See accompanying notes to the consolidated financial statements.

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June 30, 2002

General-

The accompanying unaudited consolidated financial statements included herein, have been prepared by PrimeEnergy Corporation in accordance with accounting principles generally accepted in the United States of America for interim financial information and with instructions to Form 10-Q and Article 10 of Regulation S-X. Accordingly, they do not include all of the information and footnotes required by generally accepted accounting principles for complete financial statements. In the opinion of management, all adjustments (consisting of normal recurring accruals) considered necessary for fair presentation have been included. These financial statements should be read in conjunction with the financial statements and notes thereto which are in the Company's Annual Report on Form 10-K for the fiscal year ended December 31, 2001.

The balance sheet at December 31, 2001 presented in this report, has been derived from the audited financial statements at that date but does not include all of the information and footnotes included in the Company's annual report on Form 10-K for the year ended December 31, 2001.

The results of the operations for the interim periods may not necessarily be indicative of the results to be expected for the full year.

Nature of Operations-

PrimeEnergy Corporation ("PEC"), a Delaware corporation, was organized in March 1973. PrimeEnergy Management Corporation ("PEMC"), a wholly-owned subsidiary, acts as the managing general partner, providing administration, accounting and tax preparation services for 45 private and publicly-held limited partnerships and 2 trusts (collectively, the "Partnerships"). PEC owns Eastern Oil Well Service Company, EOWS Midland Company, and Southwest Oilfield Construction Company, all of which perform oil and gas field services. PEC also owns Prime Operating Company, which serves as operator for most of the producing oil and gas properties owned by the Company and affiliated entities. Field service revenues and the administrative overhead fees earned as operator are reported as 'District operating income' on the consolidated statement of operations. PrimeEnergy Corporation and its wholly-owned subsidiaries are herein referred to as the "Company".

The Company is engaged in the development, acquisition and production of oil and natural gas properties. The Company owns leasehold, mineral and royalty interests in producing and non-producing oil and gas properties across the continental United States, including Colorado, Kansas, Louisiana, Mississippi, Montana, Nebraska, New Mexico,

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North Dakota, Oklahoma, Texas, Utah, West Virginia and Wyoming. The Company operates approximately 1,550 wells and owns non-operating interests in over 450 additional wells. Additionally, the Company provides well-servicing support operations, site-preparation and construction services for oil and gas drilling and re-working operations, both in connection with the Company's activities and providing contract services for third parties. The Company is publicly traded on the NASDAQ under the symbol "PNRG."

The markets for the Company's products and services are highly competitive, as oil and gas are commodity products and prices depend upon numerous factors beyond the control of the Company, such as economic, political and regulatory developments and competition from alternative energy sources.

Principles of Consolidation-

The consolidated financial statements include the accounts of PrimeEnergy Corporation and its wholly-owned subsidiaries. All material inter-company accounts and transactions between these entities have been eliminated. Oil and gas properties include ownership interests in the Partnerships. The statement of operations includes the Company's proportionate share of revenue and expenses related to oil and gas interests owned by the Partnerships.

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.

Estimates of oil and gas reserves, as determined by independent petroleum engineers, are continually subject to revision based on price, production history and other factors. Depletion expense, which is computed based on the units of production method, could be significantly impacted by changes in such estimates. Additionally, SFAS No. 144 requires that, if the expected future cash flow from an asset is less than its carrying cost, that asset must be written down to its fair market value. As the fair market value of a property is generally substantially less than the total future cash flow expected from the asset, small changes in the estimated future net revenue from an asset could lead to the necessity of recording a significant impairment of that asset.

Property and Equipment-

The Company follows the "successful efforts" method of accounting for its oil and gas properties. Under the successful efforts method, costs of acquiring undeveloped oil and gas leasehold acreage, including lease bonuses, brokers' fees and other related costs are capitalized. Provisions for impairment of undeveloped oil and gas leases are based on periodic evaluations. Annual lease rentals and exploration expenses, including geological and geophysical expenses and exploratory dry hole costs, are charged against income as

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incurred. Costs of drilling and equipping productive wells, including development dry holes and related production facilities, are capitalized. Costs incurred by the Company related to the exploration, development and acquisition of oil and gas properties on behalf of the Partnerships or joint ventures are deferred and charged to the related entity upon the completion of the acquisition. To the extent that the Company acquires an interest in the property, an appropriate allocation of internal costs are capitalized as part of the depletable base of the property.

All other property and equipment are carried at cost. Depreciation and depletion of oil and gas production equipment and properties are determined under the unit-of-production method based on estimated proved recoverable oil and gas reserves. Depreciation of all other equipment is determined under the straight-line method using various rates based on useful lives. The cost of assets and related accumulated depreciation is removed from the accounts when such assets are disposed of, and any related gains or losses are reflected in current earnings.

Income Taxes-

The Company records income taxes in accordance with Statement of Financial Accounting Standards ("SFAS") No. 109, "Accounting for Income Taxes". SFAS No. 109 is an asset and liability approach to accounting for income taxes, which requires the recognition of deferred tax assets and liabilities for the expected future consequences of events that have been recognized in the Company's financial statements or tax returns.

Deferred tax liabilities or assets are established for temporary differences between financial and tax reporting bases and are subsequently adjusted to reflect changes in the rates expected to be in effect when the temporary differences reverse. A valuation allowance is established for any deferred tax asset for which realization is not likely.

General and Administrative Expenses-

General and administrative expenses represent costs and expenses associated with the operation of the Company. Certain of the Partnerships and joint ventures sponsored by the Company reimburse general and administrative expenses incurred on their behalf.

Income per share-

Income per share of common stock has been computed based on the weighted average number of common shares and common stock equivalents outstanding during the respective periods in accordance with SFAS No. 128, "Earnings per Share".

Statements of cash flows-

For purposes of the consolidated statements of cash flows, the Company considers short-term, highly liquid investments with original maturities of less than ninety days to be cash equivalents.

Concentration of Credit Risk-

The Company maintains significant banking relationships with financial institutions in the State of Texas. The Company limits its risk by periodically evaluating the relative credit standing of these financial institutions. The Company's oil and gas production purchasers consist primarily of independent marketers and major gas pipeline companies.

Hedging-

From time to time, the Company may enter into futures contracts in order to reduce its exposure related to changes in oil and gas prices. In accordance with Statement of Financial Accounting Standards No. 133, any gain or loss on such contracts is treated as an adjustment to oil and gas revenue. Cash activity related to hedging transactions is treated as operating activity on the Statements of Cash Flows.

Recently Issued Accounting Standards-

 In July 2001, the Financial Accounting Standards Board ("FASB") issued SFAS No. 141, "Business Combinations." SFAS No. 141 is intended to improve the transparency of the accounting and reporting for business combinations by requiring that all business combinations be accounted for under a single method - the purchase method. SFAS 141 is effective for all transactions completed after June 30, 2001, except transactions using the pooling-of-interests method that were initiated prior to July 1, 2001. The adoption of SFAS 141 has not had an impact on the Company's consolidated financial statements.

 In July 2001, the FASB issued SFAS No. 142, "Goodwill and Other Intangible Assets." This statement applies to intangibles and goodwill acquired after June 30, 2001, as well as goodwill and intangibles previously acquired. Under this statement, goodwill as well as other intangibles determined to have an infinite life will no longer be amortized; however, these assets will be reviewed for impairment on a periodic basis. This statement is effective for the Company for the first quarter in the fiscal year ending December 31, 2002. The adoption of this statement has not had an impact on the Company's consolidated financial statements.

 In August 2001, the FASB issued SFAS No. 143, "Accounting for Asset Retirement Obligations." SFAS No. 143 requires the fair value of a liability for an asset retirement obligation to be recognized in the period in which it is incurred if a reasonable estimate of fair value can be made. The associated asset retirement costs are capitalized as part of the carrying amount of the long-lived asset. SFAS No. 143 is effective for fiscal years beginning after June 15, 2002. Management has not yet determined the impact of the adoption of this statement.

In October 2001, the FASB issued SFAS No. 144, "Accounting for the Impairment or Disposal of Long-Lived Assets." SFAS No. 144 requires that long-lived assets be measured at the lower of carrying amount or fair value less cost to sell, whether reported in continuing operations or in discontinued operations. Therefore, discontinued operations will no longer be measured at net realizable value or include amounts for operating losses that have not yet occurred. This statement was adopted by the Company in the first quarter of the fiscal year ending December 31, 2002, and did not have a material impact on the Company's financial statements.

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In April 2002, the FASB issued SFAS No. 145, "Rescission of FASB Statements No. 4, 44, and 64, Amendment of FASB Statement No. 13, and Technical Corrections". SFAS No. 145 is effective for fiscal years beginning after May 15, 2002. Management has not yet determined the impact of the adoption of this statement on the Company's financial position or results of operations.

In July 2002, the FASB issued SFAS No. 146, "Accounting For Costs Associated with Exit or Disposal Activities". SFAS No. 146 is effective for exit or disposal activities initiated after December 31, 2002. Management has not yet determined the impact of the adoption of SFAS No. 146 on the Company's financial position or results of operations.

Restricted cash and cash equivalents includes $1,269,000 and $1,174,000 at June 30, 2002 and December 31, 2001, respectively, of cash primarily pertaining to undistributed royalty payments. There were corresponding accounts payable recorded at June 30, 2002 and December 31, 2001 for these liabilities.

Accounts receivable at June 30, 2002 and December 31, 2001 consisted of the following:

Other current assets at June 30, 2002 and December 31, 2001 consisted of the following:

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During 2001, the Company estimated that its liability for the 2001 tax year would be approximately $1,000,000, and made estimated tax payments accordingly. Due primarily to a significant investment in tax deductible intangible drilling costs along with a sharp drop in oil and gas prices, the actual tax liability was substantially less. The Company filed for tax refunds during the second quarter of 2002, of which $573,000 has been collected and $135,000 is due the Company as of June 30, 2002.

Property and equipment at June 30, 2002 and December 31, 2001 consisted of the following:

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The Company has been party to a series of credit agreements with its primary lender or its predecessors since 1983. The current agreement, entered into in April 1995, provides for borrowings under a Master Note. Advances under the agreement, as amended, are limited to the borrowing base as defined in the agreement. The borrowing base is re-determined by the lender on a semi-annual basis. Since the beginning of 1999, the borrowing base has ranged from $18.95 million to $23.7 million. The credit agreement provides for interest on outstanding borrowings at the bank's base rate, as defined, payable monthly, or at rates ranging from 1.5% to 2% over the London Inter-Bank Offered Rate (LIBO rate) depending upon the Company's utilization of the available line of credit, payable at the end of the applicable interest period.

The combined average interest rates paid on outstanding borrowings subject to interest at the bank's base rate and on outstanding borrowings bearing interest based upon the LIBO rate were 3.91% during the first six months of 2002 as compared to 7.13% during the same period of 2001. As of June 30, 2002 and December 31, 2001, the total outstanding borrowings were $19.5 million and $16.95 million, respectively, with an additional $3.5 million and $6.05 million available. As of June, 30, 2002, all of the outstanding borrowings were accruing interest at the LIBO rate option. As of December 31, 2001, $14.95 million of the $16.95 million outstanding borrowings were accruing interest at the LIBO rate option.

The Company's oil and gas properties as well as certain receivables and equipment are pledged as security under the loan agreement. The agreement requires the Company to maintain, as defined, a minimum current ratio, tangible net worth, debt coverage ratio and interest coverage ratio, and restrictions are placed on the payment of dividends and the amount of treasury stock the Company may purchase.

Other long-term obligations at June 30, 2002 and December 31, 2001 consisted of the following:

In connection with the purchase of oil and gas properties located in various counties in Oklahoma in November of 1999, the Company is committed to pay contingent

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consideration to the seller based upon the performance of the properties purchased. As of December 31, 2001, the total amount of contingent consideration estimated to be paid under the agreement was $225,000, all of which was included in 'Other long-term obligations' on the Balance Sheet. During the first six months of 2002, $171,000 was paid, leaving a net estimated amount due at June 30, 2002 of $54,000.

PEMC, as managing general partner of the affiliated Partnerships is responsible for all Partnership activities, including the review and analysis of oil and gas properties for acquisition, the drilling of development wells and the production and sale of oil and gas from productive wells. PEMC also provides the administration, accounting and tax preparation work for the Partnerships and is liable for all debts and liabilities of the affiliated Partnerships, to the extent that the assets of a given limited Partnership are not sufficient to satisfy its obligations.

As a general partner, PEMC is committed to offer to purchase the limited partners' interests in certain of its managed Partnerships at various annual intervals. Under the terms of a partnership agreement, PEMC is not obligated to purchase an amount greater than 10% of the total partnership interest outstanding. In addition, PEMC will be obligated to purchase interests tendered by the limited partners only to the extent of one hundred fifty (150) percent of the revenues received by it from such partnership in the previous year. Purchase prices are based upon annual reserve reports of independent petroleum engineering firms discounted by a risk factor. Based upon historical production rates and prices, management estimates that if all such offers were to be accepted, the maximum annual future purchase commitment would be approximately $500,000.

The Company owns approximately a 27% interest in a limited partnership which owns a shopping center in Alabama. The Company is a guarantor on a mortgage secured by the shopping center. The Company believes the cash flow from the center is sufficient to service the mortgage. The market value of the center is currently substantially higher than the balance owed on the mortgage. If the partnership were unable to pay its obligations under the mortgage agreement, the maximum amount the Company is committed to pay is $400,000.

The Company is subject to environmental laws and regulations. Management believes that future expenses, before recoveries from third parties, if any, will not have a material effect on the Company's financial condition. This opinion is based on expenses incurred to date for remediation and compliance with laws and regulations which have not been material to the Company's results of operations.

In May 1989, non-statutory stock options were granted by the Company to four key executive officers for the purchase of shares of common stock. At June 30, 2002 and 2001, options on 767,500 were outstanding and exercisable at prices ranging from $1.00 to $1.25.

PEMC has a marketing agreement with its current President to provide assistance and

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advice to PEMC in connection with the organization and marketing of oil and gas partnerships and joint ventures and other investment vehicles of which PEMC is to serve as general or managing partner. The Company had a similar agreement with its former Chairman. Although that agreement has expired, the former Chairman is still entitled to receive certain payments relating to partnerships formed during the time the agreement was in effect. The President is entitled to a percentage of the Company's carried interest depending on total capital raised and annual performance of the Partnerships and joint ventures.

PEMC is a general partner in several oil and gas Partnerships in which certain directors have limited and general partnership interests. As the managing general partner in each of the Partnerships, PEMC receives approximately 5% to 15% of the net revenues of each Partnership as a carried interest in the Partnerships' properties.

The Partnership agreements allow PEMC to receive management fees for various services provided to the Partnerships as well as reimbursement for certain costs incurred on behalf of the Partnerships, including property acquisition and development costs. Reimbursement of general and administrative overhead is reported in the statements of operations as administrative revenue.

Due to related parties at June 30, 2002 and December 31, 2001 primarily represent receipts collected by the Company, as agent, from oil and gas sales net of expenses. Receivables from affiliates consist of reimbursable general and administrative costs, lease operating expenses and reimbursements for property acquisitions, development and related costs.

Treasury stock purchases in the first six months of 2002 and 2001 included shares acquired from related parties. Purchases in the first six months of 2002 and 2001 include approximately 17,000 shares purchased for a total consideration of $138,000 in 2002, and 164,000 shares purchased for a total consideration of $1,151,000 in 2001.

Included in 'Interest and other income' for the period ending June 30, 2002 are proceeds of $350,000 received in February, 2002 in settlement of a claim for additional drilling costs incurred by the Company in prior years as a result of a third party's negligence.

Basic earnings per share are computed by dividing earnings available to common stockholders by the weighted average number of common shares outstanding during the period. Diluted earnings per share reflect per share amounts that would have resulted if dilutive potential common stock had been converted to common stock. The following reconciles amounts reported in the financial statements:

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From time to time, the Company is party to certain legal actions and claims arising in the ordinary course of business. While the outcome of these events cannot be predicted with certainty, management does not expect these matters to have a materially adverse effect on the financial position or results of operations of the Company.

The Annual Meeting of Stockholders of the company was held on June 13, 2002. One matter submitted to the stockholders was the election of fourteen Directors (named below), nominated by management, all of whom were currently serving as Directors. Proxies were solicited pursuant to Regulation 14A under the Securities Act of 1934, definitive copies of which were filed with the Commission. There was no solicitation in opposition to management's nominees, and all of the Directors nominated for the re-election were elected. The number of shares of the Company's common stock outstanding and entitled to vote at the Annual Meeting was 3,763,356. Those persons nominated and elected as Directors, and the number of shares voting for or withheld for each, is shown below. There were no abstentions or broker non-votes.

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