $ 967,706
-------------------

(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 17 gross
(2.20 net) productive wells. The Program also owned a non-working interest in an
additional  8 wells.  Affiliates  of the  Program  operate 12 (48%) 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 16 gross (1.93 net) wells.  The Program  also owned a  non-working
interest in an  additional  8 wells in the  Anadarko  Basin.  Affiliates  of the
Program  operate  11  (46%) of its  total  wells in the  Anadarko  Basin.  As of
December  31,  1999,  the Program had  estimated  total  proved  reserves in the
Anadarko Basin of  approximately  1,033,738 Mcf of gas and  approximately  2,114
barrels  of crude oil,  with a present  value  (discounted  at 10% per annum) of
estimated future net cash flow of approximately $891,081.




                                      -10-
<PAGE>




      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.

      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 the Program.



                                      -11-
<PAGE>





                               Repurchase          Cash
                                  Price        Distributions
                               ----------      -------------

           1998:
             First Quarter        $ 79              $ -
             Second Quarter         79               20(1)
             Third Quarter         101                -
             Fourth Quarter        101                -

           1999:
             First Quarter        $101              $ -
             Second Quarter        101                -
             Third Quarter         124               20
             Fourth Quarter        104                -

           2000:
             First Quarter        $104              $ -

-----------------------
(1)  Includes proceeds from the sale of oil and gas properties.


      As of  March  1,  2000,  the  Program  has  6,000  Units  outstanding  and
approximately 1,650 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>

                             Selected Financial Data
<CAPTION>

                                                       December 31,

                                    ------------------------------------------------------
                                      1999        1998        1997       1996       1995
                                    --------    --------    --------   --------   --------
<S>                                 <C>         <C>         <C>        <C>        <C>
Summary of Operations:
    Oil and gas sales               $343,668    $285,801    $474,986   $458,802   $309,330
    Total revenues                   346,769     290,756     482,230    472,730    319,042

    Lease operating expenses          99,393     148,997     147,127     77,241    124,768
    Production taxes                  24,136      18,973      36,012     32,630     21,027
    General and administrative
       expenses                       63,168      63,410      68,991     65,425     66,349
    Depreciation, depletion, and
       amortization of oil and gas
       properties                     40,715      27,523      50,901     28,657     31,503

    Net income                       119,357      31,853     179,199    268,777     75,395
       per Unit                        19.65        5.24       29.50      44.25      12.41
    Cash distributions               121,480     121,480     455,550    182,220       -
       per Unit                           20          20          75         30       -

Summary Balance Sheet Data:
    Total assets                     337,364     269,656     363,453    586,573    523,826
    Partners' capital                 84,603      86,726     176,353    452,704    366,147

</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




                                      -14-
<PAGE>




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.


      Results of Operations

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

      Total oil and gas sales  increased  $57,867 (20.2%) in 1999 as compared to
1998.  Of this  increase,  approximately  $22,000  was related to an increase in
volumes of gas sold and approximately  $34,000 was related to an increase in the
average  price of gas sold.  Volumes of oil sold  decreased  33  barrels,  while
volumes  of gas sold  increased  11,510  Mcf in 1999 as  compared  to 1998.  The
increase in volumes of gas sold was primarily due to the  successful  completion
of a new well in late 1998 and the  Program  receiving a reduced  percentage  of
sales on one well during 1998 due to the  Program's  overproduced  gas balancing
position in that well.  These increases were partially offset by normal declines
in  production.  Average oil and gas prices  increased  to $14.28 per barrel and
$2.09 per Mcf,  respectively,  in 1999 from $10.47 per barrel and $1.88 per Mcf,
respectively, in 1998.

      Oil and gas production  expenses  (including lease operating  expenses and
production  taxes)  decreased  $44,441 (26.5%) in 1999 as compared to 1998. This
decrease was primarily due to workover  expenses incurred in 1998 on one well in
order to improve the recovery of reserves and subsurface  repair and maintenance
expenses incurred in 1998 on another well. As a percentage of oil and gas sales,
these expenses  decreased to 35.9% in 1999 from 58.8% in 1998.  This  percentage
decrease was primarily due to the




                                      -15-
<PAGE>




increases  in the  average  prices of oil and gas sold and the dollar  decrease
in oil and gas production expenses.

      Depreciation,  depletion,  and  amortization  of oil  and  gas  properties
increased  $13,192  (47.9%)  in 1999 as  compared  to 1998.  This  increase  was
primarily due to an increase in  depletable  oil and gas  properties  due to the
purchase of gas reserves on one significant well in 1999 in order to help reduce
a gas imbalance on the well. As a percentage of oil and gas sales,  this expense
increased  to 11.8% in 1999  from 9.6% in 1998.  This  percentage  increase  was
primarily  due  to  the  dollar  increase  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
decreased  to 18.4% in 1999 from 22.2% in 1998.  This  percentage  decrease  was
primarily due to the increase in oil and gas sales.


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

      Total oil and gas sales decreased  $189,185 (39.8%) in 1998 as compared to
1997.  Of this  decrease,  approximately  $114,000  was related to a decrease in
volumes of gas sold and  approximately  $63,000 was related to a decrease in the
average price of gas sold. Volumes of oil and gas sold decreased 315 barrels and
49,498 Mcf,  respectively,  in 1998 as compared to 1997. The decrease in volumes
of gas  sold  resulted  primarily  from  (i) the  Program  receiving  a  reduced
percentage  of sales during 1998 on one well due to the  Program's  overproduced
gas  balancing  position in that well and (ii) a positive  prior  period  volume
adjustment  made during 1997 by the purchaser on another  well.  Average oil and
gas prices  decreased to $10.47 per barrel and $1.88 per Mcf,  respectively,  in
1998 from $17.88 per barrel and $2.31 per Mcf, respectively, in 1997.

      Oil and gas production  expenses  (including lease operating  expenses and
production  taxes)  decreased  $15,169 (8.3%) in 1998 as compared to 1997.  This
decrease  resulted  primarily  from (i) a decrease  in legal fees  billed by the
operator on one well in 1998 as compared to 1997 related to a collections matter
and (ii) a decrease in production  taxes associated with the decrease in oil and
gas sales.  These  decreases  were  partially  offset by an increase in workover
expenses  incurred on one well  during 1998 in order to improve the  recovery of
reserves and an increase in subsurface repair and maintenance  expenses incurred
on another  well  during  1998.  As a  percentage  of oil and gas  sales,  these
expenses increased to 58.8% in 1998 from 38.6% in 1997. This percentage increase
was primarily due to (i) the decreases in the average prices of oil and gas sold
and (ii) the workover  expenses  and repair and  maintenance  expenses  incurred
during 1998.




                                      -16-
<PAGE>





      Depreciation,  depletion,  and  amortization  of oil  and  gas  properties
decreased  $23,378 (45.9%) in 1998 as compared to 1997.  This decrease  resulted
primarily from the decrease in volumes of oil and gas sold and upward  revisions
in the  estimates of remaining  oil and gas reserves at December 31, 1998.  As a
percentage  of oil and gas sales,  this  expense  decreased to 9.6% in 1998 from
10.7% in 1997. This percentage decrease was primarily due to the dollar decrease
in depreciation, depletion and amortization.

      General and  administrative  expenses  decreased  $5,581 (8.1%) in 1998 as
compared to 1997. As a percentage of oil and gas sales, these expenses increased
to 22.2% in 1998 from 14.5% 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  7.4 years for gas reserves and 4.4 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.  However,  during 1999 the
Program paid  $289,553,  net of taxes,  for the  purchase of gas  reserves  from
Burlington  Resources (of which  $158,361 was recorded to oil and gas properties
and  $131,192  was used to reduce  the  accrued  liability  for lease  operating
expenses)  and during 1997 the  Program  paid  $34,681  for the  purchase of gas
reserves from Oryx Energy  Company,  each related to the Yowell No. 1-26 well in
which the Program had produced  significantly  more than its share of gas. These
reserves  were  purchased  in order to assist the  Program in  reducing  its gas
imbalance  liability  on  this  well.  In  addition,  during  1998  the  Program
participated in  successfully  drilling the Lemasters No. 1-19 well and incurred
capital costs of $26,182 relating to this drilling activity.  These expenditures
by the Program may reduce or eliminate cash available for a particular quarterly
cash distribution. In connection with the 1999




                                      -17-
<PAGE>




expenditure,  the Program received a temporary advance from the General Partner.
Management  believes  that this advance will be fully  repaid  during 2000.  The
Program  has no  other  debt  commitments.  Management  believes  that  cash for
ordinary   operational  purposes  will  be  provided  by  current  oil  and  gas
production.

      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 1981-2 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
1981-2 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 20, 2000




                                      -19-
<PAGE>




                      DYCO OIL AND GAS PROGRAM
                     1981-2 LIMITED PARTNERSHIP
                           Balance Sheets
                     December 31, 1999 and 1998


                               ASSETS
                               ------
                                               1999         1998
                                             --------     --------
CURRENT ASSETS:
   Cash and cash equivalents                 $  4,991     $ 61,066
   Accrued oil and gas sales                   61,205       49,791
                                              -------      -------
   Total current assets                      $ 66,196     $110,857

NET OIL AND GAS PROPERTIES, utilizing the
   full cost method                           229,994      111,301

DEFERRED CHARGE                                41,174       47,498
                                              -------      -------
                                             $337,364     $269,656
                                              =======      =======

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

CURRENT LIABILITIES:
   Accounts payable                          $  4,795     $  9,681
   Payable to General Partner (Note 2)        207,000         -
   Gas imbalance payable                          825        2,685
                                              -------      -------
      Total current liabilities              $212,620     $ 12,366

ACCRUED LIABILITY                            $ 40,141     $170,564

PARTNERS' CAPITAL:
   General Partner, 74 general
      partner units                          $    847     $    868
   Limited Partners, issued and
      outstanding, 6,000 Units                 83,756       85,858
                                              -------      -------
      Total Partners' Capital                $ 84,603     $ 86,726
                                              -------      -------
                                             $337,364     $269,656
                                              =======      =======


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




                                      -20-
<PAGE>




                      DYCO OIL AND GAS PROGRAM
                     1981-2 LIMITED PARTNERSHIP
                      Statements of Operations
        For the Years Ended December 31, 1999, 1998, and 1997


                                        1999      1998      1997
                                      --------  --------  --------
REVENUES:
   Oil and gas sales                  $343,668  $285,801  $474,986
   Interest                              3,101     4,955     7,244
                                       -------   -------   -------
                                      $346,769  $290,756  $482,230

COSTS AND EXPENSES:
   Lease operating                    $ 99,393  $148,997  $147,127
   Production taxes                     24,136    18,973    36,012
   Depreciation, depletion, and
      amortization of oil and
      gas properties                    40,715    27,523    50,901
   General and administrative           63,168    63,410    68,991
                                       -------   -------   -------
                                      $227,412  $258,903  $303,031
                                       -------   -------   -------
NET INCOME                            $119,357  $ 31,853  $179,199
                                       =======   =======   =======

GENERAL PARTNER (1%) - NET INCOME     $  1,194  $    319  $  1,792
                                       =======   =======   =======

LIMITED PARTNERS (99%) - NET INCOME   $118,163  $ 31,534  $177,407
                                       =======   =======   =======

NET INCOME per Unit                   $  19.65  $   5.24  $  29.50
                                       =======   =======   =======

UNITS OUTSTANDING                        6,074     6,074     6,074
                                       =======   =======   =======



               The accompanying notes are an integral
                 part of these financial statements




                                      -21-
<PAGE>




                            DYCO OIL AND GAS PROGRAM
                           1981-2 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           $4,527    $448,177    $452,704
   Cash distributions              ( 4,555)  ( 450,995)  ( 455,550)
   Net income                        1,792     177,407     179,199
                                     -----     -------     -------

Balances at Dec. 31, 1997           $1,764    $174,589    $176,353
   Cash distributions              ( 1,215)  ( 120,265)  ( 121,480)
   Net income                          319      31,534      31,853
                                     -----     -------     -------

Balances at Dec. 31, 1998           $  868    $ 85,858    $ 86,726
   Cash distributions              ( 1,215)  ( 120,265)  ( 121,480)
   Net income                        1,194     118,163     119,357
                                     -----     -------     -------

Balances at Dec. 31, 1999            $ 847    $ 83,756    $ 84,603
                                     =====     =======     =======



               The accompanying notes are an integral
                 part of these financial statements




                                      -22-
<PAGE>




                            DYCO OIL AND GAS PROGRAM
                           1981-2 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                            $119,357      $ 31,853     $179,199
   Adjustments to reconcile net
      income to net cash provided
      by operating activities:
      Depreciation, depletion,
        and amortization of oil
        and gas properties                 40,715        27,523       50,901
      (Increase) decrease in
        accrued oil and gas sales       (  11,414)       21,996       44,259
      (Increase) decrease in
        deferred charge                     6,324     (   8,318)       4,093
      Increase (decrease) in
        accounts payable                (   4,886)    (  30,609)      30,394
      Increase in payable to
        General Partner                   207,000          -           -
      Increase (decrease) in gas
        imbalance payable               (   1,860)    (  17,906)      20,591
      Increase (decrease) in
        accrued liability               ( 130,423)       44,345        2,246
                                          -------       -------      -------
   Net cash provided by operating
      activities                         $224,813      $ 68,884     $331,683
                                          -------       -------      -------
CASH FLOWS FROM INVESTING ACTIVITIES:
   Proceeds from the sale of oil
      and gas properties                 $     86      $ 22,992     $  5,089
   Additions to oil and gas
      properties                        ( 159,494)    (  26,182)   (  36,436)
                                          -------       -------      -------
   Net cash used by
      investing activities              ($159,408)    ($  3,190)   ($ 31,347)
                                          -------       -------      -------
CASH FLOWS FROM FINANCING ACTIVITIES:
   Cash distributions                   ($121,480)    ($121,480)   ($455,550)
                                          -------       -------      -------
   Net cash used by financing
     activities                         ($121,480)    ($121,480)   ($455,550)
                                          -------       -------      -------
NET DECREASE IN CASH
   AND CASH EQUIVALENTS                 ($ 56,075)    ($ 55,786)   ($155,214)

CASH AND CASH EQUIVALENTS AT
   BEGINNING OF PERIOD                     61,066       116,852      272,066
                                          -------       -------      -------
CASH AND CASH EQUIVALENTS AT
   END OF PERIOD                         $  4,991      $ 61,066     $116,852
                                          =======       =======      =======


                     The accompanying notes are an integral
                       part of these financial statements



                                      -23-
<PAGE>



         DYCO OIL AND GAS PROGRAM 1981-2 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  1981-2  Limited  Partnership  (the
      "Program"), a Minnesota limited partnership,  commenced operations on June
      1, 1981. Dyco Petroleum Corporation ("Dyco") is the General Partner of the
      Program.  Affiliates of Dyco owned 2,919 (48.7%) 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.  During 1999 the Program purchased  reserves in the amount of
      $158,361 (207,777 Mcf), net of accrued



                                      -24-
<PAGE>



      liability,  on the Yowell No. 1-26 well in which the Program had  produced
      significantly  more than its share of gas.  Capitalized costs are depleted
      on the 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 $0.25,  $0.18,  and
      $0.25, 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 72,965 Mcf,  resulting in prepaid
      lease  operating  expenses of $41,174.  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
      81,500 Mcf, resulting in prepaid lease operating expenses of $47,498.


      Payable to General Partner

           The Payable to General Partner at December 31, 1999 represents a cash
      advance from Dyco.  This advance was  necessary to pay for the purchase of
      reserves at $1.50 per Mcf on the Yowell No. 1-26 well in which the Program
      had produced  significantly  more than its share of gas. The amount due as
      of March 1, 2000 was $169,000.




                                      -25-
<PAGE>



      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 71,134  Mcf,  resulting  in accrued  lease
      operating expenses of $40,141. 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 292,663  Mcf,  resulting  in
      accrued  lease  operating  expenses of  $170,564.  The decrease in accrued
      liability  was  primarily  due  to a  decrease  in  the  overproduced  gas
      imbalance  position  on the Yowell No.  1-26 well due to the  purchase  of
      reserves on this well during 1999.


      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 $825 (550
      Mcf). At December 31, 1998,  total sales  exceeded the Program's  share of
      estimated total gas reserves on two wells by $2,685 (1,790 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



                                      -26-
<PAGE>



      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.


2.    TRANSACTIONS WITH RELATED PARTIES

           The Program  obtained an operating  advance from the General  Partner
      during the fourth  quarter of 1999 due to the  purchase of reserves on one
      well. The balance due as of March 1, 2000 was $169,000. See Note 1.

           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 $63,168, $63,410, and $68,991,  respectively, of which $47,952 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.


3.    MAJOR CUSTOMERS

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

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

           El Paso Energy
             Marketing Company      94.0%      93.0%     94.8%



                                      -27-
<PAGE>



           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:

                                              December 31,
                                      ----------------------------
                                           1999            1998
                                      -------------  -------------
      Proved properties                $39,932,897    $39,773,489


      Less accumulated depreciation,
      depletion, amortization, and
      valuation allowance             ( 39,702,903)  ( 39,662,188)
                                        ----------     ----------

      Net oil and gas properties       $   229,994    $   111,301
                                        ==========     ==========


      Costs Incurred

           The Program  incurred no oil and gas  exploration  costs during 1999,
      1998, and 1997.  During 1999,  1998, and 1997 the Program incurred oil and
      gas property  acquisition  (purchase of reserves) and development costs as
      follows:

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

           Acquisition costs,
             net of accrued
             liability                 $158,361  $   -     $34,681
           Development costs              1,133   26,182     1,755
                                        =======   ======    ======



                                      -28-
<PAGE>





      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 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.





                                      -29-
<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        3,145      943,531     3,443    836,740     4,644    1,002,691

Revisions of previous
   estimates                1,102      190,972       389    237,927    (   30)       6,244

Sales of reserves            -            -          -     ( 16,025)   (   42)  (    3,605)

Purchase of reserves         -         207,777       -          -         -         28,413

Extensions and
   discoveries               -            -          127     32,394       -            -

Production                 (  781)  (  159,015)   (  814)  (147,505)   (1,129)   ( 197,003)
                            -----    ---------     -----    -------     -----    ---------
Proved reserves,
   end of year              3,466    1,183,265     3,145    943,531     3,443      836,740
                            =====    =========     =====    =======     =====    =========
Proved developed reserves:
   Beginning of year        3,145      943,531     3,443    836,740     4,644    1,002,691
                            -----    ---------     -----    -------     -----    ---------
   End of year              3,466    1,183,265     3,145    943,531     3,443      836,740
                            =====    =========     =====    =======     =====    =========
</TABLE>




                                      -30-
<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




                                      -31-
<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:




                                      -32-
<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)                       $47,952  $47,952  $47,952

----------

(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



                                      -33-
<PAGE>



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 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:



                                      -34-
<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  $28,647      -         -         -            -          -         -
                   1998  $28,378      -         -         -            -          -         -
                   1999  $29,289      -         -         -            -          -         -
---------------

(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>



                                      -35-
<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                  2,924    (48.7%)

      All directors, officers, and
        affiliates of Dyco as a group
        and Dyco (5 persons)                    2,924    (48.7%)


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


                                      -36-
<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.  These  provisions are
similar to those contained in prospectuses and partnership  agreements for other
public oil and gas partnerships.

      Samson  Resources  Company,  an  affiliate  of  Dyco,  ("Resources")  owns
approximately  49% 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.




                                      -37-
<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  Drilling  Agreement  dated  June 5, 1981 for Dyco  Drilling
                     Program  1981-2  by and  between  Dyco Oil and Gas  Program
                     1981-2, Dyco Petroleum Corporation,  and Jaye F. Dyer filed
                     as Exhibit  4.1 to Annual  Report on Form 10-K for the year
                     ended  December  31,  1991 on April 13,  1992 and is hereby
                     incorporated by reference.

                4.2  Program  Agreement  dated June 5, 1981 for Dyco Oil and Gas
                     Program  1981-2 by and between Dyco  Petroleum  Corporation
                     and the Participants  filed as Exhibit 4.2 to Annual Report
                     on Form 10-K for the year ended  December 31, 1991 on April
                     13, 1992 and is hereby incorporated by reference.

                4.3  Amendment to Program Agreement for Dyco Oil and Gas Program
                     1981-2  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  13,  1992  and is  hereby  incorporated  by
                     reference.

                4.4  Certificate of Limited  Partnership,  as amended,  for Dyco
                     Oil and Gas Program  1981-2  Limited  Partnership  filed as
                     Exhibit 4.4 to



                                      -38-
<PAGE>



                     Annual Report on Form 10-K for the year ended  December 31,
                     1991 on  April  13,  1992  and is  hereby  incorporated  by
                     reference.

               *23.1 Consent of Ryder Scott Company,  L.P. for Dyco Oil and Gas
                       Program 1981-2 Limited Partnership.

               *27.1 Financial  Data  Schedule   containing   summary  financial
                     information  extracted  from the  Dyco Oil and Gas  Program
                     1981-2  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.




                                      -39-
<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 1981-2
                               LIMITED PARTNERSHIP

                               By:  DYCO PETROLEUM CORPORATION
                                    General Partner

                                    March 24, 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 24, 2000
    -------------------      Director (Principal
       Dennis R. Neill       Executive Officer)

    //s// Patrick M. Hall    Chief Financial        March 24, 2000
    -------------------      Officer (Principal
       Patrick M. Hall       Financial and
                             Accounting Officer)

    //s// Judy K. Fox        Secretary              March 24, 2000
    -------------------
       Judy K. Fox



                                      -40-
<PAGE>



                          INDEX TO EXHIBITS


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

4.1             Drilling  Agreement dated June 5, 1981 for Dyco Drilling Program
                1981-2 by and  between  Dyco Oil and Gas  Program  1981-2,  Dyco
                Petroleum Corporation,  and Jaye F. Dyer filed as Exhibit 4.1 to
                Annual Report on Form 10-K for the year ended  December 31, 1991
                on April 13, 1992 and is hereby incorporated by reference.

4.2             Program  Agreement  dated  June 5,  1981  for  Dyco  Oil and Gas
                Program 1981-2 by and between Dyco Petroleum Corporation and the
                Participants  filed as Exhibit 4.2 to Annual Report on Form 10-K
                for the year ended  December  31,  1991 on April 13, 1992 and is
                hereby incorporated by reference.

4.3             Amendment  to  Program  Agreement  for Dyco Oil and Gas  Program
                1981-2  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 13, 1992 and is hereby incorporated by reference.

4.4             Certificate of Limited Partnership, as amended, for Dyco Oil and
                Gas Program 1981-2 Limited  Partnership  filed as Exhibit 4.4 to
                Annual Report on Form 10-K for the year ended  December 31, 1991
                on April 13, 1992 and is hereby incorporated by reference.

*23.1           Consent of Ryder Scott Company, L.P. for Dyco Oil and Gas 1981-2
                Limited Partnership.

*27.1           Financial Data Schedule containing summary financial information
                extracted  from  the  Dyco Oil and Gas  Program  1981-2  Limited
                Partnership's  financial  statements as of December 31, 1999 and
                for the year ended December 31, 1999.


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


                                      -41-