See accompanying notes to the consolidated financial statements.

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June 30, 2003

Nature of Operations-

PrimeEnergy Corporation ("PEC"), a Delaware corporation, was organized in June 1973. PrimeEnergy Management Corporation ("PEMC"), a wholly-owned subsidiary, acts as the managing general partner, providing administration, accounting and tax preparation services for 39 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, North Dakota, Oklahoma, Texas, Utah, West Virginia and Wyoming. The Company operates approximately 1,550 wells and owns non-operating interests in over 800 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.

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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 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 th e property, appropriate allocations 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

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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-

The Company periodically enters into oil and gas financial instruments to manage its exposure to oil and gas price volatility. The oil and gas reference prices upon which the price hedging instruments are based reflect various market indices that have a high degree of historical correlation with actual prices received by the Company.

The financial instruments are accounted for in accordance with Financial Accounting Standards ("SFAS") No. 133, "Accounting for Derivative Instruments and Hedging Activities", which established new accounting and reporting requirements for derivative instruments and hedging activities. SFAS No. 133, as amended by SFAS No. 138, requires that all derivative instruments subject to the requirements of the statement be

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measured at fair market value and recognized as assets or liabilities in the balance sheet. The accounting for changes in the fair value of a derivative depends on the intended use of the derivative and the resulting designation is generally established at the inception of a derivative. For derivatives designated as cash flow hedges and meeting the effectiveness guidelines of SFAS No. 133, changes in fair value, to the extent effective, are recognized in other comprehensive income until the hedged item is recognized in earnings. Hedge effectiveness is measured at least quarterly based on the relative changes in fair value between the derivative contract and the hedged item over time. Any change in fair value of a derivative resulting from ineffectiveness or an excluded component of the gain/loss is recognized immediately in the statement of operations.

Recently Issued Accounting Standards-

 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. This statement was adopted by the Company for the first quarter of 2003, and had no material impact on the Company's financial statements

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 for the first quarter of the fiscal year ending December 31, 2002, and did not have a material impact on the Company's financial statements.

In June 2002, the FASB issued SFAS No. 146, "Accounting for Costs Associated with Exit or Disposal Activities." SFAS No. 146 requires that a liability for a cost associated with an exit or disposal activity be recognized and measured initially at fair value only when the liability is incurred. SFAS No. 146 is effective for exit or disposal activities that are initiated after December 31, 2002. The adoption of SFAS No. 146 in 2003 is not expected to have an effect on the Company's financial position or results of operations.

In November 2002, the FASB issued Financial Interpretation No. 45, "Guarantor's Accounting and Disclosure Requirements for Guarantees, including Indirect Guarantee of Indebtedness of Others" (FIN 45). FIN 45 requires that upon issuance of a guarantee, the guarantor must recognize a liability for the fair value of the obligation it assumes under that guarantee. FIN 45's provisions for initial recognition and measurement should be applied on a prospective basis to guarantees issued or modified after December 31, 2002.

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The guarantor's previous accounting for guarantees that were issued before the date of FIN 45's initial application may not be revised or restated to reflect the effect of the recognition and measurement provisions of the Interpretation. The disclosure requirements are effective for financial statements of both interim and annual periods that end after December 15, 2002. The adoption of FIN 45 did not have an impact on the Company's consolidated financial statements.

In December 2002, the FASB issued SFAS 148, "Accounting for Stock-Based Compensation Transition and Disclosure." SFAS No. 148 amends FASB Statement No. 123, "Accounting for Stock-Based Compensation" to provide alternative methods of transition for a voluntary change to the fair value based method of accounting for stock-based employee compensation. In addition, this Statement amends the disclosure for stock-based employee compensation and the effect of the method used on the reported results. The provisions of SFAS 148 are effective for financial statements with fiscal years ending after December 15, 2002. The adoption of this statement will not impact the Company's financial position or results of operations.

In January 2003, the FASB issued Financial Interpretation No. 46, "Consolidation of Variable Interest Entities an interpretation of ARB No. 51" (FIN 46). FIN 46 is an interpretation of Accounting Research Bulletin 51, "Consolidated Financial Statements", and addresses consolidation by business enterprises of variable interest entities (VIE's). The primary objective of FIN 46 is to provide guidance on the identification of, and financial reporting for, entities over which control is achieved through means other than voting rights; such entities are known as VIE's. FIN 46 requires an enterprise to consolidate a variable interest entity if that enterprise has a variable interest that will absorb a majority of the entity's expected losses if they occur, receive a majority of the entity's expected residual return if they occur, or both. An enterprise shall consider the rights and obligations conveyed by its variable interests in making this determination. This guidance applies immedia tely to variable interest entities created after January 31, 2003, and to variable interest entities in which an enterprise obtains an interest after that date. It applies in the first fiscal year or interim period beginning after June 15, 2003, to variable interest entities in which an enterprise holds a variable interest that it acquired before February 1, 2003. The adoption of this interpretation is not expected to have an effect on the Company's financial position or results of operations.

Restricted cash and cash equivalents include $1,546,900 and $750,000 at June 30, 2003 and December 31, 2002, respectively, of cash primarily pertaining to undistributed royalty payments. There were corresponding accounts payable recorded at June 30, 2003 and December 31, 2002 for these liabilities.

Certain balance sheet amounts are comprised of the following:

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Property and equipment at June 30, 2003 and December 31, 2002 consisted of the following:

As of December 2002 the Company entered in to a credit agreement with a new primary lender. The Company and the lender agreed to amend and restate in its entirety the credit agreement dated April 26, 1995 between the Company and its predecessor lender. This agreement will continue to provide 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. The combined current borrowing base is $25,533,000 which includes a Reducing Revolver Loan of $3,533,000. The Reducing Revolver Loan reduces the first of the month by $66,667. The reducing revolver is in effect until December 31 2004 and the next overall borrowing base review date is on or around December 1, 2003. The credit agreement provides for interest on outstanding borrowings at the bank's base rate, as defined, payable monthly, or at rates 2% over the London Inter-Bank Off ered Rate (LIBO rate) payable at the end of the applicable interest period

The Company had been party to a series of credit agreements with its former lender or its predecessors since 1983. The agreement, entered into in April 1995, provided for borrowings under a Master Note. Advances under the agreement, as amended, were limited to the borrowing base as defined in the agreement and re-determined by the lender on a semi-annual basis. Since the beginning of 2000, the borrowing base ranged from $20 million to $23.7 million. The credit agreement provided for interest on outstanding borrowings at the bank's base rate, as defined, payable monthly, or at rates ranging from 1 1/2% 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. This credit agreement was assigned to the Company's primary lender effective December 2002.

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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 4.38% during the first six months of 2003 as compared to 3.91% during the same period of 2002. As of June 30, 2003 and December 31, 2002, the total outstanding borrowings were $22.82 million and $24.5 million, respectively, with an additional $1,779,000 and $500,000 available. As of June 30, 2003, $16 million of the amounts outstanding accrued 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.

The Company has several noncancelable operating leases, primarily for rental of office space, that have a term of more than one year.

Capital Leases:

The Company has two capital leases for office equipment. Future minimum lease payments as of June 30, 2003 under operating and capital leases are as follows:

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 $350,000.

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.

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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, 2003 and 2002, 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 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 expired, the former Chairman was still entitled to receive certain payments relating to partnerships formed during the time the agreement was in effect. In October 2002, the President and the former Chairman sold and assigned all rights, title and interest related to certain Partnerships formed under these marketing agreements to the Company. The President is still entitled to a percentage of the Company's carried interest depending on total capital raised and annual performance of other 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, 2003 and December 31, 2002 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 2003 totaled $323,700 which included, a total of approximately 22,350 shares purchased from related parties for a total consideration of $182,838.

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:

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 20, 2003. The only matter submitted to the stockholders was the election of thirteen 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 3,681,212. 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.

No reports on form 8K were filed by the Company during the three months ended June 30, 2003.