10-K 1 d95491e10-k.txt FORM 10-K FOR FISCAL YEAR END DECEMBER 31, 2001 -------------------------------------------------------------------------------- SECURITIES AND EXCHANGE COMMISSION WASHINGTON, D.C. 20549 FORM 10-K (Mark One) [X] ANNUAL REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934 FOR THE FISCAL YEAR ENDED DECEMBER 31, 2001 OR [] TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934 FOR THE TRANSITION PERIOD FROM TO COMMISSION FILE NO. 2-84452-01 STERLING DRILLING FUND 1983-2, L.P. (Exact name of Registrant as specified in its charter) NEW YORK 13-3167551 (State or other jurisdiction of (I.R.S. Employer Identification No.) incorporation or organization) ONE LANDMARK SQUARE STAMFORD, CONNECTICUT 06901 (Address of principal executive offices) (Zip Code)

Registrant's telephone number, including area code: (203) 358-5700 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 (Title of Class) Indicate by check mark whether Registrant (1) has filed all reports required to be filed by Section 13 or 15(d) of the Securities Exchange Act of 1934 during the preceding 12 months (or for such shorter period that the registrant was required to file such reports), and (2) has been subject to such filing requirements for the past 90 days.YES X NO Indicate by check mark 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-K or any amendment to this Form 10-K. The Registrant has no voting stock. There is no market for the Units and therefore no market value of the Units is reported. The number of Units of the Registrant outstanding as of March 15, 2002, was: 15,697. DOCUMENTS INCORPORATED BY REFERENCE NONE -------------------------------------------------------------------------------- STERLING DRILLING FUND 1983-2, L.P. FORM 10-K ANNUAL REPORT FOR THE FISCAL YEAR ENDED DECEMBER 31, 2001 PART I ITEM 1. BUSINESS Sterling Drilling Fund 1983-2, L.P., formerly Sterling-Fuel Resources Drilling Fund 1983-2 (the "Registrant" or the "Partnership") is a limited partnership formed under the laws of the State of New York on May 26, 1983. The sole business of the Partnership was the drilling of formation extension wells principally for natural gas in various locations in the State of West Virginia. No exploratory drilling was undertaken. The principal place of business of the Partnership is at One Landmark Square, Stamford, Connecticut 06901, telephone (203) 358-5700. The Managing General Partner of the Partnership is PrimeEnergy Management Corporation, a New York corporation, which is a wholly-owned subsidiary of PrimeEnergy Corporation, a publicly held Delaware corporation. Messrs. Charles E. Drimal, Jr., Oliver J. Sterling and Samuel R. Campbell also are General Partners. Mr. Drimal is a Director, President and Chief Executive Officer of PrimeEnergy Management Corporation and PrimeEnergy Corporation, and Mr. Campbell is a Director of PrimeEnergy Corporation. The aggregate contributions to the Partnership were $15,697,000, all of which, net of the organization expenses of the Partnership, was expended in the drilling of such formation extension wells. Such properties are located in Clay, Roane, Calhoun, Wirt, Kanawha, Lincoln and Putnam Counties, West Virginia. The Partnership does not operate any of the properties in which it has an interest, but generally such properties are operated and serviced by Prime Operating Company, a Texas corporation, and Eastern Oil Well Service Company, a West Virginia corporation, both wholly-owned subsidiaries of PrimeEnergy Corporation. During 2001, the Partnership did not engage in any other development drilling activities or the acquisition of any significant additional properties, but engaged in the production of oil and gas from its producing properties in the usual and customary course. Since January 1, 2002, and to the date of this Report, the Partnership has not engaged in any drilling activities nor participated in the acquisition of any material producing oil and gas properties. During early 2001, PrimeEnergy Management negotiated a Farmout Agreement with Eastern American Energy. (EAE) covering leasehold interests in approximately 5,000 acres in Clay County, West Virginia. Acreage held by Sterling Drilling Fund 1983-2 Limited Partnership has been included in the Farmout Agreement. This agreement provided for a small cash bonus paid at closing and gives EAE the right but not the obligation to select acreage and drill a deep well on the selected acreage, subject to an overriding royalty interest due to the leasehold owners. This agreement closed in May 2001 and will be in effect till May 1, 2003. If EAE does not exercise their rights under this agreement PrimeEnergy will attempt to find other parties interested in this acreage, however there is no guarantee that a new agreement will be made. During 2000, PrimeEnergy Management negotiated a Farmout Agreement with Columbia Natural Resources, Inc. (CNR) covering leasehold interests in approximately 5,000 acres in Clay County, West Virginia. Acreage held by Sterling Drilling Fund 1983-2 Limited Partnership was included in the Farmout Agreement. Pursuant to this agreement, CNR had the right but not the obligation to select acreage and drill a deep well on the selected acreage, subject to an overriding royalty interest due to the leasehold owners. This agreement terminated in April 2001. CNR did not exercise their rights to select acreage and drill a well. COMPETITION AND MARKETS Competitors of the Partnership in the marketing of its oil and gas production include oil and gas companies, independent concerns, and individual producers and operators, many of which have financial resources, staffs and facilities substantially greater than those available to the Partnership. Furthermore, domestic producers of oil and gas must not only compete with each other in marketing their output, but must also compete with producers of imported oil and gas and alternative energy sources such as coal, nuclear power and hydro-electric power. The availability of a ready market for any oil and gas produced by the Partnership at acceptable prices per unit of production will depend upon numerous factors beyond the control of the Partnership, including the extent of domestic production and importation of oil and gas, the proximity of the Partnership's producing properties to gas pipelines and the availability and capacity of such pipelines, the marketing of other competitive fuels, fluctuation in demand, governmental regulation of production, refining, transportation and sales, general national and worldwide economic conditions, and pricing, use and allocation of oil and gas and their substitute fuels. The Partnership does not currently own or lease any bulk storage facilities or pipelines, other than adjacent to and used in connection with producing wells. The Partnership deals with a number of major and independent companies for the purchase of its oil and gas production, in the areas of production. In 2001, approximately $637,121 or 87.08% and $86,219 or 11.78% of the Partnership's gas production was sold to Dominion Field Services( formerly named Phoenix Diversified) and Cabot Oil & Marketing Corporation, respectively, and about $39,656 or 100% of the Partnership's oil production was sold to Clearfield Appalachian Holdings ( formerly named American Refining Group). None of the purchasers has any relationship or is otherwise affiliated with the Partnership. The Partnership believes that its current purchasers will continue to purchase oil and gas products and, if not, could be replaced by other purchasers. ENVIRONMENTAL MATTERS The petroleum industry is subject to numerous federal and state environmental statutes, regulations and other pollution controls. In general, the Partnership is, and will be subject to, present and future environmental statutes and regulations, and in the future the cost of its activities may materially increase as a result thereof. The Partnership's expenses relating to preserving the environment during 2001 as they relate to its oil and gas operations were not significant in relation to operating costs and the Partnership expects no material change in the near future. The Partnership believes that environmental regulations should not, in the future, result in a curtailment of production or otherwise have a materially adverse effect on the Partnership's operations or financial condition. REGULATION The Partnership's oil and gas operations are subject to a wide variety of federal, state and local regulations. Administrative agencies in such jurisdictions may promulgate and enforce rules and regulations relating to, among other things, drilling and spacing of oil and gas wells, production rates, prevention of waste, conservation of natural gas and oil, pollution control, and various other matters, all of which may affect the Partnership's future operations and production of oil and gas. The Partnership's natural gas production and prices received for natural gas are regulated by the Federal Energy Regulatory Commission ("FERC") and the Natural Gas Policy Act of 1978 and various state regulations. The Partnership is also subject to state drilling and proration regulations affecting its drilling operations and production rates. The FERC continues to regulate interstate natural gas pipeline transportation rates and service conditions pursuant to the NGA and NGPA. Federal regulation of interstate transporter's affects the marketing of natural gas produced by the Partnership as well as the revenues received by the Partnership for sales of such natural gas. Since the latter part of 1985, through its Order Nos. 436, 500 and 636 rulemakings, the FERC has endeavored to make natural gas transportation accessible to gas buyers and sellers on an open and non-discriminatory basis. The FERC's efforts have significantly altered the marketing and pricing of natural gas. No prediction can be made as to what additional legislation may be proposed, if any, affecting the competitive status of a gas producer, restricting the prices at which a producer may sell its gas, or the market demand for gas, nor can it be predicted which proposals, including those presently under consideration, if enacted, might be effective. Additional proposals and proceedings that might affect the natural gas industry are considered from time to time by Congress, the FERC, state regulatory bodies and the courts. The Partnership cannot predict when or if any such proposals might become effective, or their effect, if any, on the Partnership's operations. The Partnership believes that it will comply with all orders and regulation changes applicable to its operations. However, in view of the many uncertainties with respect to the current controls, including their duration and possible modification together with any new proposals that may be enacted, the Partnership cannot predict the overall effect, if any, of such controls on its operations. TAXATION The Partnership received an opinion of its counsel that the Partnership would be classified as a partnership and the holders of Partnership Units would be treated as limited partners for federal income tax purposes. The Partnership itself, to the extent that it is treated for federal income tax purposes as a partnership, is not subject to any federal income taxation, but it is required to file annual partnership returns. Each holder of Partnership Units will be allocated his distributive shares of the Partnership's income, gain, profit, loss, deductions, credits, tax preference items and distributions for any taxable year of the Partnership ending within or with his taxable year without regard as to whether such holder has received or will receive any cash distributions from the Partnership. ITEM 2. PROPERTIES The Partnership has no interest in any properties other than its oil and gas properties. The information set forth below summarizes the Partnership's oil and gas wells, production and reserves, for the periods indicated. PRODUCING WELLS AND OPERATING INFORMATION The Partnership, following its formation, and in December, 1983, contracted for the drilling of 52 development wells, which resulted in 51 producing wells and one dry hole. As of December 31, 2001, the Partnership had ownership interests in the following gross and net producing oil and gas wells and gross and net producing acres.(1) The Partnership has no material undeveloped leasehold, mineral or royalty acreage. Producing wells:

~~Producing wells:~~ Gross Net ----- ----- Oil Wells.........................~~........~~ 1 1 Gas Wells.........................~~.......~~ 60 48.3 Producing acres...................~~....~~ 6,086 4,898

(1) A gross well is a well in which an interest is owned; a net well is the sum of the interests owned in gross wells. Wells are classified by their primary product. Some wells produce both oil and gas. The following table sets forth the Partnership's oil and gas production, average sales prices and average production costs as of and for the periods indicated:

YEAR ENDED DECEMBER 31, ---------------------------------------------------------------------- 2001 2000 1999 1998 1997 ~~1996~~ ---------- ---------- ---------- ---------- ---------- Production: Oil and Condensate (bbl) 1,748 1,861 1,790 2,049 2,158 ~~1,598~~ Gas (Mcf) 140,730 141,004 118,204 114,667 121,542 ~~129,675~~ Average Price of Sales: Oil and Condensate (bbl) 22.69 26.91 15.63 12.14 18.50 ~~19.45~~ Gas (Mcf) 5.20 3.57 2.48 2.95 3.11 ~~2.43~~ Production Expense per Dollar Of Operating Revenue 0.47 0.43 0.47 0.51 0.46 ~~0.44~~

OIL AND GAS RESERVES The Partnership's interests in proved developed oil and gas properties have been evaluated by Ryder Scott Company,L.P. for the periods indicated below. All of the Partnership's reserves are located in the continental United States. The following table summarizes the Partnership's oil and gas reserves at the dates shown (figures rounded):

Proved Developed As of ----------------------------------------------- 12-31 Oil (bbls) Gas (Mcf) ----- ---------- ---------~~-------~~ ~~1996 19,500 2,535,000~~ 1997 21,000 2,384,000 1998 17,700 2,165,400 1999 21,460 1,954,600 2000 20,400 2,321,540 2001 21,340 2,205,100

The estimated future net revenue using current prices and costs as of the dates indicated, exclusive of income taxes (at a 10% discount for estimated timing of cash flow) for the Partnership's proved developed oil and gas reserves for the periods indicated are summarized as follows (figures rounded):

Proved Developed ~~--------------------~~ As of Future Net Present Value of 12-31 Revenue $ Future Net Revenue $ ----- ---------- -------------------- ~~1996 $ 3,967,000 $ 1,578,300~~ 1997 3,351,400 1,288,800 1998 2,708,600 1,009,000 1999 3,051,300 1,368,500 2000 19,003,750 7,413,300 2001 3,408,560 1,477,000

The estimated reserve quantities and future income quantities are related to hydrocarbon prices. Therefore, volumes of reserves actually recovered and amounts of income actually received may differ significantly from the estimated quantities presented in this report. In accordance with FASB Statement No. 69, December 31, 2001 market prices were determined using the daily oil price or daily gas sales price ("spot price") adjusted for oilfield or gas gathering hub and wellhead price differentials (e.g. grade, transportation, gravity, sulfur, and BS&W) as appropriate. Also, in accordance with SEC and FASB specifications, changes in market prices subsequent to December 31, 2000 and 2001 were not considered. The spot price for gas at December 31, 2000 was $9.23 per MMBTU. The range of spot prices during the year 2000 was a low of $2.14 and a high of $10.50 and the average was $4.28. The spot price for gas at December 31, 2001 was $2.63 per MMBTU. The range of spot prices during the year 2001 was a low of $1.77 and a high of $10.29 and the average was $3.94. The range during the first quarter of 2002 has been from $2.01 to $3.31 with an average of $2.42. The recent futures market prices have been in the $3.00 range. While it may reasonably be anticipated that the prices received by Sterling Drilling Fund 1983-2 for the sale of its production may be higher or lower than the prices used in this evaluation, as described above, and the operating costs relating to such production may also increase or decrease from existing levels, such possible changes in prices and costs were, in accordance with rules adopted by the SEC, omitted from consideration in making this evaluation for the SEC case. Actual volumes produced, prices received and costs incurred by the partnership may vary significantly from the SEC case. Since January 1, 2001, the Partnership has not filed any estimates of its oil and gas reserves with, nor were any such estimates included in any reports, to any federal authority or agency, other than the Securities and Exchange Commission. ITEM 3. LEGAL PROCEEDINGS The Partnership is not a party to, nor is any of its property the subject of, any legal proceedings actual or threatened, which would have a material adverse effect on the business and affairs of the Partnership. ITEM 4. SUBMISSION OF MATTERS TO A VOTE OF SECURITY HOLDERS There were no matters submitted during 2001 for vote by the holders of Partnership Units. PART II ITEM 5. MARKET FOR THE REGISTRANT'S COMMON EQUITY AND RELATED STOCKHOLDER MATTERS There is no market for the Limited Partnership Units (the "Units) of the Partnership. As of March 15, 2002, there were 900 holders of record of the Units. The Units are not regarded as stock and payments or distributions to holders of Units are not made in the form of dividends. Cash distributions to the holders of Units for 2001 aggregated $78,485. Aggregate cash distributions to the holders of the Units as of December 31, 2001, is $1,907,186. The Managing General Partner may purchase Units directly from the unit holders if presented to the Managing General Partner, subject to conditions, including limitations on numbers of Units, and at a price to be fixed by the Managing General Partner in accordance with certain procedures, all as provided for in the Limited Partnership Agreement of the Partnership. ITEM 6. SELECTED FINANCIAL DATA The information required hereunder is set forth under "Selected Financial Data" in the Financial Information section included in this Report. The index to the Financial Information section is at page F-1. ITEM 7. MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS The information required hereunder is set forth under "Management's Discussion and Analysis of Financial Condition and Results of Operations" in the Financial Information section included in this Report. The index to the Financial Information section is at page F-1. ITEM 7A. QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK Registrant is a "small business issuer" as defined in the Securities and Exchange Act Rule 12b-2 and no information is required to be provided by this Item 7A. ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA The information required hereunder is set forth under "Report of Independent Public Accountants," "Balance Sheets," "Statements of Operations," "Statements of Changes in Partners' Equity," "Statements of Cash Flows" and "Notes to Financial Statements" in the Financial Information section included in this Report. The index to the Financial Information section is at page F-1. ITEM 9. CHANGES IN AND DISAGREEMENTS WITH ACCOUNTANTS ON ACCOUNTING AND FINANCIAL DISCLOSURE There was no disagreement between the Partnership and its certified public accountants on any matter of accounting principles or practices or financial statement disclosure. PART III ITEM 10. DIRECTORS AND EXECUTIVE OFFICERS OF THE REGISTRANT The Managing General Partner of the Partnership is PrimeEnergy Management Corporation, a New York corporation ("Management"). The principal business of Management is the management of the Partnership and other publicly and privately held exploration and development limited partnerships and joint ventures and publicly held asset and income fund limited partnerships. As of March 15, 2002, Management acts as the Managing General Partner in a total of 45 limited partnerships and joint ventures, of which 4 are publicly held, and is the Managing Trustee of 2 Delaware Business Trusts. The primary activity of such Partnerships, joint ventures and trusts is the production of oil and gas and Management, as the Managing General Partner of the Partnership, will devote such of its time as it believes necessary in the conduct and management of the business and affairs of the Partnership. Management, and other of the General Partners of the Partnership, are engaged in and intend to continue to engage in the oil and gas business for their own accounts and for the accounts of others. Management, which provides all of the executive, management and administrative functions of the Partnership, is a wholly owned subsidiary of PrimeEnergy Corporation ("PrimeEnergy"), a publicly held Delaware corporation. The principal offices of PrimeEnergy and Management are in Stamford, Connecticut. The operating subsidiaries of PrimeEnergy, Prime Operating Company and Eastern Oil Well Service Company maintain their principal offices in Houston, Texas, with district offices in Midland, Texas, Oklahoma City, Oklahoma, and Charleston, West Virginia. PrimeEnergy and its subsidiaries have approximately 200 employees, including their principal officers, providing management and administrative services, accounting, engineers, geologists, production engineers, land department personnel and field employees. Set forth below is information concerning the directors and executive officers of Management and PrimeEnergy that are involved with the conduct of the business and operations of the Partnership. Charles E. Drimal, Jr., age 54, is a Director and President of Management and has held those positions since May 1983. He is also a Director and President of Prime Energy and the operating subsidiaries. He graduated from the University of Maryland in 1970 and from Samford University School of Law in 1973 and is a member of the New York State Bar. Beverly A. Cummings, age 49, has been a Director and Vice President, Finance, of Management since August 1985. She is also a Director and Vice President, Finance, and Treasurer of PrimeEnergy and the operating subsidiaries. Ms. Cummings is a Certified Public Accountant and holds a Bachelor of Science degree from the State University of New York and a Master in Business Administration from Rutgers University. Lynne G. Pizor, age 42, has been Controller of Prime Operating Company since January 1992, and Eastern Oil Well Service Company since September 1990. She also held that position with Management from January 1986, through August 1994, and PrimeEnergy from May 1990, through August 1994. She joined Management in October 1984, as Manager of Partnership Accounting. She is a graduate of Wagner College with a Bachelor of Science degree in Economics and Business Administration and is a Certified Public Accountant. James F. Gilbert, age 69, has been Secretary of Management since June 1990, and has been Secretary of PrimeEnergy since March 1973, and was a Director of PrimeEnergy from that date to October 1987. He also serves as Secretary of the operating subsidiaries. He is an attorney in Dallas, Texas. ITEM 11. EXECUTIVE COMPENSATION The Partnership has no officers, directors or employees. The officers and employees of the Managing General Partner and PrimeEnergy perform all management and operational functions of the Partnership. The Partnership does not pay any direct salaries or other remuneration to the officers, directors or employees of the Managing General Partner or PrimeEnergy. The Managing General Partner is reimbursed for the general and administrative expenses of the Partnership, which are allocated to the Partnership, together with administrative work by third parties limited annually to 5% of the aggregate capital contribution of the holders of the Partnership Units. During 2001, the allocation of general and administrative expenses to the Partnership was approximately $100,800. ITEM 12. SECURITY OWNERSHIP OF CERTAIN BENEFICIAL OWNERS AND MANAGEMENT The following table shows as of March 16, 2000, the name and address and the number and percent of Units beneficially and directly owned by each person, entity or group, known to the Partnership to own more than 5% of the Units.

NUMBER NAME AND ADDRESS OF BENEFICIAL OWNER OF UNITS PERCENT ------------------------------------ -------- ------- PrimeEnergy Management Corporation One Landmark Square Stamford, CT 06901............................. 1,171 7.46% PrimeEnergy Corporation One Landmark Square Stamford, CT 06901............................. 3,~~261~~775 2024.7705%

ITEM 13. CERTAIN RELATIONSHIPS AND RELATED TRANSACTIONS Prime Operating Company acts as the operator for most of the producing oil and gas wells of the Partnership pursuant to operating agreements with the Partnership and other working interest owners, including other partnerships managed by the Managing General Partner. PrimeOperating Company was paid, in 2001, well operating fees ranging from about $248 to $686 per month per well. Well operating supplies and equipment and related servicing operations are generally provided by Eastern Oil Well Service Company. The Partnership pays its proportionate part of such operating fees and expenses. Such fees and expenses vary depending on such matters as the location of the well, the complexity of the producing equipment, whether wells produce oil or gas or both and similar factors. The Partnership believes that such services are as favorable to the Partnership as they would be if the Partnership entered into such transactions with unaffiliated third parties. In 2001 and 2000, the Partnership paid an aggregate of $194,034 and $147,899, respectively, in such fees and expenses. PART IV ITEM 14. EXHIBITS, FINANCIAL STATEMENT SCHEDULES, AND REPORTS ON FORM 8-K (a) The following documents are filed as a part of this Report: 1. Financial Statements (Index to the Financial Information at page F-1) 2. Financial Statement Schedules: Schedule V Property and Equipment - Oil and Gas Properties Schedule VI Accumulated Depreciation, Depletion and Amortization - Oil and Gas Properties 3. Exhibits: (3) Form of Agreement of Limited Partnership of Sterling Drilling Fund 1983-2 (Incorporated by reference to Exhibit (3) of Sterling Drilling Fund 1983-2 Form 10-K for the year ended December 31, 1994.) (23) Consent of Ryder Scott Company, L.P. (filed herewith) (b) Reports on Form 8-K: No reports on Form 8-K have been filed during the last quarter of the year covered by this Report. SIGNATURES Pursuant to the requirements of Section 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 authorized, on the 28 day of March, 2002. Sterling Drilling Fund 1983-2, L.P. By: PrimeEnergy Management Corporation Managing General Partner By: /S/ Charles E. Drimal Jr. ------------------------------------- Charles E. Drimal, Jr. 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 indicated and on the 28 day of March, 2002. /S/ Charles E. Drimal Jr. Director and President, -------------------------------- PrimeEnergy Management Corporation; Charles E. Drimal, Jr. The Principal Executive Officer /S/ Beverly A. Cummings Director and Vice President and Treasurer, -------------------------------- PrimeEnergy Management Corporation; Beverly A. Cummings The Principal Financial and Accounting Officer STERLING DRILLING FUND 1983-2, L.P. (A NEW YORK LIMITED PARTNERSHIP) INDEX TO FINANCIAL STATEMENTS AND SCHEDULES

Page No. -------- Selected Financial Data F-2 Management's Discussion and Analysis of Financial Condition and Results of Operations F-2 Report of Independent Public Accountants F-56 Financial Statements: Balance Sheets, December 31, ~~2000~~2001 and ~~1999~~2000 F-67 Statements of Operations for the Years Ended December 31, ~~2000~~2001, ~~1999~~2000 and ~~1998~~1999 F-78 Statements of Changes in Partners' Equity for the Years Ended December 31, ~~2000~~2001, ~~1999~~2000 and ~~1998~~1999 F-89 Statements of Cash Flow for the Years Ended December 31, ~~2000~~2001, ~~1999~~2000, and ~~1998~~1999 F-910 Notes to Financial Statements F-1011 Schedules: V - Property and Equipment - Oil and Gas Properties for the Years Ended December 31, ~~2000~~2001, ~~1999~~2000 and ~~1998~~1999 F-1819 VI - Accumulated Depreciation, Depletion, and Amortization - Oil and Gas Properties for the Years Ended December 31, ~~2000~~2001, ~~1999~~2000 and ~~1998~~1999 F-1920

All other schedules have been omitted as the information required is either included in the financial statements, related notes, or is not applicable. F-1 ITEM 6. SELECTED FINANCIAL DATA The following table summarizes certain selected financial data to highlight significant trends in the Registrant's financial condition and results of operations for the periods indicated. The selected financial data should be read in conjunction with the financial statements and related notes included elsewhere in this report.

Year Ended December 31, (000's omitted) ---------------------------------------------------------------------------- 2001 2000 1999 1998 1997 ~~1996~~ ---------- ---------- ---------- ---------- ---------- Revenues: ~~553~~837 ~~321~~572 327 364 431 ~~350~~ Net Income(Loss) Limited Partners 210 104 (23) (0.2) 33 ~~(4)~~ General Partners 77 44 5 11 22 12 Per equity unit 13.40 6.61 (1.47) (0.02) 2.10 ~~(0.23)~~ Total assets 1,507 1,321 1,224 1,292 1,331 ~~1,327~~ Cash Distributions: Limited Partners 3978 39 39 39 39 General Partners 23 11 11 11 12 12 Limited partners as a % of original contribution 0.2550% 0.25% 0.25% 0.25% 0.25%

ITEM 7. MANAGEMENT'S DISCUSSION & ANALYSIS OF FINANCIAL CONDITION & RESULTS OF OPERATIONS 1. Liquidity: The oil and gas industry is intensely competitive in all its phases. There is also competition between this industry and other industries in supplying energy and fuel requirements of industrial and residential consumers. It is not possible for the Registrant to calculate its position in the industry as the Registrant competes with many other companies having substantially greater financial and other resources. In accordance with the terms of the Agreement of Limited Partnership of the Partnership, the General Partners of the Registrant will make cash distributions of as much of the Partnership cash credited to the capital accounts of the partners as the General Partners have determined is not necessary or desirable for the payment of any contingent debts, liabilities or expenses for the conduct of the Partnership business. As of December 31, 2001, the General partners have distributed $1,907,186 or 12.15%, of original Limited Partner capital contributions, to the Limited Partners. The net proved oil and gas reserves of the Partnership are considered to be a primary indicator of financial strength and future liquidity. The present value of unescalated future net revenues (S.E.C. case) associated with such reserves, discounted at 10% as of December 31, 2001, was approximately $1,476,995 as compared to the discounted reserves as of December 31, 2000, which were approximately $7,413,300. Overall reservoir engineering is a subjective process of estimating underground accumulations of gas and oil that cannot be measured in an exact manner. The estimated reserve quantities and future income quantities are related to hydrocarbon prices. Therefore, volumes of reserves actually recovered and amounts of income actually received may differ significantly from the estimated quantities presented in this report. F-2 In accordance with FASB Statement No. 69, December 31, 2001 market prices were determined using the daily oil price or daily gas sales price ("spot price") adjusted for oilfield or gas gathering hub and wellhead price differentials (e.g. grade, transportation, gravity, sulfur, and BS&W) as appropriate. Also, in accordance with SEC and FASB specifications, changes in market prices subsequent to December 31, 2000 and 2001 were not considered. The spot price for gas at December 31, 2000 was $9.23 per MMBTU. The range of spot prices during the year 2000 was a low of $2.14 and a high of $10.50 and the average was $4.28. The spot price for gas at December 31, 2001 was $2.63 per MMBTU. The range of spot prices during the year 2001 was a low of $1.77 and a high of $10.29 and the average was $3.94. The range during the first quarter of 2002 has been from $2.01 to $3.31 with an average of $2.42. The recent futures market prices have been in the $3.00 range. While it may reasonably be anticipated that the prices received by Sterling Drilling Fund 1983-2 for the sale of its production may be higher or lower than the prices used in this evaluation, as described above, and the operating costs relating to such production may also increase or decrease from existing levels, such possible changes in prices and costs were, in accordance with rules adopted by the SEC, omitted from consideration in making this evaluation for the SEC case. Actual volumes produced, prices received and costs incurred by the partnership may vary significantly from the SEC case Since January 1, 2001, the Partnership has not filed any estimates of its oil and gas reserves with, nor were any such estimates included in any reports, to any federal authority or agency, other than the Securities and Exchange Commission. 2. Capital Resources: The Partnership was formed for the sole intention of drilling oil and gas wells. The Partnership entered into a drilling contract with an independent contractor in December 1993, for $13,400,000. Pursuant to the terms of this contract fifty-two wells were drilled resulting in fifty-one producing wells and one dry hole. 3. Results of operations: 2001 compared to 2000 The Partnership gas and oil production remained constant from 141,004 MCF and 1,861 barrels in 2000 to 140,730 MCF and 1,748 barrels in 2001. The partnership received a significantly higher average price per MCF from $3.57 in 2000 to $5.20 in 2001. The combination of constant gas production and high gas prices were the main factors to overall operating revenue to increase from $553,449 in 2000 to $771,282 in 2001. For most of 2001 the Partnership's revenue was based upon a higher contract price than was the average spot market price. A new contract was entered into in December 2001 and the Partnership will be paid based upon current spot market prices until November 2002. The Partnership's other income is a result of a cash bonus paid to the partnership for a farmout agreement. The farmout agreement allows a third party the right to drill a deep well on leasehold acerage owned by the partnership for a period of two years. If the third party exercises their rights within the two years the Partnership could receive an overriding royalty interest. Interest income fluctuates with changes in the interest rates received as well as the amount of cash in the bank at any given time. F-3 Some production expenses may be variable in nature, vary with production volumes or others are directly related to repairs, labor, location costs and maintenance of the wells and well site. Occasionally the Partnership will expend additional funds on light repairs or capital improvements, which the operator has deemed necessary. The operator expended funds on capital improvements in the amount of $37,607. These repairs and capital expenditures are considered an appropriate means to increase, sustain or halt changes in production. These repairs, which may include additional labor and well site maintence, as well as the additional or replacement equipment contributed to additional production operating cost incurred during 2001. The Partnership's production expenses increased from $231,866 in 2000 to $363,020 in 2001. General and administrative costs remained relatively unchanged from $123,270 in 2000 to $116,851 in 2001. The stable amounts reflect management's efforts to limit costs, both incurred and allocated to the Partnership. Management will use in-house resources if it will provide efficient and timely services to the partnership. Amounts in both years are substantially less than the $784,850 allocable to the Partnership under the Partnership Agreement. The Partnership records additional depreciation, depletion and amortization to the extent that the net capitalized costs exceed the undiscounted future net cash flows attributable to the Partnership. No additional depletion deduction was needed in 2000 or 2001. The overall Partnership depreciation and depletion expense was consistent with the current basis in the Partnership properties and the rates applied. 2000 compared to 1999 The Partnership experienced changes in gas and oil production 118,204 MCF and 1,790 barrels in 1999 to 141,004 MCF and 1,861 barrels in 2000. The partnership received a significantly higher average price per MCF and per barrel from $2.48 and $15.63 in 1999 to $3.57 and $26.91in 2000. The combination of positive production and prices changes contributed to overall operating revenue to increase from $321,377 in 1999 to $553,449 in 2000. The Partnership also received $12,395 as part of a one time settlement from a class action lawsuit it participated in. Interest income fluctuates with changes in the interest rates received as well as the amount of cash in the bank at any given time. Some production expenses may be variable in nature, vary with production volumes or others are directly related to repairs, labor, location costs and maintenance of the wells and well site. The expenditures made in 1999 were for the general upkeep and maintenance of the Partnership's wells. Occasionally the Partnership will expend additional funds on light repairs or capital improvements, which the operator has deemed necessary. . The operator expended funds on capital improvements in the amount of $87,732. These repairs and capital expenditures are considered an appropriate means to increase, sustain or halt changes in production. These repairs as well as the additional or replacement equipment contributed to additional production operating cost incurred during 2000. The Partnership's production expenses increased from $150,423 in 1999 to $231,866 in 2000. F-4 General and administrative costs remained relatively unchanged from $126,852 in 1999 to $123,270 in 2000. The stable amounts reflect management's efforts to limit costs, both incurred and allocated to the Partnership. Management will use in-house resources if it will provide efficient and timely services to the partnership. Amounts in both years are substantially less than the $784,850 allocable to the Partnership under the Partnership Agreement. The Partnership records additional depreciation, depletion and amortization to the extent that the net capitalized costs exceed the undiscounted future net cash flows attributable to the Partnership. No additional depletion deduction was needed in 1999 or 2000. The overall Partnership depreciation and depletion expense was consistent with the current basis in the Partnership properties and the rates applied. F-5 STERLING DRILLING FUND 1983-2, L.P. (a New York limited partnership) REPORT OF INDEPENDENT PUBLIC ACCOUNTANTS To the Partners of Sterling Drilling Fund 1983-2, L.P.: We have audited the accompanying balance sheets of Sterling Drilling Fund 1983-2, L.P. (a New York limited partnership) as of December 31, 2001 and 2000, and the related statements of operations, changes in partners' equity, and cash flows for the years ended December 31, 2001, 2000 and 1999. These financial statements are the responsibility of the Partnership's management. Our responsibility is to express an opinion on these financial statements based on our audits. We conducted our audits in accordance with auditing standards generally accepted in the United States of America. 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 disclosures 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 Sterling Drilling Fund 1983-2, L.P. as of December 31, 2001 and 2000, and the results of its operations and cash flows for the years ended December 31, 2001, 2000 and 1999 in conformity with accounting principles generally accepted in the United States of America. Our audits were made for the purpose of forming an opinion on the basic financial statements taken as a whole. The schedules listed in the index to financial statements and schedules are presented for purposes of complying with the Securities and Exchange Commission's rules and are not part of the basic financial statements. These schedules have been subjected to the auditing procedures applied in the examination of the basic financial statements and, in our opinion, fairly state in all material respects the financial data required to be set forth therein in relation to the basic financial statements taken as a whole. PUSTORINO, PUGLISI & CO., LLP New York, New York March 26, 2002 F-6 STERLING DRILLING FUND 1983-2 (A NEW YORK LIMITED PARTNERSHIP) BALANCE SHEETS DECEMBER 31, 2001 AND 2000

~~2000~~Assets ~~1999~~2001 2000 ------------ ------------ ~~Assets~~ Current Assets: Cash and cash equivalents (Note 2) $ ~~154~~385,~~612~~775 $ 75154,~~872~~612 Due from ~~affiliate~~affiliates (Note 6) 25,732 38,446 ~~39,003~~ ------------ ------------ Total Current Assets 411,507 193,058 ~~114,875~~ ------------ ------------ Oil and Gas Properties - successful efforts ~~method~~methods (~~Note~~note 3) - ~~(Schedules V and VI):~~ Leasehold costs 497,639 497,639 Wells and related facilities 13,~~034~~071,~~260~~867 1213,~~946~~034,~~528~~260 ------------ ------------ Total 13,~~531~~569,~~899~~506 13,~~444~~531,~~167~~899 Less - Accumulated depreciation, depletion and amortization (12,~~403~~473,~~819~~750) (12,~~335~~403,~~303~~819) ------------ ------------ ~~and amortization~~ 1,~~128~~095,~~080~~756 1,~~108~~128,~~864~~080 ------------ ------------ Total Assets $ 1,~~321~~507,~~138~~263 $ 1,~~223~~321,~~739~~138 ============ ============ Liabilities and Partners' Equity Total Current Liabilities $ -- $ -- ------------ ------------ Partners' Equity: Limited partners 1,~~281~~413,~~564~~464 1,~~216~~281,~~998~~564 General partners 93,799 39,574 ~~6,741~~ ------------ ------------ Total Partners' Equity 1,~~321~~507,~~138~~263 1,~~223~~321,~~739~~138 ------------ ------------ Total Liabilities and Partners' Equity $ 1,~~321~~507,~~138~~263 $ 1,~~223~~321,~~739~~138 ============ ============

The Notes to Financial Statements are an integral part of these statements. F-7 STERLING DRILLING FUND 1983-2 (a New York limited partnership) STATEMENTS OF OPERATIONS FOR THE YEARS ENDED DECEMBER 31, 2001, 2000, 1999

2001 2000 1999 ~~1998~~ -------------------------------- --------------------------------- --------------------------------- Limited General Limited General Limited General Partners Partners Total Partners Partners Total Partners Partners Total --------- --------- --------- --------- --------- --------- --------- --------- --------- ~~Revenues~~Revenue: Operating revenues $ 590,031 $ 181,251 $ 771,282 $ 423,389 $ 130,060 $ 553,449 $ 245,853 $ 75,524 $ 321,377 $Interest ~~278~~7,~~241~~022 $652 857,~~473~~674 ~~$ 363,714 Interest~~ 5,309 493 5,802 2,686 249 2,935 ~~3,787 352 4,139~~ Other revenue (Note 10) 44,420 13,646 58,066 9,482 2,913 12,395 1,854 570 2,424 -- -- -- ---~~------~~ --------- --------- --------- --------- --------- --------- --------- --------- Total ~~Revenues~~Revenue 641,473 195,549 837,022 438,180 133,466 571,646 250,393 76,343 326,736 ~~282,028 85,825 367,853~~ --------- --------- --------- --------- --------- --------- --------- --------- --------- Costs and Expenses: Production expenses 277,710 85,310 363,020 177,377 54,489 231,866 115,074 35,349 150,423 ~~130,738 40,162 170,900~~ Depreciation, depletion and amortization 63,987 5,944 69,931 62,692 5,824 68,516 61,359 5,700 67,059 ~~56,378 5,237 61,615~~ General and administrative expenses (Note 7) 89,391 27,460 116,851 94,302 28,968 123,270 97,042 29,810 126,852 ~~95,176 29,237 124,413~~ --------- --------- --------- --------- --------- --------- --------- --------- --------- Total Expenses 431,088 118,714 549,802 334,371 89,281 423,652 273,475 70,859 344,334 ~~282,292 74,636 356,928~~ --------- --------- --------- --------- --------- --------- --------- --------- --------- Net Income (Loss) $ 210,385 $ 76,835 $ 287,220 $ 103,809 $ 44,185 $ 147,994 $ (23,082) $ 5,484 $ (17,598) ~~$ (264) $ 11,189 $ 10,925~~ ========= ========= ========= ========= ========= ========= ========= ========= ========= Net Income (Loss) Per Equity Unit (Note 2) $ 13.40 $ 6.61 $ (1.47) ~~$ (.02)~~ ========= ========= =========

The Notes to Financial Statements are integral part of these statements. F-8 STERLING DRILLING FUND 1983-2 (a New York limited partnership) STATEMENTS OF CHANGES IN PARTNERS' EQUITY FOR THE YEARS ENDED DECEMBER 31, 2001, 2000, 1999

Limited General Partners Partners Total ------------ ------------ ------------ Balance at December 31, ~~1997~~1998 $ 1,~~318~~279,~~829~~323 $ 12,~~525~~330 $ 1,~~331~~291,~~354~~653 Partners' ~~Contributions~~contributions -- ~~113~~112 ~~113~~112 Distributions to partners (39,~~242~~243) (11,~~497~~185) (50,~~739~~428) Net Income (Loss) (~~264~~23,082) 115,~~189~~484 10(17,~~925~~598) ------------ ------------ ------------ Balance at December 31, ~~1998~~1999 1,~~279~~216,~~323~~998 126,~~330~~741 1,~~291~~223,~~653~~739 Partners' contributions -- ~~112~~113 ~~112~~113 Distributions to partners (39,243) (11,~~185~~465) (50,~~428~~708) Net Income ~~(Loss) (23~~103,~~082)~~809 544,~~484~~185 ~~(17~~147,~~598)~~994 ------------ ------------ ------------ Balance at December 31, ~~1999~~2000 1,~~216~~281,~~998~~564 639,~~741~~574 1,~~223~~321,~~739~~138 Partners' contributions -- ~~113~~225 ~~113~~225 Distributions to partners (3978,~~243~~485) (1122,~~465~~835) (50101,~~708~~320) Net Income ~~103~~210,~~809~~385 4476,~~185~~835 ~~147~~287,~~994~~220 ------------ ------------ ------------ Balance at December 31, ~~2000~~2001 $ 1,~~281~~413,~~564~~464 $ 3993,~~574~~799 $ 1,~~321~~507,~~138~~263 ============ ============ ============

The Notes to Financial Statements are an integral part of these statements. F-9 STERLING DRILLING FUND 1983-2 (A NEW YORK LIMITED PARTNERSHIP) STATEMENTS OF CASH FLOWS FOR THE YEARS ENDED DECEMBER 31, 2001, 2000, 1999

2001 2000 1999 ~~1998~~ ------------ ------------ ------------ Cash Flows From Operating Activities: Net ~~income~~Income (~~loss~~Loss) $ 287,220 $ 147,994 $ (17,598) ~~$ 10,925~~ Adjustments to reconcile net income (loss) to net cash provided by operating activities: Depreciation, depletion and Amortization 69,931 68,516 67,059 ~~61,615~~ Changes in Assets and Liabilities: (Increase) ~~decrease~~ due from affiliates 12,714 557 507 ~~(39,510) Increase in due to affiliates~~ -- -- ~~48,737~~ --------- ------------ ------------ Net Cash Provided by Operating Activities 369,865 217,067 49,968 ~~81,767~~ ------------ ------------ ------------ Cash Flows From Investing Activities: Equipment purchases (37,607) (87,732) (12,334) -- ---------- ------------ ------------ Cash Flows From Financing Activities: Partners' contributions 225 113 112 ~~113~~ Distributions to partners (50101,~~708~~320) (50,~~428~~708) (50,~~739~~428) ------------ ------------ ------------ Net Cash Used in Financing Activities (50101,~~595~~095) (50,~~316~~595) (50,~~626~~316) ------------ ------------ ------------ Net ~~increase~~Increase (decrease) in cash and cash ~~equivalents~~Equivalents 231,163 78,740 (12,682) ~~31,141~~ Cash and cash equivalents, at beginning of ~~year~~Year 154,612 75,872 88,554 ~~57,413~~ ------------ ------------ ------------ Cash and cash equivalents, at end of year $ 385,775 $ 154,612 $ 75,872 ~~$ 88,554~~ ============ ============ ============

The Notes to Financial Statements are an integral part of these statements. F-10 STERLING DRILLING FUND 1983-2, L.P. (a New York limited partnership) NOTES TO FINANCIAL STATEMENTS DECEMBER 31, 2001, 2000 AND 1999 (1) Organization and Capital Contributions: Sterling Drilling Fund 1983-2, L.P., a New York limited partnership (the "Partnership"), was formed on May 26, 1983 for the primary purpose of acquiring, developing and producing oil and gas in the state of West Virginia. The general partners are: PrimeEnergy Management Corporation (PEMC), a wholly owned subsidiary of PrimeEnergy Corporation (PEC), Charles E. Drimal, Jr., Oliver J. Sterling and Samuel R. Campbell. Fifteen thousand six hundred ninety-seven limited partnership units, (15,697), were sold at $1,000 per unit aggregating total limited partner contributions of $15,697,000. The general partners' contributions amounted to $1,284,839. Partnership operations commenced on December 22, 1983. (2) Summary of Significant Accounting Policies: Revenue Recognition: The Partnership recognizes operating revenues, consisting of sales of oil and gas production, in the month of sale. Uncollected revenue is accrued based on known facts and trends of the relevant oil and gas properties on a monthly basis. Basis of Accounting: The accounts of the Partnership are maintained in accordance with accounting practices permitted for federal income tax reporting purposes. Under this method of accounting, (a) substantially all exploration and development costs except leasehold and equipment costs are expensed as paid, (b) costs of abandoned leases and equipment are expensed when abandoned, and (c) depreciation (for equipment placed in service) is provided on an accelerated basis. In order to present the accompanying financial statements in accordance with generally accepted accounting principles, memorandum adjustments have been made to account for oil and gas properties, as discussed below. F-11 STERLING DRILLING FUND 1983-2, L.P. (a New York limited partnership) NOTES TO FINANCIAL STATEMENTS DECEMBER 31, 2001, 2000 AND 1999 (2) Summary of Significant Accounting Policies - (Cont'd): Oil and Gas Producing Activities: The Partnership accounts for its oil and gas operations using the successful efforts method of accounting on a property by property basis. The Partnership only participates in developmental drilling. Accordingly, all costs of drilling and equipping these wells, together with leasehold acquisition costs, are capitalized. These capitalized costs are amortized on a property by property basis by the unit-of-production method based upon the ratio of production to proved oil and gas reserves. Additional depreciation, depletion and amortization may be recorded if net capitalized costs exceed the undiscounted future net cash flows attributable to Partnership properties. (See Note 4) Federal Income Taxes: As federal income taxes are the liability of the individual partners, the accompanying financial statements do not include any provision for federal income taxes. (See Note 8) Limited Partners' Loss Per Equity Unit: The limited partners' income (loss) per equity unit is computed on the 15,697 limited partner equity units. Cash and Cash Equivalents: For purposes of the statements of cash flows the Partnership considers all highly liquid debt instruments with a maturity of three months or less to be cash equivalents. Use of Estimates: 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. F-12 STERLING DRILLING FUND 1983-2, L.P. (a New York limited partnership) NOTES TO FINANCIAL STATEMENTS DECEMBER 31, 2001, 2000 AND 1999 (3) Oil and Gas Properties: The Partnership acquired leases or farmouts from PEMC at its cost. Cost is defined as any amount paid for delay rentals, lease bonuses, if any, surveys and other expenses including such portion of any of the general partners', or their affiliates' reasonable, necessary and actual expenses for geological, geophysical, seismic, land, engineering, drafting, accounting, legal and other services. The Partnership currently pays royalties of approximately 12.50% to 18.75% of the selling price of the oil and gas extracted. The following table sets forth certain revenue and expense data concerning the Partnership's oil and gas activities for the years ended December 31, 2001, 2000 and 1999:

2001 2000 1999 ~~1998~~ ------------ ------------ ------------ Average sales price per MCF of gas $ 35.5720 $ 23.4857 $ 2.9548 Average sales price per BBL of oil and other liquids $ 22.69 $ 26.91 $ 15.63 ~~$ 12.14 and other liquids~~ Production expense per dollar of $operating ~~0.43~~revenue $ 0.47 $ 0.5143 ~~operating~~$ ~~revenue~~0.47

(4) Quantities of Oil and Gas Reserves: The amount of proved reserves (all of which are developed) presented below has been estimated by an independent firm of petroleum engineers as of January 1, 2002. Petroleum engineers on the staff of PEC have also reviewed the data presented below, as of December 31, 2001, for consistency with current year production and operating history. All of the Partnership's oil and gas reserves are located within the United States.

(Unaudited) ------------------------------ GAS (MCF) OIL (BBL) ------------ ------------ Reserves as of December 31, ~~1997~~1998 2,~~384~~165,~~111~~449 2117,~~009~~721 Revisions of previous estimates (~~103~~92,~~995~~642) (15,~~239~~532) Production (~~114~~118,~~667~~204) (21,~~049~~790) ------------ ------------ Reserves as of December 31, ~~1998~~1999 21,~~165~~954,~~449~~603 1721,~~721~~463 Revisions of previous estimates ~~(92~~507,~~642)~~945 ~~5,532~~784 Production (~~118~~141,~~204~~004) (1,~~790~~861) ------------ ------------ Reserves as of December 31, ~~1999~~2000 12,~~954~~321,~~603~~544 2120,~~463~~386 Revisions of previous estimates ~~507~~24,~~945~~288 ~~784~~(2,700) Production (~~141~~140,~~004~~730) (1,~~861~~748) ------------ ------------ Reserves as of December 31, ~~2000~~2001 2,~~321~~205,~~544~~102 2021,~~386~~338 ============ ============

F-13 STERLING DRILLING FUND 1983-2, L.P. (a New York limited partnership) NOTES TO FINANCIAL STATEMENTS DECEMBER 31, 2001, 2000 AND 1999 (4) Quantities of Oil and Gas Reserves - (Cont'd): Should future prices decline, operation of certain wells would become uneconomic, on a pretax basis, as production levels decline with age. In accordance with the rules and regulations of the Securities and Exchange Commission, proved reserves exclude production which would be uneconomic. The partners are entitled to certain tax benefits and credits which, if available in the future, may result in production continuing beyond the level included in the above table. Revisions arise from changes in current prices, as well as engineering and geological data which would alter the useful life and therefore the overall predicted production of each well. Future changes in these estimates are common and would impact the reserve quantities used to calculate depreciation, depletion and amortization. As discussed in Note 2, the Partnership may record additional depreciation, depletion and amortization if net capitalized costs exceed the undiscounted future net cash flows attributable to Partnership properties. Significant price declines affect estimated future net revenues both directly and as a consequence of their impact on estimates of future production. The Partnership has recorded no additional provision for 2001, 2000 and 1999. F-14 STERLING DRILLING FUND 1983-2, L.P. (a New York limited partnership) NOTES TO FINANCIAL STATEMENTS DECEMBER 31, 2001, 2000 AND 1999 (5) Allocation of Partnership Revenues, Costs and Expenses: Under the terms of the Limited Partnership Agreement, all Partnership revenues and expenses, including deductions attributable thereto, are to be allocated as follows:

Limited General Partners Partners --------- -------- Participation in Costs: Sales commissions and dealer manager fees ~~100.0% --%~~ in excess of the $50,000 paid by PEMC 100% 0 % Offering costs other than $75,000 paid by the Partnership and the Sterling Drilling Fund 1983-12, L.P. --0% 100.0% Management fee 100.0% --0% Lease acquisition costs 91.5% 8.5% Drilling and completion costs 91.5% 8.5% General and administrative expenses 76.5% 23.5% Production operator's fee 76.5% 23.5% Operating expenses 76.5% 23.5% All other costs 91.5% 8.5% Participation in Revenues: Sale of production 76.5% 23.5% Sale of properties 91.5% 8.5% Sale of equipment 91.5% 8.5% All other revenues 91.5% 8.5%

(6) Transactions With Affiliates: (a) The receivable from affiliates at December 2001 and 2000 represents general and administrative and certain other expenses incurred on behalf of the Partnership by PEC and its subsidiaries, and amounts due for production operator's fees (Note 6(b)), net of production revenues collected on behalf of the Partnership. (b) As operator of the Partnership's properties, Prime Operating Company (POC), a subsidiary of PEC, receives, as compensation from the Partnership, a monthly production operator's fee of $495 for each producing gas well and $686 for each producing oil or combination gas and oil well, based on the Partnership's F-15 STERLING DRILLING FUND 1983-2, L.P. (a New York limited partnership) NOTES TO FINANCIAL STATEMENTS DECEMBER 31, 2001, 2000 AND 1999 (6) Transactions With Affiliates - (Cont'd): percentage of working interest in the well. Such fee is subject to annual adjustment by the percentage increase in the Cost of Living Index published by the U.S. Department of Labor over the year in which production began. During 2001, 2000 and 1999, $183,130, $132,107, and $84,742, of production operator's fees were incurred, respectively. (c) In accordance with the terms of the Partnership Agreement, the general partners are required to pay 8.5% of drilling and completion costs, lease acquisition costs and certain other costs, of which 1% will be paid for by the general partners out of revenues received by them from the Partnership. At December 31, 2001, $25,927 was due from certain general partners for such costs. (d) Eastern Oil Well Services Company (EOWSC), a subsidiary of PEC, provided field services to the Partnership during the years ending December 31, 2001, 2000, and 1999 for which it was billed $10,904, $15,790, and $18,779, respectively. (7) General and Administrative Expenses: In accordance with the Management Agreement, the general partners will be reimbursed for the portion of their in-house overhead, including salaries and related benefits, attributable to the affairs and operations of the Partnership. This amount, combined with certain direct expenses for geology, engineering, legal, accounting, auditing, insurance and other items shall not exceed an annual amount equal to 5% of limited partner capital contributions. Excess expenses shall be borne by the general partners in their individual capacity. During 2001, 2000 and 1999, the Partnership recognized general and administrative expenses incurred on its behalf by a general partner of $100,800, $100,000 and $100,000,respectively. F-16 STERLING DRILLING FUND 1983-2, L.P. (a New York limited partnership) NOTES TO FINANCIAL STATEMENTS DECEMBER 31, 2001, 2000 AND 1999 (8) Federal Income Taxes: The following is a reconciliation between the net income (loss) as reported on the Partnership's federal income tax return and the net income (loss) reported in the accompanying financial statements:

Year Ended December 31, ------------------------------------------------ 2001 2000 1999 ~~1998~~ ------------ ------------ ------------ Net ~~income~~Income as reported on the Partnership's federal income tax return $ 319,544 $ 125,134 $ 34,690 ~~$ 68,484~~ Recompletion costs reported differently for financial reporting purposes and for income tax reporting purposes 37,607 87,732 12,335 -- Depreciation, depletion and amortization ~~for~~For income tax purposes in excess of (less than) financial reporting ~~amount~~amounts (6469,~~872~~931) (64,~~623~~872) (5764,~~559~~623) ------------ ------------ ------------ Net ~~income~~ Income/(~~loss~~Loss) per accompanying financial statements $ 287,220 $ 147,994 $ (17,598)) ~~$ 10,925~~ ============ ============ ============

The tax returns of the Partnership, the qualifications of the Partnership as such for tax purposes, and the amount of Partnership income or loss are subject to examination by federal and state taxing authorities. If such examinations result in changes with respect to Partnership's qualifications or in changes to its income or loss, the tax liability of the partners would be changed accordingly. F-17 STERLING DRILLING FUND 1983-2, L.P. (a New York limited partnership) NOTES TO FINANCIAL STATEMENTS DECEMBER 31, 2001, 2000 AND 1999 (9) Major Customers: A schedule of the major purchases of the Partnership's production is as follows:

Purchaser 2001 2000 1999 ~~1998~~ ---------- ---------- ---------- ~~Phoenix~~Dominion ~~Diversified~~Field Services $ 637,121 $ 422,078 $ 234,637 Cabot $ ~~294~~86,~~607~~219 ~~Cabot~~ $ 74,873 $ 52,100 $Clearfield ~~51,167~~Appalachian ~~American~~Holdings ~~Refining~~$ ~~Group~~39,656 $ 53,445 $ 27,985 ~~$ 24,627~~

The Partnership renewed its gas purchase contracts in December, 2001 resulting in a gas contract price based upon spot market pricing. (10) Other Revenue: In 2001 the Partnerships other income is a result of a cash bonus paid to the partnership for a two-year farmout agreement. The farmout agreement allows a third party the right to drill a deep well on leasehold acerage owned by the partnership for a period of two years. If the third party exercises their rights with in the two years the Partnership could receive an overriding royalty interest. In 2000 the Partnership was a member of Class of Oil Producers involved in litigation alleging that the principal refiners of Penn Grade crude engaged in a conspiracy to fix, lower, maintain and stabilize the purchase prices of crude purchased by the refiners from the oil producers. The Partnership received this amount pursuant to the Settlement Agreement of this litigation. In 1999 other revenue represents settled claims against Columbia Gas Transmission Corp. (Columbia) arising from amounts due from Columbia when they declared bankruptcy. No significant additional claims are expected concerning this matter. F-18 SCHEDULE V STERLING DRILLING FUND 1983-2, L.P. (a New York limited partnership) PROPERTY AND EQUIPMENT - OIL AND GAS PROPERTIES FOR THE YEARS ENDED DECEMBER 31, 2001, 2000 AND 1998

Balance at Balance Beginning Additions Other at End of Year at Cost Retirements Changes of Year ------------ ------------ ------------ ------------ ------------ Year Ended December 31, ~~2000~~2001: Leasehold costs $ 497,639 $ -- $ -- $ -- $ 497,639 Wells and related facilities 1213,~~946~~034,~~528~~260 8737,~~732~~607 -- -- 13,~~034~~071,~~260~~867 ------------ ------------ ------------ ------------ ------------ $ 13,~~444~~531,~~167~~899 $ 8737,~~732~~607 $ -- $ -- $ 13,~~531~~569,~~899~~506 ============ ============ ============ ============ ============ Year Ended December 31, ~~1999~~2000: Leasehold costs $ 497,639 $ -- $ -- $ -- $ 497,639 Wells and related facilities 12,~~934~~946,~~194~~528 1287,~~334~~732 -- -- 1213,~~946~~034,~~528~~260 ------------ ------------ ------------ ------------ ------------ $ 13,~~431~~444,~~833~~167 $ 1287,~~334~~732 $ -- $ -- $ 13,~~444~~531,~~167~~899 ============ ============ ============ ============ ============ Year ~~ended~~Ended December 31, ~~1998~~1999: ------------ Leasehold costs $ 497,639 $ -- $ -- $ -- $ 497,639 Wells and related facilities 12,934,194 --12,334 -- -- 12,~~934~~946,~~194~~528 ------------ ------------ ------------ ------------ ------------ $ 13,431,833 $ --12,334 $ -- $ -- $ 13,~~431~~444,~~833~~167 ============ ============ ============ ============ ============

F-19 SCHEDULE VI STERLING DRILLING FUND 1983-2, L.P. (a New York limited partnership) ACCUMULATED DEPRECIATION, DEPLETION AND AMORTIZATION - OIL AND GAS PROPERTIES FOR THE YEARS ENDED DECEMBER 31, 2001, 2000 AND 1998

Balance at Charges to Balance Beginning Costs and Other at End of Year Expenses Retirements Changes of Year ------------ ------------ ------------ ------------ ------------ Year Ended December 31, ~~2000~~2001: Wells and related facilities $ 11,~~845~~913,~~905~~949 $ 6869,~~044~~465 $ -- $ -- $ 11,~~913~~983,~~949~~414 Leasehold costs 489,~~398~~870 ~~472~~466 -- -- ~~489~~490,~~870~~336 ------------ ------------ ------------ ------------ ------------ $ 12,~~335~~403,~~303~~819 $ 6869,~~516~~931 $ -- $ -- $ 12,~~403~~473,~~819~~750 ============ ============ ============ ============ ============ Year Ended December 31, ~~1999~~2000: Wells and related facilities $ 11,~~779~~845,~~344~~905 $ 6668,~~561~~044 $ -- $ -- $ 11,~~845~~913,~~905~~949 Leasehold costs ~~488~~489,~~900~~398 ~~498~~472 -- -- 489,~~398~~870 ------------ ------------ ------------ ------------ ------------ $ 12,~~268~~335,~~244~~303 $ 6768,~~059~~516 $ -- $ -- $ 12,~~335~~403,~~303~~819 ============ ============ ============ ============ ============ Year ~~ended~~Ended December 31, ~~1998~~1999: ------------ Wells and related facilities $ 11,~~718~~779,~~191~~344 $ 6166,~~153~~561 $ -- $ -- $ 11,~~779~~845,~~344~~905 Leasehold costs 488,~~438~~900 ~~462~~498 -- -- ~~488~~489,~~900~~398 ------------ ------------ ------------ ------------ ------------ $ 12,~~206~~268,~~629~~244 $ 6167,~~615~~059 $ -- $ -- $ 12,~~268~~335,~~244~~303 ============ ============ ============ ============ ============

F-20 INDEX TO EXHIBITS

EXHIBIT NUMBER DESCRIPTION ------- ------------ (3) Form Agreement of Limited Partnership of Sterling-Fuel Resources Drilling Fund 1983-1 (now Sterling Drilling Fund 1983-2, L.P.) (incorporated by reference to Exhibit (3) of Sterling Gas Drilling Fund 1983-2, L.P., Form 10-K for the year ended December 31, 1994) (23) Consent of Ryder Scott Company , L.P. (filed herewith)

Filing Compare · STERLING DRILLING FUND 1983-2