-----BEGIN PRIVACY-ENHANCED MESSAGE----- Proc-Type: 2001,MIC-CLEAR Originator-Name: webmaster@www.sec.gov Originator-Key-Asymmetric: MFgwCgYEVQgBAQICAf8DSgAwRwJAW2sNKK9AVtBzYZmr6aGjlWyK3XmZv3dTINen TWSM7vrzLADbmYQaionwg5sDW3P6oaM5D3tdezXMm7z1T+B+twIDAQAB MIC-Info: RSA-MD5,RSA, MBqNgQOLHxKxR3WTwYDmnt2vktTJOicIoF2V5yZ3zUVvcluZ2Skl12UWGOFeG7xO /ZOEWCJHMuYYsmu2bz59KA== 0000806573-97-000001.txt : 19970222 0000806573-97-000001.hdr.sgml : 19970222 ACCESSION NUMBER: 0000806573-97-000001 CONFORMED SUBMISSION TYPE: 10-K405 PUBLIC DOCUMENT COUNT: 3 CONFORMED PERIOD OF REPORT: 19961231 FILED AS OF DATE: 19970220 SROS: NONE FILER: COMPANY DATA: COMPANY CONFORMED NAME: DYCO OIL & GAS PROGRAM 1979-1 LIMITED PARTNERSHIP CENTRAL INDEX KEY: 0000806573 STANDARD INDUSTRIAL CLASSIFICATION: DRILLING OIL & GAS WELLS [1381] IRS NUMBER: 411358013 STATE OF INCORPORATION: MN FISCAL YEAR END: 1231 FILING VALUES: FORM TYPE: 10-K405 SEC ACT: 1934 Act SEC FILE NUMBER: 033-10346-07 FILM NUMBER: 97539805 BUSINESS ADDRESS: STREET 1: SAMSON PLZ STREET 2: TWO W SECOND ST CITY: TULSA STATE: OK ZIP: 74103 BUSINESS PHONE: 9185831791 MAIL ADDRESS: STREET 1: SAMSON PLZ STREET 2: TWO W SECOND ST CITY: TULSA STATE: OK ZIP: 74103 FILER: COMPANY DATA: COMPANY CONFORMED NAME: DYCO OIL & GAS PROGRAM 1979-2 LIMITED PARTNERSHIP CENTRAL INDEX KEY: 0000806574 STANDARD INDUSTRIAL CLASSIFICATION: DRILLING OIL & GAS WELLS [1381] IRS NUMBER: 411358015 STATE OF INCORPORATION: MN FISCAL YEAR END: 1231 FILING VALUES: FORM TYPE: 10-K405 SEC ACT: 1934 Act SEC FILE NUMBER: 033-10346-08 FILM NUMBER: 97539806 BUSINESS ADDRESS: STREET 1: SAMSON PLZ 2 W SECOND ST CITY: TULSA STATE: OK ZIP: 74103 BUSINESS PHONE: 9185831791 MAIL ADDRESS: STREET 1: SAMSON PLZ STREET 2: TWO W SECOND ST CITY: TULSA STATE: OK ZIP: 74103 10-K405 1 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, 1996 Commission File Number 33-10346-07 (1979-1 Program) 33-10346-08 (1979-2 Program) DYCO 1979 OIL AND GAS PROGRAMS (TWO LIMITED PARTNERSHIPS) (Exact name of registrant as specified in its charter) 41-1358013 (1979-1 Program) Minnesota 41-1358015 (1979-2 Program) (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. Yes X No (Disclosure is contained herein) ----- ----- 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. FORM 10-K405 DYCO 1979 OIL AND GAS PROGRAMS (Two Minnesota limited partnerships) TABLE OF CONTENTS PART I . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 1 ITEM 1. BUSINESS . . . . . . . . . . . . . . . . . . . . . 1 ITEM 2. PROPERTIES . . . . . . . . . . . . . . . . . . . . 5 ITEM 3. LEGAL PROCEEDINGS . . . . . . . . . . . . . . . . 12 ITEM 4. SUBMISSION OF MATTERS TO A VOTE OF LIMITED PARTNERS . . . . . . . . . . . . . . . . . . . . . 13 PART II . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 14 ITEM 5. MARKET FOR THE REGISTRANT'S LIMITED PARTNERSHIP UNITS AND RELATED LIMITED PARTNER MATTERS . . . . 14 ITEM 6. SELECTED FINANCIAL DATA . . . . . . . . . . . . . 16 ITEM 7. MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS . . . . . . . 18 ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA . . . 28 ITEM 9. CHANGES IN AND DISAGREEMENTS WITH ACCOUNTANTS ON ACCOUNTING AND FINANCIAL DISCLOSURE . . . . . . . 52 PART III . . . . . . . . . . . . . . . . . . . . . . . . . . . . 52 ITEM 10. DIRECTORS AND EXECUTIVE OFFICERS OF THE REGISTRANT . . . . . . . . . . . . . . . . . . . . 52 ITEM 11. EXECUTIVE COMPENSATION . . . . . . . . . . . . . . 53 ITEM 12. SECURITY OWNERSHIP OF CERTAIN BENEFICIAL OWNERS AND MANAGEMENT . . . . . . . . . . . . . . . . . . 58 ITEM 13. CERTAIN RELATIONSHIPS AND RELATED TRANSACTIONS . . . . . . . . . . . . . . . . . . . 59 PART IV . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 61 ITEM 14. EXHIBITS, FINANCIAL STATEMENT SCHEDULES, AND REPORTS ON FORM 8-K . . . . . . . . . . . . . . . 61 SIGNATURES . . . . . . . . . . . . . . . . . . . . . . . . . 64 ii PART I ITEM 1. BUSINESS General The Dyco Oil and Gas Program 1979-1 Limited Partnership (the "1979-1 Program") and Dyco Oil and Gas Program 1979-2 Limited Partnership (the "1979-2 Program") (collectively, the "Programs") are Minnesota limited partnerships engaged in the production of oil and gas. The 1979-1 Program and 1979-2 Program commenced operations on April 2, 1979 and July 2, 1979, respectively, with the primary financial objective of investing their limited partners' subscriptions in the drilling of oil and gas prospects and then distributing to their 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 Programs. See "Item 2. Properties" for a description of the Programs' reserves and properties. The limited partnership agreements for each of the Programs (the "Program Agreements") provide 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 each Program's reimbursement to Dyco of the Program's proportionate share of Dyco's geological, engineering, and general and administrative expenses. Dyco serves as General Partner of 32 limited partnerships, including the Programs. Dyco is a wholly-owned subsidiary of Samson Investment Company. Samson Investment Company and its various corporate subsidiaries, including Dyco, (collectively, the "Samson Companies") are 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, 1996, the Samson Companies owned interests in approximately 16,000 oil and gas wells located in 19 states of the United States and Canada, Venezuela, and Russia. At December 31, 1996, the Samson Companies operated approximately 2,600 oil and gas wells located in 15 states of the United States and Canada, Venezuela, and Russia. As limited partnerships, the Programs have no officers, directors, or employees. They rely instead on the personnel of Dyco and the other Samson Companies. As of February 1, 1997 the Samson Companies employed approximately 780 persons. No employees are covered by collective bargaining agreements, and management believes that the Samson Companies provide a sound employee relations environment. For information regarding the executive officers of Dyco, see "Item 10. Directors and Executive Officers of the Registrant." 1 Dyco's and the Programs' 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. Funding Although the Program Agreements permit the Programs to incur borrowings, each Program's operations and expenses are currently funded out of each Program's revenues from oil and gas sales. Dyco may, but is not required to, advance funds to each of the Programs for the same purposes for which Program borrowings are authorized. Principal Products Produced and Services Rendered The Programs' sole business is the development and production of oil and gas with a concentration on gas. The Programs do not hold any patents, trademarks, licenses, or concessions and are not a party to any government contracts. The Programs have no backlog of orders and do not participate in research and development activities. The Programs are 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. 2 Regulation of Sales and Transportation of Oil and Gas -- Sales of crude oil and condensate are made by the Programs 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, including, but not limited to, the Natural Gas Act of 1938 (the "NGA"), the Natural Gas Policy Act of 1978 (the "NGPA"), and regulations promulgated by the Federal Energy Regulatory Commission (the "FERC") under the NGA, the NGPA, and other statutes. The provisions of the NGA and the NGPA, as well as the regulations thereunder, are complex and affect all who produce, resell, transport, or purchase gas, including the Programs. Although virtually all of the Programs' gas production is not subject to price regulation, the NGA, NGPA, and FERC 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 Programs' 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. Regulation of the Environment -- The Programs' 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 therewith, may increase the cost of the Programs' operations or may affect the Programs' ability to complete, in a timely fashion, 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 94.8% of the 1979-1 Program's oil and gas sales during the year ended December 31, 1996. With respect to the 1979-2 Program, purchases of gas by El Paso accounted for approxi- mately 74.8% of its oil and gas sales during the year ended December 31, 1996. 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 Programs' pipeline transporters, the Programs may encounter difficulty in marketing their gas and in maintaining historic sales levels. Alternative purchasers or transporters may not be readily available. 3 The Programs' principal customers for crude oil production are refiners and other companies which have pipeline facilities near the producing properties of the Programs. 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 Programs to produce and market oil and gas profitably depends on a number of factors that are beyond the control of the Programs. 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 Programs' revenues is the prices received for the sale of oil and gas. Predicting future prices is very difficult. Concerning past trends, average yearly wellhead gas prices in the United States have been relatively volatile for a number of years. For the past ten years, such prices have generally been in the $1.40 to $2.00 per Mcf range, significantly below prices received in the early 1980s. Average gas prices in the last several months have, however, been somewhat higher than those yearly averages. It is not known whether this is a short-term trend or will lead to higher average gas prices on a longer-term basis. Substantially all of the Programs' gas reserves are being sold in 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 Programs' gas increased from approximately $2.00 per Mcf at December 31, 1995 to approximately $3.57 per Mcf at December 31, 1996. Such prices were on an MMBTU basis and differ from the prices actually received by the Programs due to transportation and marketing costs, BTU adjustments, and regional price and quality differences. 4 Due to global consumption and supply trends over the last several months, oil prices have recently been higher than the yearly average prices of the late to mid-1980s and early 1990s. It is not known whether this trend will continue. Prices for the Programs' oil increased from approximately $18.50 per barrel at December 31, 1995 to approximately $23.75 per barrel at December 31, 1996. Future prices for both oil and gas will likely be different from (and may be lower than) the prices in effect on December 31, 1996. Primarily due to heating season demand, year-end prices in many past years have tended to be higher, and in some cases significantly higher, than the yearly average price actually received by the Programs for at least the following year. In particular, it should be noted that December 31, 1996 prices were much higher than year-end prices for the last several years and substantially higher than the average prices received in each of the last several years. It is not possible to predict whether the December 1996 pricing level is indicative of a new trend toward higher energy prices or a short-term deviation from the recent history of low to moderate prices; therefore, management is unable to predict whether future oil and gas prices will (i) stabilize, (ii) increase, or (iii) decrease. Insurance Coverage The Programs are 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 Programs maintain insurance coverage as is customary for entities of a similar size engaged in operations similar to that of the Programs, 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 Programs' financial position and results of operations. ITEM 2. PROPERTIES Well Statistics The following table sets forth the numbers of gross and net productive wells of the Programs as of December 31, 1996. 5 Well Statistics(1) As of December 31, 1996 1979-1 1979-2 Program Program ------- ------- Gross productive wells(2): Oil 3 - Gas 36 23 -- -- Total 39 23 Net productive wells(3): Oil .15 - Gas 1.78 1.62 ---- ---- Total 1.93 1.62 - --------------- (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 expressed as whole numbers and fractions thereof. For example, a 15% leasehold interest in a well represents one Gross Well, but 0.15 Net Well. 6 Drilling Activities The Programs participated in no drilling activities for the year ended December 31, 1996. 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 Programs, revenues attributable to such production, and certain price and cost information. Net Production Data Year Ended December 31, -------------------------------- 1996 1995 1994 ---------- --------- -------- 1979-1 Program: - -------------- Production: Oil (Bbls)(1) 378 817 677 Gas (Mcf)(2) 238,389 286,965 242,706 Oil and gas sales: Oil $ 8,094 $ 14,730 $ 10,885 Gas 492,114 381,763 389,813 ------- ------- ------- Total $500,208 $396,493 $400,698 ======= ======= ======= Total direct operating expenses $103,193 $118,370 $ 81,317 ======= ======= ======= Direct operating expenses as a percentage of oil and gas sales 20.6% 29.9% 20.3% Average sales price: Per barrel of oil $21.42 $18.03 $16.08 Per Mcf of gas 2.06 1.33 1.61 Direct operating expenses per equivalent Mcf of gas(3) $ .43 $ .41 $ .33 7 1979-2 Program: - -------------- Production: Oil (Bbls)(1) 1,336 1,614 3,276 Gas (Mcf)(2) 296,244 313,765 574,279 Oil and gas sales: Oil $ 28,156 $ 26,983 $ 51,648 Gas 700,890 456,484 965,696 ------- ------- --------- Total $729,046 $483,467 $1,017,344 ======= ======= ========= Total direct operating expenses $147,342 $103,957 $ 253,688 ======= ======= ========= Direct operating expenses as a percentage of oil and gas sales 20.2% 21.5% 24.9% Average sales price: Per barrel of oil $21.07 $16.72 $15.77 Per Mcf of gas 2.37 1.45 1.68 Direct operating expenses per equivalent Mcf of gas(3) $ .48 $ .32 $ .43 - --------------- (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) 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 Proved Reserves and Net Present Value The following table sets forth the Programs' estimated proved oil and gas reserves and net present value therefrom as of December 31, 1996. 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"). 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 Programs' proved reserves was calculated on the basis of current costs and prices at December 31, 1996. 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 Programs' proved reserves do not necessarily reflect market prices for oil and gas production subsequent to December 31, 1996. Furthermore, gas prices at December 31, 1996 were much higher than the price used for determining the Programs' net present value of proved reserves for the year ended December 31, 1995 and substantially higher than average prices received by the Programs in each of the last several years. There can be no assurance that the prices used in calculating the net present value of the Programs' proved reserves at December 31, 1996 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 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. 9 Proved Reserves and Net Present Value From Proved Reserves As of December 31, 1996 1979-1 Program: - -------------- Estimated proved reserves: Gas (Mcf) 1,077,521 Oil and liquids (Bbls) 3,193 Net present value (discounted at 10% per annum) $2,085,222 1979-2 Program: - -------------- Estimated proved reserves: Gas (Mcf) 955,767 Oil and liquids (Bbls) 12,678 Net present value (discounted at 10% per annum) $2,083,557 No estimates of the proved reserves of the Programs comparable to those included herein have been included in reports to any federal agency other than the SEC. Additional information relating to the Programs' proved reserves is contained in Note 4 to the Programs' financial statements, included in Item 8 of this Annual Report. Significant Properties 1979-1 Program -------------- As of December 31, 1996, the 1979-1 Program's properties consisted of 39 gross (1.93 net) productive wells. The 1979-1 Program also owned a non-working interest in an additional 10 wells. Affiliates of the 1979-1 Program operate 15 (31%) of its total wells. As of December 31, 1996, the 1979-1 Program had estimated total proved reserves of 1,077,521 Mcf of gas and 3,193 barrels of oil, with a present value (discounted at 10% per annum) of estimated future net cash flow of $2,085,222. All of the 1979-1 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. 10 1979-2 Program -------------- As of December 31, 1996, the 1979-2 Program's properties consisted of 23 gross (1.62 net) productive wells. Affiliates of the 1979-2 Program operate 5 (22%) of its wells. As of December 31, 1996, the 1979-2 Program had estimated total proved reserves of 955,767 Mcf of gas and 12,678 barrels of oil, with a present value (discounted at 10% per annum) of estimated future net cash flow of $2,083,557. Substantially all of the 1979-2 Program's reserves are located in the Anadarko Basin. All of the 1979-2 Program's properties are located onshore in the continental United States. As of December 31, 1996, the 1979-2 Program's properties in the Anadarko Basin consisted of 16 gross (1.28 net) productive wells. Affiliates of the 1979-2 Program operate 4 (25%) of its Anadarko Basin wells. As of December 31, 1996, the 1979-2 Program had estimated total proved reserves in the Anadarko Basin of approximately 836,238 Mcf of gas and approximately 11,562 barrels of crude oil, with a present value (discounted at 10% per annum) of estimated future net cash flow of approximately $1,917,588. Title to Oil and Gas Properties Management believes that the Programs have satisfactory title to their oil and gas properties. Record title to substantially all of the Programs' properties is held by Dyco as nominee. Title to the Programs' 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 Programs' interest therein or materially interfere with their use in the operation of the Programs' business. 11 ITEM 3. LEGAL PROCEEDINGS On October 26, 1993, certain royalty owners filed a class action lawsuit against Dyco and another party in which they alleged entitlement to a share of the proceeds from a gas contract involving one of the 1979-2 Program's wells, the Johnson No. 1-22. (Randy Beutler, et al. v. Dyco, et al., Case No. CJ-93-311, District Court of Custer County, Oklahoma). The 1979-2 Program has an approximate 2.6% working interest in the Johnson No. 1-22 well. The plaintiffs alleged claims based on breach of contract, breach of fiduciary obligation, and unjust enrichment and sought an accounting and declaration as a third party beneficiary under the gas contract. The plaintiffs have not quantified the amount of their damages, but they are seeking exemplary damages, unpaid royalties, and interest. Dyco has filed its answer in the matter in which it denied all of the plaintiffs' allegations, and discovery is proceeding in the matter. On January 18, 1994 the district court certified the matter as a class action. Oral arguments were heard on plaintiffs' motion for summary judgment in January 1995, however, as of the date of this Annual Report, the district court has not ruled on the motion. Dyco intends to vigorously defend the lawsuit. On September 10, 1996 the Oklahoma Supreme Court ruled in a separate lawsuit that owners of royalty interests in Oklahoma oil and gas properties do not have the right to share in the proceeds of take-or-pay settlements. On February 11, 1997 the Oklahoma Supreme Court denied the plaintiffs' request for a rehearing in this separate lawsuit; therefore, its holding that Oklahoma royalty owners do not have the right to share in the proceeds of take-or-pay settlements should be dispositive of the Beutler case. On October 21, 1994 a royalty owner filed a class action lawsuit against Samson Resources Company and other parties in which the royalty owner alleged entitlement to a share of the proceeds from a gas contract involving one of the 1979-2 Program's wells, the Guenzel No. 1 (T.W. Walbert v. Samson Resources Company, et al., Case No. CJ- 94-74, District Court of Dewey County, Oklahoma). The 1979-2 Program has a 1.08% working interest in the Guenzel No. 1 well. The plaintiffs alleged claims based on unjust enrichment, breach of contract and fiduciary obligation, and constructive fraud, and are seeking an accounting. On September 10, 1996 the Oklahoma Supreme Court ruled in a separate lawsuit that owners of royalty interests in Oklahoma oil and gas properties do not have the right to share in the proceeds of take-or-pay settlements. As a result of such ruling, the Plaintiff dismissed the Walbert case. 12 On October 24, 1996, certain royalty owners filed a class action lawsuit against Dyco and certain other parties in which they alleged entitlement to a share of the proceeds from a gas contract involving one of the 1979-2 Program's wells, the Maxwell No. 1-23. (Thurman Horn, et al., v. Dyco, et al., Case No. 10,324, District Court of Wheeler County, Texas.) The 1979-2 Program has a 22.5% working interest in the Maxwell No. 1-23. The plaintiffs are alleging causes of action based on breach of duty to market, breach of duty to pay royalties, and breach of duty of good faith and fair dealing and are seeking restitution and an accounting. The plaintiffs have not quantified the amount of their damages. Dyco has filed its answer in the matter in which it denied all of the plaintiffs' allegations, and discovery is proceeding in the matter. Dyco intends to vigorously defend the lawsuit. As of the date of this Annual Report, management cannot determine the amount of any alleged damages which would be allocable to the 1979-2 Program from this lawsuit. A Texas appellate court has previously ruled in a separate lawsuit that owners of royalty interests in Texas oil and gas properties do not have the right to share in the proceeds of take-or-pay settlements. To the knowledge of the management of Dyco and the Programs, neither Dyco, the Programs, nor the Programs' properties are subject to any litigation, the results of which would have a material effect on the Programs' 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 of either Program during 1996. 13 PART II ITEM 5. MARKET FOR THE REGISTRANT'S LIMITED PARTNERSHIP UNITS AND RELATED LIMITED PARTNER MATTERS The Programs do not have an established trading market for their units of limited partnership interest ("Units"). Pursuant to the terms of the Program Agreements, Dyco, as General Partner, is obligated to annually issue a repurchase offer which is based on the estimated future net revenues from the Programs' reserves and is calculated pursuant to the terms of the Program Agreements. 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 Programs' cash distributions per Unit for the same period. For purposes of this Annual Report, a Unit represents an initial subscription of $5,000 to a Program. 1979-1 Program -------------- Repurchase Cash Price Distributions ---------- ------------- 1995: First Quarter $228 $35 Second Quarter 229 30 Third Quarter 229 - Fourth Quarter 229 - 1996: First Quarter $204 $25 Second Quarter 179 25 Third Quarter 250 30 Fourth Quarter 230 20 1997: First Quarter $230 (1) --------------- (1) To be declared in March 1997. 14 1979-2 Program -------------- Repurchase Cash Price Distributions ---------- ------------- 1995: First Quarter $239 $65 Second Quarter 335 40 Third Quarter 310 25 Fourth Quarter 285 25 1996: First Quarter $245 $40 Second Quarter 205 40 Third Quarter 255 45 Fourth Quarter 210 45 1997: First Quarter $210 (1) --------------- (1) To be declared in March 1997 The 1979-1 Program has 3,172 Units outstanding and approximately 1,106 limited partners of record. The 1979-2 Program has 2,889 Units outstanding and approximately 839 limited partners of record. 15 ITEM 6. SELECTED FINANCIAL DATA
SELECTED FINANCIAL DATA The following tables present selected financial data for the Programs. This data should be read in conjunction with the financial statements of the Programs, and the respective notes thereto, included elsewhere in this Annual Report. See "Item 8. Financial Statements and Supplementary Data." 1979-1 Program -------------- December 31, -------------------------------------------------- 1996 1995 1994 1993 1992 -------- -------- -------- -------- ---------- Summary of Operations: Oil and gas sales $500,208 $396,493 $400,698 $717,528 $ 909,666 Total revenues 502,561 398,559 401,930 720,210 1,405,677 Lease operating expenses 67,719 90,080 52,310 37,565 61,391 Production taxes 35,474 28,290 29,007 51,198 64,842 General and administrative expenses 54,220 54,317 51,498 55,466 58,109 Depreciation, depletion, and amortization of oil and gas properties 33,690 54,252 70,054 103,973 156,925 Interest expense - - - - 12,366 Net income 311,458 171,620 199,061 472,008 1,052,044 per Unit 98 54 63 149 332 Cash distributions 317,200 206,180 237,900 602,680 697,840 per Unit 100 65 75 190 220 Summary Balance Sheet Data: Total assets 453,642 467,816 483,352 489,362 620,617 Partners' capital 403,825 409,567 444,127 482,966 613,638
16
1979-2 Program -------------- December 31, --------------------------------------------------------- 1996 1995 1994 1993 1992 -------- -------- ---------- ---------- ---------- Summary of Operations: Oil and gas sales $729,046 $483,467 $1,017,344 $ 947,742 $ 373,656 Total revenues 735,326 490,205 1,025,628 1,037,181 1,065,329 Lease operating expenses 94,195 67,295 178,826 145,697 76,118 Production taxes 53,147 36,662 74,862 68,291 27,876 General and administrative expenses 40,363 40,709 37,993 42,565 44,708 Depreciation, depletion, and amortization of oil and gas properties 71,807 84,448 244,687 185,125 86,297 Interest expense - - - - 18,402 Net income 475,814 261,091 489,260 595,503 811,928 per Unit 165 90 169 206 281 Cash distributions 491,130 447,795 476,685 1,820,070 173,340 per Unit 170 155 165 630 60 Summary Balance Sheet Data: Total assets 709,662 705,367 857,507 1,538,968 2,774,685 Partners' capital 647,275 662,591 849,295 836,720 2,061,287
17 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 Programs. 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 Programs' revenues is the prices received for the sale of oil and gas. Predicting future prices is very difficult. Concerning past trends, average yearly wellhead gas prices in the United States have been relatively volatile for a number of years. For the past ten years, such prices have generally been in the $1.40 to $2.00 per Mcf range, significantly below prices received in the early 1980s. Average gas prices in the last several months have, however, been somewhat higher than those yearly averages. It is not known whether this is a short-term trend or will lead to higher average gas prices on a longer-term basis. 18 Substantially all of the Programs' gas reserves are being sold in 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 Programs' gas increased from approximately $2.00 per Mcf at December 31, 1995 to approximately $3.57 per Mcf at December 31, 1996. Such prices were on an MMBTU basis and differ from the prices actually received by the Programs due to transportation and marketing costs, BTU adjustments, and regional price and quality differences. Due to global consumption and supply trends over the last several months, oil prices have recently been higher than the yearly average prices of the late to mid-1980s and early 1990s. It is not known whether this trend will continue. Prices for the Programs' oil increased from approximately $18.50 per barrel at December 31, 1995 to approximately $23.75 per barrel at December 31, 1996. Future prices for both oil and gas will likely be different from (and may be lower than) the prices in effect on December 31, 1996. Primarily due to heating season demand, year-end prices in many past years have tended to be higher, and in some cases significantly higher, than the yearly average price actually received by the Programs for at least the following year. In particular, it should be noted that December 31, 1996 prices were much higher than year-end prices for the last several years and substantially higher than the average prices received in each of the last several years. It is not possible to predict whether the December 1996 pricing level is indicative of a new trend toward higher energy prices or a short-term deviation from the recent history of low to moderate prices; therefore, management is unable to predict whether future oil and gas prices will (i) stabilize, (ii) increase, or (iii) decrease. 19 Results of Operations 1979-1 Program -------------- Year Ended December 31, 1996 Compared to Year Ended December 31, 1995 ------------------------------------- Total oil and gas sales increased $103,715 (26.2%) for the year ended December 31, 1996 as compared to the year ended December 31, 1995. Of this increase, approximately $209,000 was related to an increase in the average price of gas sold, partially offset by a decrease of approximately $100,000 related to a decrease in volumes of gas sold. Volumes of oil and gas sold decreased 439 barrels and 48,576 Mcf, respectively, for the year ended December 31, 1996 as compared to the year ended December 31, 1995. The decrease in volumes of oil sold resulted primarily from a positive prior period adjustment made by the purchaser on one well during the year ended December 31, 1995. The decrease in volumes of gas sold resulted primarily from (i) the depletion of reserves on one well during the year ended December 31, 1996 and (ii) normal declines in production due to diminished gas reserves on another well. Average oil and gas prices increased to $21.42 per barrel and $2.06 per Mcf, respectively, for the year ended December 31, 1996 from $18.03 per barrel and $1.33 per Mcf, respectively, for the year ended December 31, 1995. Oil and gas production expenses (including lease operating expenses and production taxes) decreased $15,177 (12.8%) for the year ended December 31, 1996 as compared to the year ended December 31, 1995. This decrease resulted primarily from (i) the decreases in volumes of oil and gas sold during the year ended December 31, 1996 as compared to the year ended December 31, 1995 and (ii) workover expenses incurred on one well during the year ended December 31, 1995 in order to improve the recovery of reserves. As a percentage of oil and gas sales, these expenses decreased to 20.6% for the year ended December 31, 1996 from 29.9% for the year ended December 31, 1995. This percentage decrease was primarily due to the increases in the average prices of oil and gas sold during the year ended December 31, 1996 as compared to the year ended December 31, 1995. 20 Depreciation, depletion, and amortization of oil and gas properties decreased $20,562 (37.9%) for the year ended December 31, 1996 as compared to the year ended December 31, 1995. This decrease resulted primarily from (i) the decreases in volumes of oil and gas sold during the year ended December 31, 1996 as compared to the year ended December 31, 1995 and (ii) an upward revision in the estimate of remaining gas reserves at December 31, 1996. As a percentage of oil and gas sales, this expense decreased to 6.7% for the year ended December 31, 1996 from 13.7% for the year ended December 31, 1995. This percentage decrease was primarily due to the dollar decrease in depreciation, depletion, and amortization discussed above and the increases in the average prices of oil and gas sold during the year ended December 31, 1996 as compared to the year ended December 31, 1995. General and administrative expenses remained relatively constant for the year ended December 31, 1996 as compared to the year ended December 31, 1995. As a percentage of oil and gas sales, these expenses decreased to 10.8% for the year ended December 31, 1996 from 13.7% for the year ended December 31, 1995. This percentage decrease was primarily due to the increases in oil and gas sales during the year ended December 31, 1996 as compared to the year ended December 31, 1995 as discussed above. Year Ended December 31, 1995 Compared to Year Ended December 31, 1994 ------------------------------------- Total oil and gas sales decreased $4,205 (1.0%) for the year ended December 31, 1995 as compared to the year ended December 31, 1994. Of this decrease, approximately $68,000 was related to a decrease in the average price of gas sold, partially offset by increases of approximately $3,000 and $59,000, respectively, related to increases in volumes of oil and gas sold and an increase of approximately $1,000 related to an increase in the average price of oil sold. Volumes of oil and gas sold increased 140 barrels and 44,259 Mcf, respectively, for the year ended December 31, 1995 as compared to the year ended December 31, 1994. The increase in volumes of gas sold was primarily a result of (i) significant positive prior period volume adjustments on two wells during the year ended December 31, 1995 and (ii) increased production on another well during the year ended December 31, 1995 as compared to the year ended December 31, 1994 as a result of recent recompletion activities on the well. Average gas prices decreased to $1.33 per Mcf for the year ended December 31, 1995 from $1.61 per Mcf for the year ended December 31, 1994, while average oil prices increased to $18.03 per barrel for the year ended December 31, 1995 from $16.08 per barrel for the year ended December 31, 1994. 21 Oil and gas production expenses (including lease operating expenses and production taxes) increased $37,053 (45.6%) for the year ended December 31, 1995 as compared to the year ended December 31, 1994. This increase was primarily a result of workover charges incurred on one well during the year ended December 31, 1995 in order to improve the recovery of reserves and the increase in volumes of gas sold during the year ended December 31, 1995 as compared to the year ended December 31, 1994. As a percentage of oil and gas sales, these expenses increased to 29.9% for the year ended December 31, 1995 from 20.3% for the year ended December 31, 1994. This percentage increase was primarily a result of the dollar increase in oil and gas production expenses related to the workover charges discussed above and the decrease in the average price of gas sold for the year ended December 31, 1995 as compared to the similar period in 1994. Depreciation, depletion, and amortization of oil and gas properties decreased $15,802 (22.6%) for the year ended December 31, 1995 as compared to the year ended December 31, 1994. This decrease was primarily a result of a significant upward revision in the estimate of remaining gas reserves at December 31, 1995. As a percentage of oil and gas sales, this expense decreased to 13.7% for the year ended December 31, 1995 from 17.5% for the year ended December 31, 1994. This decrease was primarily a result of the dollar decrease in depreciation, depletion, and amortization discussed above. General and administrative expenses increased slightly by $2,819 (5.5%) for the year ended December 31, 1995 as compared to the year ended December 31, 1994. This increase resulted primarily from an increase in professional fees and printing and postage fees during the year ended December 31, 1995 as compared to the year ended December 31, 1994. As a percentage of oil and gas sales, these expenses remained relatively stable, increasing only slightly to 13.7% for the year ended December 31, 1995 from 12.9% for the year ended December 31, 1994 due to the dollar increase in general and administrative expenses discussed above. 22 1979-2 Program -------------- Year Ended December 31, 1996 Compared to Year Ended December 31, 1995 ------------------------------------- Total oil and gas sales increased $245,579 (50.8%) for the year ended December 31, 1996 as compared to the year ended December 31, 1995. Of this increase, approximately $289,000 was related to an increase in the average price of gas sold, partially offset by a decrease of approximately $42,000 related to a decrease in volumes of gas sold. Volumes of oil and gas sold decreased 278 barrels and 17,521 Mcf, respectively, for the year ended December 31, 1996 as compared to the year ended December 31, 1995. The decrease in volumes of oil sold resulted primarily from normal declines in production due to diminished oil reserves on two wells. Average oil and gas prices increased to $21.07 per barrel and $2.37 per Mcf, respectively, for the year ended December 31, 1996 from $16.72 per barrel and $1.45 per Mcf, respectively, for the year ended December 31, 1995. Oil and gas production expenses (including operating expenses and production taxes) increased $43,385 (41.7%) for the year ended December 31, 1996 as compared to the year ended December 31, 1995. This increase resulted primarily from an increase in severance taxes associated with the increase in the average prices of oil and gas sold. As a percentage of oil and gas sales, these expenses remained relatively constant at 20.2% for the year ended December 31, 1996 compared to 21.5% for the year ended December 31, 1995. Depreciation, depletion, and amortization of oil and gas properties decreased $12,641 (15.0%) for the year ended December 31, 1996 as compared to the year ended December 31, 1995. This decrease resulted primarily from (i) the decrease in volumes of oil and gas sold during the year ended December 31, 1996 as compared to the year ended December 31, 1995 and (ii) an upward revision in the estimate of remaining gas reserves at December 31, 1996. As a percentage of oil and gas sales, this expense decreased to 9.8% for the year ended December 31, 1996 from 17.5% for the year ended December 31, 1995. This percentage decrease was primarily due to the dollar decrease in depreciation, depletion, and amortization discussed above and the increases in the average prices of oil and gas sold during the year ended December 31, 1996 as compared to the year ended December 31, 1995. 23 General and administrative expenses remained relatively constant for the year ended December 31, 1996 as compared to the year ended December 31, 1995. As a percentage of oil and gas sales, these expenses decreased to 5.5% for the year ended December 31, 1996 from 8.4% for the year ended December 31, 1995. This percentage decrease was primarily due to the increase in oil and gas sales during the year ended December 31, 1996 as compared to the year ended December 31, 1995, as discussed above. Year Ended December 31, 1995 Compared to Year Ended December 31, 1994 ------------------------------------- Total oil and gas sales decreased $533,877 (52.5%) for the year ended December 31, 1995 as compared to the year ended December 31, 1994. Of this decrease, approximately $378,000 was related to a decrease in volumes of gas sold and approximately $132,000 was related to a decrease in the average price of gas sold. Volumes of oil and gas sold decreased 1,662 barrels and 260,514 Mcf, respectively, for the year ended December 31, 1995 as compared to the year ended December 31, 1994. The decreases in volumes of oil and gas sold was primarily a result of significant positive prior period volume adjustments from various purchasers on several wells during the year ended December 31, 1994. Average gas prices decreased to $1.45 per Mcf for the year ended December 31, 1995 from $1.68 per Mcf for the year ended December 31, 1994, while the average price of oil sold increased to $16.72 per barrel for the year ended December 31, 1995 from $15.77 per barrel for the year ended December 31, 1994. Oil and gas production expenses (including lease operating expenses and production taxes) decreased $149,731 (59.0%) for the year ended December 31, 1995 as compared to the year ended December 31, 1994. This decrease resulted primarily from (i) lower operating expenses due to decreased oil and gas production in 1995 and (ii) lower production taxes due to the decrease in oil and gas sales during the year ended December 31, 1995 as compared to the year ended December 31, 1994. As a percentage of oil and gas sales, these expenses decreased to 21.5% for the year ended December 31, 1995 from 24.9% for the year ended December 31, 1994. This percentage decrease was primarily a result of the dollar decrease discussed above, partially offset by the decrease in the average price of gas sold for the year ended December 31, 1995 as compared to the year ended December 31, 1994. 24 Depreciation, depletion, and amortization of oil and gas properties decreased $160,239 (65.5%) for the year ended December 31, 1995 as compared to the year ended December 31, 1994. This dollar decrease was primarily a result of (i) an upward revision in the estimate of remaining gas reserves at December 31, 1995 and (ii) the decreases in volumes of oil and gas sold during the year ended December 31, 1995 as compared to the year ended December 31, 1994. As a percentage of oil and gas sales, this expense decreased to 17.5% for the year ended December 31, 1995 from 24.1% for the year ended December 31, 1994. This percentage decrease was primarily a result of the dollar decrease in depreciation, depletion, and amortization expense discussed above. General and administrative expenses increased $2,716 (7.1%) for the year ended December 31, 1995 as compared to the year ended December 31, 1994. This increase resulted primarily from an increase in professional fees and printing and postage fees during the year ended December 31, 1995 as compared to the year ended December 31, 1994. As a percentage of oil and gas sales, these expenses increased to 8.4% for the year ended December 31, 1995 from 3.7% for the year ended December 31, 1994. This percentage increase was primarily due to the dollar 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 production levels for the year ended December 31, 1996, the 1979-1 Program's and 1979-2 Program's proved reserve quantities at December 31, 1996 would have a life of approximately 4.5 and 3.2 years, respectively, for gas reserves and 8.4 and 9.5 years, respectively, for oil reserves. However, since the Programs' reserve estimates are based on oil and gas prices at December 31, 1996, it is possible that a significant decrease in oil and gas prices from December 31, 1996 levels will reduce such reserves and their corresponding life-span. The Programs' 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. The Programs have no debt commitments. Cash for operational purposes will be provided by current oil and gas production. 25 The Samson Companies are currently in the process of evaluating certain oil and gas properties owned by the Programs and other entities of the Samson Companies. As a result of such evaluation, it is expected that certain of these properties will be placed in bid packages and offered for sale during the first half of 1997. It is likely that the Programs will have an interest in some of the properties being sold. It is currently estimated that the value of such sales, as a percentage of total proved reserves of either Program, will range from 1% to 10%. The decision to accept any offer for the purchase of a property owned by one or both of the Programs will be made by Dyco after giving due consideration to the offer price and Dyco's estimate of both the property's remaining proved reserves and future operating costs. Net proceeds from the sale of any such properties will be distributed to the Programs and will be included in the calculation of the Programs' cash distributions for the quarter immediately following the Programs' receipt of the proceeds. Following completion of any sale, the Programs' quantity of proved reserves will be reduced. It is also possible that the Programs' repurchase values and future cash distributions could decline as a result of a reduction of the Programs' reserve base. On the other hand, Dyco believes there will be beneficial operating efficiencies related to the Programs' remaining properties. This is primarily due to the fact that the properties being considered for sale are more likely to bear a higher ratio of operating expenses as compared to reserves than the properties not being considered for sale. The net effect of such property sales is difficult to predict as of the date of this Annual Report. There can be no assurance as to the amount of the Programs' future cash distributions. The Programs' ability to make cash distributions depends primarily upon the level of available cash flow generated by the Programs' operating activities, which will be affected (either positively or negatively) by many factors beyond the control of the Programs, 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 Programs are not replacing production through acquisitions of producing properties and drilling. If the Programs sell any of their properties as discussed above, the Programs' quantity of proved reserves will be reduced; therefore, it is possible that the Programs' future cash distributions could decline as a result of a reduction of the Programs' reserve base. 26 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 Programs in 1996. 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." 27 ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA REPORT OF INDEPENDENT ACCOUNTANTS TO THE PARTNERS DYCO OIL AND GAS PROGRAM 1979-1 LIMITED PARTNERSHIP We have audited the financial statements of the Dyco Oil and Gas Program 1979-1 Limited Partnership (a Minnesota limited partnership) as listed in Item 14(a) of this Annual Report. 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 in accordance with generally accepted auditing standards. Those standards require that we plan and perform the audit to obtain reasonable assurance about whether the financial statements are free of material misstatement. An audit includes examining, on a test basis, evidence supporting the amounts and dis- closures in the financial statements. An audit also includes assessing the accounting principles used and significant estimates made by management, as well as evaluating the overall financial statement presentation. We believe that our audits provide a reasonable basis for our opinion. In our opinion, the financial statements referred to above present fairly, in all material respects, the financial position of the Dyco Oil and Gas Program 1979-1 Limited Partnership at December 31, 1996 and 1995, and the results of its operations and cash flows for each of the three years in the period ended December 31, 1996, in conformity with generally accepted accounting principles. COOPERS & LYBRAND L.L.P. Tulsa, Oklahoma February 10, 1997 28 DYCO OIL AND GAS PROGRAM 1979-1 LIMITED PARTNERSHIP Balance Sheets December 31, 1996 and 1995 ASSETS ------ 1996 1995 -------- -------- CURRENT ASSETS: Cash and cash equivalents $ 59,449 $ 32,509 Accrued oil and gas sales, including $64,832 due from related parties at 1995 (Note 2) 101,981 74,181 ------- ------- Total current assets $161,430 $106,690 NET OIL AND GAS PROPERTIES, utilizing the full cost method 241,255 291,717 DEFERRED CHARGE 50,957 69,409 ------- ------- $453,642 $467,816 ======= ======= LIABILITIES AND PARTNERS' CAPITAL --------------------------------- CURRENT LIABILITIES: Accounts payable $ 4,342 $ 6,802 Gas imbalance payable 11,643 13,323 ------- ------- Total current liabilities $ 15,985 $ 20,125 ACCRUED LIABILITY 33,832 38,124 PARTNERS' CAPITAL: General Partner, issued and outstanding, 32 Units 4,039 4,096 Limited Partners, issued and outstanding, 3,140 Units 399,786 405,471 ------- ------- Total Partners' Capital $403,825 $409,567 ------- ------- $453,642 $467,816 ======= ======= The accompanying notes are an integral part of these financial statements. 29 DYCO OIL AND GAS PROGRAM 1979-1 LIMITED PARTNERSHIP Statements of Operations For the Years Ended December 31, 1996, 1995 and 1994 1996 1995 1994 -------- -------- -------- REVENUES: Oil and gas sales, including $344,098 and $389,812 of sales to related parties in 1995 and 1994 (Note 2) $500,208 $396,493 $400,698 Interest 2,353 2,066 1,232 ------- ------- ------- $502,561 $398,559 $401,930 COSTS AND EXPENSES: Lease operating $ 67,719 $ 90,080 $ 52,310 Production taxes 35,474 28,290 29,007 Depreciation, depletion, and amortization of oil and gas properties 33,690 54,252 70,054 General and administrative 54,220 54,317 51,498 ------- ------- ------- $191,103 $226,939 $202,869 ------- ------- ------- NET INCOME $311,458 $171,620 $199,061 ======= ======= ======= GENERAL PARTNER (1%) - NET INCOME $ 3,115 $ 1,716 $ 1,991 ======= ======= ======= LIMITED PARTNERS (99%) - NET INCOME $308,343 $169,904 $197,070 ======= ======= ======= NET INCOME per Unit $ 98 $ 54 $ 63 ======= ======= ======= UNITS OUTSTANDING 3,172 3,172 3,172 ======= ======= ======= The accompanying notes are an integral part of these financial statements. 30 DYCO OIL AND GAS PROGRAM 1979-1 LIMITED PARTNERSHIP Statements of Partners' Capital For the Three Years Ended December 31, 1996, 1995, and 1994 General Limited Partner Partners Total -------- ---------- ---------- Balances at December 31, 1993 $4,830 $478,136 $482,966 Cash distributions ( 2,379) ( 235,521) ( 237,900) Net income 1,991 197,070 199,061 ----- ------- ------- Balances at December 31, 1994 $4,442 $439,685 $444,127 Cash distributions ( 2,062) ( 204,118) ( 206,180) Net income 1,716 169,904 171,620 ----- ------- ------- Balances at December 31, 1995 $4,096 $405,471 $409,567 Cash distributions ( 3,172) ( 314,028) ( 317,200) Net income 3,115 308,343 311,458 ----- ------- ------- Balances at December 31, 1996 $4,039 $399,786 $403,825 ===== ======= ======= The accompanying notes are an integral part of these financial statements. 31 DYCO OIL AND GAS PROGRAM 1979-1 LIMITED PARTNERSHIP Statements of Cash Flows For the Years Ended December 31, 1996, 1995, and 1994 1996 1995 1994 ---------- ---------- ---------- CASH FLOWS FROM OPERATING ACTIVITIES: Net income $311,458 $171,620 $199,061 Adjustments to reconcile net income to net cash provided by operating activities; Depreciation, depletion, and amortization of oil and gas properties 33,690 54,252 70,054 (Increase) decrease in accrued oil and gas sales ( 27,800) ( 28,658) 44,405 (Increase) decrease in accounts receivable - Related Party - 13,447 ( 13,447) (Increase) decrease in deferred charge 18,452 4,763 ( 44,301) Increase (decrease) in accounts payable ( 2,460) 3,199 ( 2,793) Increase (decrease) in gas imbalance payable ( 1,680) 13,323 - Increase (decrease) in accrued liability ( 4,292) 2,502 35,622 ------- ------- ------- Net cash provided by operating activities $327,368 $234,448 $288,601 ------- ------- ------- CASH FLOWS FROM INVESTING ACTIVITIES: Proceeds from the sale of oil and gas properties $ 16,772 $ 2,561 $ 7,483 Additions to oil and gas properties - ( 81,982) ( 8,295) ------- ------- ------- Net cash provided (used) by investing activities $ 16,772 ($ 79,421) ($ 812) ------- ------- ------- CASH FLOWS FROM FINANCING ACTIVITIES: Cash distributions ($317,200) ($206,180) ($237,900) ------- ------- ------- Net cash used by financing activities ($317,200) ($206,180) ($237,900) ------- ------- ------- NET INCREASE (DECREASE) IN CASH AND CASH EQUIVALENTS $ 26,940 ($ 51,153) $ 49,889 CASH AND CASH EQUIVALENTS AT BEGINNING OF PERIOD 32,509 83,662 33,773 ------- ------- ------- CASH AND CASH EQUIVALENTS AT END OF PERIOD $ 59,449 $ 32,509 $ 83,662 ======= ======= ======= The accompanying notes are an integral part of these financial statements. 32 DYCO OIL AND GAS PROGRAM 1979-1 LIMITED PARTNERSHIP Notes to Financial Statements For the Years Ended December 31, 1996, 1995, and 1994 1. ORGANIZATION AND SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES Organization and Nature of Operations The Dyco Oil and Gas Program 1979-1 Limited Partnership (the "Program"), a Minnesota limited partnership, commenced operations on April 2, 1979. Dyco Petroleum Corporation ("Dyco") is the General Partner of the Program. Affiliates of Dyco owned 1,232.30 (38.8%) of the Program's Units at December 31, 1996. 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. 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. 33 Oil and Gas Properties Oil and gas operations are accounted for using the full cost method of accounting. All productive and non-productive costs associated with the acquisition, exploration, and development of oil and gas reserves are capitalized. Capitalized costs are depleted on 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, 1996, 1995, and 1994 were $0.14, $0.19, and $0.28, respectively. The Program's calculation of depreci-ation, 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. In addition, SEC rules provide that if prices decline subsequent to year end, any excess that results from these declines may also be charged to expense during the current year. 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, 1996 and 1995 represents costs deferred for lease operating expenses incurred in connection with the Program's underproduced gas imbalance position. At December 31, 1996, 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 224,876 Mcf, resulting in prepaid lease operating expenses of $50,957. At December 31, 1995, 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 248,512 Mcf, resulting in prepaid lease operating expenses of $69,409. 34 Accrued Liability The Accrued Liability at December 31, 1996 and 1995 represents charges accrued for lease operating expenses incurred in connection with the Program's overproduced gas imbalance position. At December 31, 1996, cumulative total gas sales volumes for overproduced wells exceeded the Program's pro-rata share of total gas production from these wells by 149,301 Mcf, resulting in accrued lease operating expenses of $33,832. At December 31, 1995, cumulative total gas sales volumes for overproduced wells exceeded the Program's pro-rata share of total gas production from these wells by 136,498 Mcf, resulting in accrued lease operating expenses of $38,124. 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 income 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 income 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. At December 31, 1996, total sales exceeded the Program's share of estimated total gas reserves on two wells by $11,643 (7,762 Mcf). At December 31, 1995, total sales exceeded the Program's share of estimated total gas reserves on one well by $13,323 (6,499 Mcf). 35 Use of Estimates in Financial Statements The preparation of financial statements in conformity with generally accepted accounting principles requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities and disclosure of contingent assets and liabilities at the date of the financial statements and the reported amounts of revenues and expenses during the reporting period. Actual results could differ from those estimates. Further, accrued oil and gas sales, the deferred charge, the gas imbalance payable, and the accrued liability all involve estimates which could materially differ from the actual amounts ultimately realized 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 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, 1996, 1995, and 1994, such expenses totaled $54,220, $54,317, and $51,498, respectively, of which $44,520 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. During 1994 and 1995 the Program sold gas at market prices to El Paso Energy Marketing Company, formerly known as Premier Gas Company ("El Paso"). El Paso, like other similar gas marketing firms, then resold such gas to third parties at market prices. El Paso was an affiliate of the Program until December 6, 1995. During 1995 and 1994, these sales totaled $344,098 and $389,812, respectively. At December 31, 1995 accrued oil and gas sales included $64,832 due from El Paso. 36 3. MAJOR CUSTOMERS The following purchasers individually accounted for more than 10% of the combined oil and gas sales of the Program for the years ended December 31, 1996, 1995, and 1994: Purchaser 1996 1995 1994 --------- ----- ----- ---- El Paso 94.8% 86.8% 97.3% Apache - % 12.5% - % In the event of interruption of purchases by these significant customers 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 were as follows: December 31, ---------------------------- 1996 1995 ------------- ------------- Proved properties $20,435,512 $20,452,284 Unproved properties, not subject to depreciation, depletion, and amortization - - ---------- ---------- $20,435,512 $20,452,284 Less accumulated depreciation, depletion, amortization, and valuation allowance ( 20,194,257) ( 20,160,567) ---------- ---------- Net oil and gas properties $ 241,255 $ 291,717 ========== ========== 37 Costs Incurred Costs incurred by the Program in connection with its oil and gas property acquisition, exploration, and development activities were as follows: December 31, ----------------------- 1996 1995 1994 ------- ------ ------ Acquisition of properties $ - $ - $ - Exploration costs - - - Development costs - 81,982 8,295 ------ ------ ----- Total costs incurred $ - $81,982 $8,295 ====== ====== ===== 38
Quantities of Proved Oil and Gas Reserves - Unaudited Set forth below is a summary of the changes in the net quantities of the Program's proved crude oil and gas reserves for the years ended December 31, 1996, 1995, and 1994. Proved reserves were estimated by petroleum engineers employed by affiliates of Dyco. All of the Program's reserves are located in the United States. 1996 1995 1994 -------------------- -------------------- -------------------- Oil Gas Oil Gas Oil Gas (Bbls) (Mcf) (Bbls) (Mcf) (Bbls) (Mcf) ------- ----------- ------- ----------- ------- ----------- Proved reserves, beginning of year 3,472 1,094,721 2,272 1,010,914 2,583 1,113,662 Revisions of previous estimates 108 222,455 2,017 370,888 366 139,958 Sales of reserves ( 9) ( 1,266) - ( 116) - - Extensions and discoveries - - - - - - Production ( 378) ( 238,389) ( 817) ( 286,965) ( 677) ( 242,706) ----- --------- ----- --------- ----- --------- Proved reserves, end of year 3,193 1,077,521 3,472 1,094,721 2,272 1,010,914 ===== ========= ===== ========= ===== ========= Proved developed reserves: Beginning of year 3,472 1,094,721 2,272 1,010,914 2,583 1,095,961 ----- --------- ----- --------- ----- --------- End of year 3,193 1,077,521 3,472 1,094,721 2,272 1,010,914 ===== ========= ===== ========= ===== ========= 39 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; con- sequently, 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. 40 REPORT OF INDEPENDENT ACCOUNTANTS TO THE PARTNERS DYCO OIL AND GAS PROGRAM 1979-2 LIMITED PARTNERSHIP We have audited the financial statements of the Dyco Oil and Gas Program 1979-2 Limited Partnership (a Minnesota limited partnership) as listed in Item 14(a) of this Annual Report. 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 in accordance with generally accepted auditing standards. Those standards require that we plan and perform the audit to obtain reasonable assurance about whether the financial statements are free of material misstatement. An audit includes examining, on a test basis, evidence supporting the amounts and dis- closures in the financial statements. An audit also includes assessing the accounting principles used and significant estimates made by management, as well as evaluating the overall financial statement presentation. We believe that our audits provide a reasonable basis for our opinion. In our opinion, the financial statements referred to above present fairly, in all material respects, the financial position of the Dyco Oil and Gas Program 1979-2 Limited Partnership at December 31, 1996 and 1995, and the results of its operations and cash flows for each of the three years in the period ended December 31, 1996, in conformity with generally accepted accounting principles. COOPERS & LYBRAND L.L.P. Tulsa, Oklahoma February 10, 1997 41 DYCO OIL AND GAS PROGRAM 1979-2 LIMITED PARTNERSHIP Balance Sheets December 31, 1996 and 1995 ASSETS ------ 1996 1995 -------- -------- CURRENT ASSETS: Cash and cash equivalents $123,603 $105,766 Accrued oil and gas sales, including $71,862 due from related parties at 1995 (Note 2) 168,871 91,623 ------- ------- Total current assets $292,474 $197,389 NET OIL AND GAS PROPERTIES, utilizing the full cost method 366,631 440,361 DEFERRED CHARGE 50,557 67,617 ------- ------- $709,662 $705,367 ======= ======= LIABILITIES AND PARTNERS' CAPITAL --------------------------------- CURRENT LIABILITIES: Accounts payable $ 11,114 $ 6,417 Gas imbalance payable 44,960 36,359 ------- ------- Total current liabilities $ 56,074 $ 42,776 ACCRUED LIABILITIES 6,313 - PARTNERS' CAPITAL: General Partner, issued and outstanding, 29 Units 6,473 6,626 Limited Partners, issued and outstanding, 2,860 Units 640,802 655,965 ------- ------- Total Partners' Capital $647,275 $662,591 ------- ------- $709,662 $705,367 ======= ======= The accompanying notes are an integral part of these financial statements. 42 DYCO OIL AND GAS PROGRAM 1979-2 LIMITED PARTNERSHIP Statements of Operations For the Years Ended December 31, 1996, 1995 and 1994 1996 1995 1994 -------- -------- ---------- REVENUES: Oil and gas sales, including $452,687 and $909,037 of sales to related parties in 1995 and 1994 (Note 2) $729,046 $483,467 $1,017,344 Interest and other income 6,280 6,738 8,284 ------- ------- --------- $735,326 $490,205 $1,025,628 COSTS AND EXPENSES: Lease operating $ 94,195 $ 67,295 $ 178,826 Production tax 53,147 36,662 74,862 Depreciation, depletion, and amortization of oil and gas properties 71,807 84,448 244,687 General and administrative 40,363 40,709 37,993 ------- ------- --------- $259,512 $229,114 $ 536,368 ------- ------- --------- NET INCOME $475,814 $261,091 $ 489,260 ======= ======= ========= GENERAL PARTNER (1%) - NET INCOME $ 4,758 $ 2,611 $ 4,893 ======= ======= ========= LIMITED PARTNERS (99%) - NET INCOME $471,056 $258,480 $ 484,367 ======= ======= ========= NET INCOME per Unit $ 165 $ 90 $ 169 ======= ======= ========= UNITS OUTSTANDING 2,889 2,889 2,889 ======= ======= ========= The accompanying notes are an integral part of these financial statements. 43 DYCO OIL AND GAS PROGRAM 1979-2 LIMITED PARTNERSHIP Statements of Partners' Capital For the Three Years Ended December 31, 1996, 1995, and 1994 General Limited Partner Partners Total --------- ---------- ---------- Balances at Dec. 31, 1993 $8,367 $828,353 $836,720 Cash distributions ( 4,767) ( 471,918) ( 476,685) Net income 4,893 484,367 489,260 ----- ------- ------- Balances at Dec. 31, 1994 $8,493 $840,802 $849,295 Cash distributions ( 4,478) ( 443,317) ( 447,795) Net income 2,611 258,480 261,091 ----- ------- ------- Balances at Dec. 31, 1995 $6,626 $655,965 $662,591 Cash distributions ( 4,911) ( 486,219) ( 491,130) Net income 4,758 471,056 475,814 ----- ------- ------- Balances at Dec. 31, 1996 $6,473 $640,802 $647,275 ===== ======= ======= The accompanying notes are an integral part of these financial statements. 44 DYCO OIL AND GAS PROGRAM 1979-2 LIMITED PARTNERSHIP Statements of Cash Flows For the Years Ended December 31, 1996, 1995, and 1994 1996 1995 1994 -------- -------- -------- CASH FLOWS FROM OPERATING ACTIVITIES: Net income $475,814 $261,091 $489,260 Adjustments to reconcile net income to net cash provided by operating activities; Depreciation, depletion, and amortization of oil and gas properties 71,807 84,448 244,687 (Increase) decrease in accrued oil and gas sales ( 77,248) 57,513 30,202 (Increase) decrease in deferred charge 17,060 ( 10,175) 103,937 Decrease in payable to General Partner - - ( 696,695) Increase in accounts payable 4,697 541 323 Increase in gas imbalance payable 8,601 34,023 2,336 Increase in accrued liability 6,313 - - ------- ------- ------- Net cash provided by operating activities $507,044 $427,441 $174,050 ------- ------- ------- CASH FLOWS FROM INVESTING ACTIVITIES: Proceeds from the sale of oil and gas properties $ 3,075 $ - $ - Additions to oil and gas properties ( 1,152) ( 3,546) ( 1,211) ------- ------- ------- Net cash provided (used) by investing activities $ 1,923 ($ 3,546) ($ 1,211) ------- ------- ------- CASH FLOWS FROM FINANCING ACTIVITIES: Cash distributions ($491,130) ($447,795) ($476,685) ------- ------- ------- Net cash used by financing activities ($491,130) ($447,795) ($476,685) ------- ------- ------- NET INCREASE (DECREASE) IN CASH AND CASH EQUIVALENTS $ 17,837 ($ 23,900) $303,846 CASH AND CASH EQUIVALENTS AT BEGINNING OF PERIOD 105,766 129,666 433,512 ------- ------- ------- CASH AND CASH EQUIVALENTS AT END OF PERIOD $123,603 $105,766 $129,666 ======= ======= ======= The accompanying notes are an integral part of these financial statements. 45 DYCO OIL AND GAS PROGRAM 1979-2 LIMITED PARTNERSHIP Notes to Financial Statements For the Years Ended December 31, 1996, 1995, and 1994 1. ORGANIZATION AND SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES Organization and Nature of Operations The Dyco Oil and Gas Program 1979-2 Limited Partnership (the "Program"), a Minnesota limited partnership, commenced operations on July 2, 1979. Dyco Petroleum Corporation ("Dyco") is the General Partner of the Program. Affiliates of Dyco owned 1,170.98 (40.5%) of the Program's Units at December 31, 1996. 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. 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. 46 Oil and Gas Properties Oil and gas operations are accounted for using the full cost method of accounting. All productive and non-productive costs associated with the acquisition, exploration, and development of oil and gas reserves are capitalized. Capitalized costs are depleted on 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, 1996, 1995, and 1994 were $0.24, $0.26, and $0.41, respectively. The Program's calculation of depreci-ation, 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. In addition, SEC rules provide that if prices decline subsequent to year end, any excess that results from these declines may also be charged to expense during the current year. 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, 1996 and 1995 represents costs deferred for lease operating expenses incurred in connection with the Program's underproduced gas imbalance position. At December 31, 1996, 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 213,322 Mcf, resulting in prepaid lease operating expenses of $50,557. At December 31, 1995, 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 319,409 Mcf, resulting in prepaid lease operating expenses of $67,617. Accrued Liability The Accrued Liability at December 31, 1996 represents charges accrued for lease operating expenses incurred in connection with the Program's overproduced gas imbalance position. At December 31, 1996, cumulative total gas sales volumes for overproduced wells exceeded the Program's pro-rata share of total gas production from these wells by 26,639 Mcf, resulting in accrued lease operating expenses of $6,313. No such liability was recorded at December 31, 1995. 47 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 income 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 income 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. At December 31, 1996, total sales exceeded the Program's share of estimated total gas reserves on one well by $44,960 (29,973 Mcf). At December 31, 1995, total sales exceeded the Program's share of estimated total gas reserves on one well by $36,359 (17,070 Mcf). Use of Estimates in Financial Statements The preparation of financial statements in conformity with generally accepted accounting principles requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities and disclosure of contingent assets and liabilities at the date of the financial statements and the reported amounts of revenues and expenses during the reporting period. Actual results could differ from those estimates. Further, accrued oil and gas sales, the deferred charge, the gas imbalance payable, and the accrued liability all involve estimates which could materially differ from the actual amounts ultimately realized 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. 48 2. TRANSACTIONS WITH RELATED PARTIES Under the terms of the Program Agreement, Dyco is entitled to receive a reimbursement for all direct expenses and general and administrative, geological, and engineering expenses it incurs on behalf of the Program. During the years ended December 31, 1996, 1995, and 1994, such expenses totaled $40,363, $40,709, and $37,993, respectively, of which $31,212 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. During 1994 and 1995 the Program sold gas at market prices to El Paso Energy Marketing Company, formerly known as Premier Gas Company ("El Paso"). El Paso, like other similar gas marketing firms, then resold such gas to third parties at market prices. El Paso was an affiliate of the Program until December 6, 1995. During 1995 and 1994, these sales totaled $452,687 and $909,037, respectively. At December 31, 1995 accrued oil and gas sales included $71,862 due from El Paso. 3. MAJOR CUSTOMERS The following purchaser individually accounted for more than 10% of the combined oil and gas sales for the years ended December 31, 1996, 1995, and 1994: Purchaser 1996 1995 1994 --------- ----- ----- ----- El Paso 74.8% 93.6% 89.4% In the event of interruption of purchases by this significant customer or the cessation or material change in availability of open-access transportation by the Program's pipeline transporters, the Program may encounter difficulty in marketing its gas and in maintaining historic sales levels. Alternative purchasers or transporters may not be readily available. 4. SUPPLEMENTAL OIL AND GAS INFORMATION The following supplemental information regarding the oil and gas activities of the Program is presented pursuant to the disclosure requirements promulgated by the SEC. 49 Capitalized Costs The Program's capitalized costs and accumulated depreciation, depletion, amortization, and valuation allowance were as follows: December 31, ---------------------------- 1996 1995 ------------- ------------- Proved properties $18,560,621 $18,562,544 Unproved properties, not subject to depreciation, depletion, and amortization - - ---------- ---------- $18,560,621 $18,562,544 Less accumulated depreciation, depletion, amortization, and valuation allowance ( 18,193,990) ( 18,122,183) ---------- ---------- Net oil and gas properties $ 366,631 $ 440,361 ========== ========== Costs Incurred Costs incurred by the Program in connection with its oil and gas property acquisition, exploration, and development activities were as follows: December 31, -------------------------- 1996 1995 1994 ------ ------ ------ Acquisition of properties $ - $ - $ - Exploration costs - - - Development costs 1,152 3,546 1,211 ----- ----- ----- Total costs incurred $1,152 $3,546 $1,211 ===== ===== ===== 50
Quantities of Proved Oil and Gas Reserves - Unaudited Set forth below is a summary of the changes in the net quantities of the Program's proved crude oil and gas reserves for the years ended December 31, 1996, 1995, and 1994. Proved reserves were estimated by petroleum engineers employed by affiliates of the Program. All of the Program's reserves are located in the United States. 1996 1995 1994 -------------------- -------------------- -------------------- Oil Gas Oil Gas Oil Gas (Bbls) (Mcf) (Bbls) (Mcf) (Bbls) (Mcf) -------- ----------- ------- ----------- ------- ----------- Proved reserves, beginning of year 13,652 1,137,576 8,440 1,296,960 6,870 1,702,349 Revisions of previous estimates 422 122,479 6,826 154,381 4,846 168,890 Sales of reserves ( 60) ( 8,044) - - - - Extensions and discoveries - - - - - - Production ( 1,336) ( 296,244) ( 1,614) ( 313,765) (3,276) ( 574,279) ------ --------- ------ --------- ----- --------- Proved reserves, end of year 12,678 955,767 13,652 1,137,576 8,440 1,296,960 ====== ========= ====== ========= ===== ========= Proved developed reserves: Beginning of year 13,652 1,137,576 8,440 1,296,960 6,001 1,679,239 ------ --------- ------ --------- ----- --------- End of year 12,678 955,767 13,652 1,137,576 8,440 1,296,960 ====== ========= ====== ========= ===== =========
51 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 substan- tially 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. 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 Programs are limited partnerships and have no directors or executive officers. The following individuals are directors and executive officers of Dyco, which serves as the General Partner. The business address of such directors and executive officers is Two West Second Street, Tulsa, Oklahoma 74103. NAME AGE POSITION WITH GENERAL PARTNERS ---------------- --- -------------------------------- Dennis R. Neill 44 President and Director Patrick M. Hall 38 Chief Financial Officer Judy K. Fox 45 Secretary The director will hold office until the next annual meeting of shareholders of Dyco and until his successor has been duly elected and qualified. All executive officers serve at the discretion of the Board of Directors. 52 Dennis R. Neill joined the Samson Companies 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 the Samson Companies, he 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; President and Director of Samson Properties Incorporated, Samson Hydrocarbons Company, Geodyne Resources, Inc. and its subsidiaries, Berry Gas Company, Circle L Drilling Company, and Compression, Inc.; and President and Chairman of the Board of Directors of Samson Securities Company. Patrick M. Hall joined the Samson Companies 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 the Samson Companies 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 the Samson Companies in 1990 and was named Secretary of Dyco on June 30, 1996. Prior to joining the Samson Companies, 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., Geodyne Resources, Inc. and its subsidiaries, Samson Hydrocarbons Company, and Samson Properties Incorporated. ITEM 11. EXECUTIVE COMPENSATION The Programs are limited partnerships and, therefore, have no officers or directors. The following table summarizes the amounts paid by the Programs as compensation and reimbursements to Dyco and its affiliates for the three years ended December 31, 1996: 53 Compensation/Reimbursement to Dyco and its affiliates Three Years Ended December 31, 1996 Type of Compensation/Reimbursement(1) Expense - ------------------------------------- ------------------------- 1996 1995 1994 ------- ------- ------- 1979-1 Program - -------------- Compensation: Operations $ (2) $ (2) $ (2) Gas Marketing $ (3) $ (3) $ (3) Reimbursements: General and Administrative, Geological, and Engineering Expenses and Direct Expenses(4) $44,520 $44,520 $44,520 1979-2 Program - -------------- Compensation: Operations $ (2) $ (2) $ (2) Gas Marketing $ (3) $ (3) $ (3) Reimbursements: General and Administrative, Geological, and Engineering Expenses and Direct Expenses(4) $31,212 $31,212 $31,212 - --------------- (1) The authority for all of such compensation and reimbursement is the Program Agreements. 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 Programs serve as operator of some of the Programs' 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 Programs to such affiliates is impossible to quantify as of the date of this Annual Report. 54 (3) During 1994 and 1995 El Paso, an affiliate of the Programs until December 6, 1995, purchased a portion of the Programs' gas at market prices and resold such gas at market prices directly to end-users and local distribution companies. For the years ended December 31, 1995 and 1994, the 1979-1 Program sold $344,098 and $389,812, respectively, of gas to El Paso. For the years ended December 31, 1995 and 1994, the 1979-2 Program sold $452,687 and $909,037, respectively, of gas to El Paso. After December 6, 1995, the Programs' gas was marketed by Dyco and its affiliates, who were reimbursed for such activities as general and administrative expenses. (4) The Programs reimburse 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 Programs. The directors, officers, and employees of Dyco and its affiliates receive no direct remuneration from the Programs for their services to the Programs. See "Salary Reimbursement Table" below. The allocable general and administrative, geological, and engineering expenses are apportioned on a reasonable basis between the Programs' 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 Programs 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 Programs for their services. However, to the extent such services represent direct involvement with the Programs, as opposed to general corporate functions, such persons' salaries are allocated to and reimbursed by the Programs. Such allocation to the Programs' 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 Programs' operations. 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, 1996: 55
1979-1 Program -------------- Salary Reimbursement Three Years Ended December 31, 1996 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 ($) ($) ($) ($) SARs(#) ($) ($) - --------------- ---- ------- ------- ------- ---------- -------- ------- ------- C. Philip Tholen, President, Chief Executive Officer(1)(2) 1994 - - - - - - - 1995 - - - - - - - 1996 - - - - - - - Dennis R. Neill, President(2)(3) 1996 - - - - - - - All Executive Officers, Directors, and Employees as a group(4) 1994 $24,263 - - - - - - 1995 $24,308 - - - - - - 1996 $26,044 - - - - - - --------------- (1) Mr. Tholen served as President and Chief Executive Officer of Dyco until June 30, 1996. (2) 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. Tholen or Mr. Neill. (3) Mr. Neill became President of Dyco on June 30, 1996. (4) 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 $100,000 per annum.
56
1979-2 Program -------------- Salary Reimbursement Three Years Ended December 31, 1996 Long Term Compensation ------------------------------- Annual Compensation Awards Payouts ------------------------- --------------------- ------- Securi- Other ties All Name Annual Restricted Under- Other and Compen- Stock lying LTIP Compen- Principal Salary Bonus sation Award(s) Options/ Payouts sation Position Year ($) ($) ($) ($) SARs(#) ($) ($) - --------------- ---- ------- ------- ------- ---------- -------- ------- ------- C. Philip Tholen, President, Chief Executive Officer(1)(2) 1994 - - - - - - - 1995 - - - - - - - 1996 - - - - - - - Dennis R. Neill, President(2)(3) 1996 - - - - - - - All Executive Officers, Directors, and Employees as a group(4) 1994 $17,011 - - - - - - 1995 $17,042 - - - - - - 1996 $18,259 - - - - - - - --------------- (1) Mr. Tholen served as President and Chief Executive Officer of Dyco until June 30, 1996. (2) 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. Tholen or Mr. Neill. (3) Mr. Neill became President of Dyco on June 30, 1996. (4) 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.
57 In addition to the compensation/reimbursements noted above, during the three years ended December 31, 1996, the Samson Companies were in the business of supplying field and drilling equipment and services to affiliated and unaffiliated parties in the industry. These companies may have provided equipment and services for wells in which the Programs have an interest. Such equipment and services were 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 Programs for a portion of such costs based upon the Programs' 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 Programs' Units as of January 31, 1997 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) - ---------------------------------------------- --------------- 1979-1 Program: - -------------- Samson Resources Company 1,232.30 (38.8%) All directors, officers, and affiliates of Dyco as a group and Dyco (5 persons) 1,232.30 (38.8%) 1979-2 Program: - -------------- Samson Resources Company 1,172.98 (40.6%) All directors, officers, and affiliates of Dyco as a group and Dyco (5 persons) 1,172.98 (40.6%) 58 To the best knowledge of the Programs and Dyco, there were no officers, directors, or 5% owners who were delinquent filers of reports required under section 16 of the Securities Exchange Act of 1934. ITEM 13. CERTAIN RELATIONSHIPS AND RELATED TRANSACTIONS Certain affiliates of Dyco engage in oil and gas activities independently of the Programs 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 Programs and such affiliates also create potential conflicts of interest. An affiliate of the Program owns a significant amount of the Programs' Units and therefore has an identity of interest with other limited partners with respect to the operations of the Programs. In order to attempt to assure limited liability for limited partners as well as an orderly conduct of business, management of the Programs is exercised solely by Dyco. The Program Agreements grant Dyco broad discretionary authority with respect to the Programs' participation in drilling prospects and expenditure and control of funds, including borrowings. These provisions are similar to those contained in prospectuses and partnership agreements for other public oil and gas partnerships. Broad discretion as to general management of the Programs involves circumstances where Dyco has conflicts of interest and where it must allocate costs and expenses, or opportunities, among the Programs and other competing interests. Dyco does not devote all of its time, efforts, and personnel exclusively to the Programs. Furthermore, the Programs do not have any employees, but instead rely on the personnel of the Samson Companies. The Programs thus compete with the Samson Companies (including other currently sponsored oil and gas programs) for the time and resources of such personnel. The Samson Companies devote such time and personnel to the management of the Programs as are indicated by the circumstances and as are consistent with Dyco's fiduciary duties. 59 Affiliates of the Programs are solely responsible for the negotiation, administration, and enforcement of oil and gas sales agreements covering the Programs' leasehold interests. Because affiliates of the Programs who provide services to the Programs have fiduciary or other duties to other members of the Samson Companies, contract amendments and negotiating positions taken by them in their effort to enforce contracts with purchasers may not necessarily repre- sent the positions that a Program would take if it were to administer its own contracts without involvement with other members of the Samson Companies. On the other hand, management believes that the Programs' negotiating strength and contractual positions have been enhanced by virtue of its affiliation with the Samson Companies. For a description of certain other relationships and related transactions see "Item 11. Executive Compensation." 60 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 Programs as of December 31, 1996 and 1995 and for the years ended December 31, 1996, 1995, and 1994 are filed as part of this report: Reports of Independent Accountants Balance Sheets Statements of Operations Statements of Partners' Capital Statements of Cash Flows Notes to Financial Statements (2) Financial Statement Schedules: None. (3) Exhibits: 4.1 Drilling Agreement dated April 2, 1979 for Dyco Drilling Program 1979-1 by and between Dyco Oil and Gas Program 1979-1, Dyco Petroleum Cor- poration, 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 10, 1992 and is hereby incorporated herein. 4.2 Form of Program Agreement for Dyco Oil and Gas Program 1979-1 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 10, 1992 and is hereby incorporated herein. 61 4.3 Amendment to Program Agreement for Dyco Oil and Gas Program 1979-1 dated February 9, 1989 filed as Exhibit 4.3 to Annual Report on Form 10-K for the year ended December 31, 1991 on April 10, 1992 and is hereby incorporated herein. 4.4 Certificate of Limited Partnership (as amended) for Dyco Oil and Gas Program 1979-1 Limited Partnership filed as Exhibit 4.4 to Annual Report on Form 10-K for the year ended December 31, 1991 on April 10, 1992 and is hereby incorporated herein. 4.5 Drilling Agreement dated July 2, 1979 for Dyco Drilling Program 1979-2 by and between Dyco Oil and Gas Program 1979-2, Dyco Petroleum Corporation, and Jaye F. Dyer filed as Exhibit 4.5 to Annual Report on Form 10-K for the year ended December 31, 1991 on April 10, 1992 and is hereby incorporated herein. 4.6 Form of Program Agreement for Dyco Oil and Gas Program 1979-2 by and between Dyco Petroleum Corporation and the Participants filed as Exhibit 4.6 to Annual Report on Form 10-K for the year ended December 31, 1991 on April 10, 1992 and is hereby incorporated herein. 4.7 Amendment to Program Agreement for Dyco Oil and Gas Program 1979-2 dated February 9, 1989 filed as Exhibit 4.7 to Annual Report on Form 10-K for the year ended December 31, 1991 on April 10, 1992 and is hereby incorporated herein. 4.8 Certificate of Limited Partnership (as amended) for Dyco Oil and Gas Program 1979-2 Limited Partnership filed as Exhibit 4.8 to Annual Report on Form 10-K for the year ended December 31, 1991 on April 10, 1992 and is hereby incorporated herein. *27.1 Financial Data Schedule containing summary financial information extracted from the Dyco Oil and Gas Program 1979-1 Limited Partner-ship's financial statements as of December 31, 1996 and for the year ended December 31, 1996. 62 *27.2 Financial Data Schedule containing summary financial information extracted from the Dyco Oil and Gas Program 1979-2 Limited Partner-ship's financial statements as of December 31, 1996 and for the year ended December 31, 1996. All other Exhibits are omitted as inapplicable. ------------------ * Filed herewith. (b) Reports on Form 8-K for the fourth quarter of 1996: None. 63 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 1979-1 LIMITED PARTNERSHIP By: DYCO PETROLEUM CORPORATION General Partner February 20, 1997 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 February 20, 1997 ------------------- Director (Principal Dennis R. Neill Executive Officer) /s/Patrick M. Hall Chief Financial February 20, 1997 ------------------- Officer (Principal Patrick M. Hall Financial and Accounting Officer) /s/Judy K. Fox Secretary February 20, 1997 ------------------- Judy K. Fox 64 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 1979-2 LIMITED PARTNERSHIP By: DYCO PETROLEUM CORPORATION General Partner February 20, 1997 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 February 20, 1997 ------------------- Director (Principal Dennis R. Neill Executive Officer) /s/Patrick M. Hall Chief Financial February 20, 1997 ------------------- Officer (Principal Patrick M. Hall Financial and Accounting Officer) /s/Judy K. Fox Secretary February 20, 1997 ------------------- Judy K. Fox 65 INDEX TO EXHIBITS Exhibit Number Description - ------- ----------- 4.1 Drilling Agreement dated April 2, 1979 for Dyco Drilling Program 1979-1 by and between Dyco Oil and Gas Program 1979- 1, 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 10, 1992 and is hereby incorporated herein. 4.2 Form of Program Agreement for Dyco Oil and Gas Program 1979- 1 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 10, 1992 and is hereby incorporated herein. 4.3 Amendment to Program Agreement for Dyco Oil and Gas Program 1979-1 dated February 9, 1989 filed as Exhibit 4.3 to Annual Report on Form 10-K for the year ended December 31, 1991 on April 10, 1992 and is hereby incorporated herein. 4.4 Certificate of Limited Partnership (as amended) for Dyco Oil and Gas Program 1979-1 Limited Partnership filed as Exhibit 4.4 to Annual Report on Form 10-K for the year ended Decem- ber 31, 1991 on April 10, 1992 and is hereby incorporated herein. 4.5 Drilling Agreement dated July 2, 1979 for Dyco Drilling Pro- gram 1979-2 by and between Dyco Oil and Gas Program 1979-2, Dyco Petroleum Corporation, and Jaye F. Dyer filed as Exhibit 4.5 to Annual Report on Form 10-K for the year ended December 31, 1991 on April 10, 1992 and is hereby incorporated herein. 4.6 Form of Program Agreement for Dyco Oil and Gas Program 1979- 2 by and between Dyco Petroleum Corporation and the Participants filed as Exhibit 4.6 to Annual Report on Form 10-K for the year ended December 31, 1991 on April 10, 1992 and is hereby incorporated herein. 4.7 Amendment to Program Agreement for Dyco Oil and Gas Program 1979-2 dated February 9, 1989 filed as Exhibit 4.7 to Annual Report on Form 10-K for the year ended December 31, 1991 on April 10, 1992 and is hereby incorporated herein. 66 4.8 Certificate of Limited Partnership (as amended) for Dyco Oil and Gas Program 1979-2 Limited Partnership filed as Exhibit 4.8 to Annual Report on Form 10-K for the year ended Decem- ber 31, 1991 on April 10, 1992 and is hereby incorporated herein. *27.1 Financial Data Schedule containing summary financial information extracted from the Dyco Oil and Gas Program 1979-1 Limited Partnership's financial statements as of December 31, 1996 and for the year ended December 31, 1996. *27.2 Financial Data Schedule containing summary financial information extracted from the Dyco Oil and Gas Program 1979-2 Limited Partnership's financial statements as of December 31, 1996 and for the year ended December 31, 1996. - ------------------ * Filed herewith. 67 EX-27 2
5 0000806573 DYCO OIL & GAS PROGRAM 1979-1 LIMITED PARTNERSHIP 12-MOS DEC-31-1996 JAN-01-1996 DEC-31-1996 59,449 0 101,981 0 0 161,430 20,435,512 20,194,257 453,642 15,985 0 0 0 0 403,825 453,642 500,208 502,561 0 191,103 0 0 0 311,458 0 311,458 0 0 0 311,458 98 0
EX-27 3
5 0000806574 DYCO OIL & GAS PROGRAM 1978-2 LIMITED PARTNERSHIP 12-MOS DEC-31-1996 JAN-01-1996 DEC-31-1996 123,603 0 168,871 0 0 292,474 18,560,621 18,193,990 709,662 56,074 0 0 0 0 647,275 709,662 729,046 735,326 0 259,512 0 0 0 475,814 0 475,814 0 0 0 475,814 165 0
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