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1993 ANNUAL REPORT |
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Notes to Consolidated Financial Statements
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1993 ANNUAL REPORT |
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Notes to Consolidated Financial Statements
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1. Summary of Significant Accounting Policies
Principles of Consolidation. The accompanying consolidated financial statements include the accounts of Swift Energy Company (Swift) and its wholly owned subsidiaries (collectively referred to as the "Company"). The Company’s investments in associated oil and gas partnerships and its joint ventures are accounted for using the proportionate consolidation method, whereby the Company’s proportionate share of each entity’s assets, liabilities, revenues, and expenses is included in the appropriate classifications in the consolidated financial statements. The Company’s investment in Pet-Tech Tools, Inc. was accounted for using the equity method. Intercompany balances and transactions have been eliminated in preparing the consolidated statements. Certain reclassifications have been made to prior year amounts to conform to the current year presentation.
Property and Equipment. For financial reporting purposes, the Company follows the "full-cost" method of accounting for oil and gas property and equipment costs. Under this method of accounting, all productive and nonproductive costs incurred in the acquisition, exploration, and development of oil and gas reserves are capitalized, including interests earned in limited partnerships and joint ventures formed for the purpose of acquiring interests in producing oil and gas properties. No gains or losses are recognized upon the sale or disposition of oil and gas properties, except in extraordinary transactions. Instead, the proceeds from the sale of oil and gas properties are treated as a reduction of oil and gas property costs. Management fees from associated oil and gas exploration and development limited partnerships are credited to oil and gas property costs to the extent they do not represent reimbursement of general and administrative expenses currently charged to expense.
The Company computes the provision for depreciation, depletion, and amortization of oil and gas properties on the unit-of-production method. Under this method, the Company computes the provision by multiplying the total unamortized costs of oil and gas properties, excluding costs of unproved properties, by an overall rate determined by dividing the physical units of oil and gas produced during the period by the total estimated units of proved oil and gas reserves. The cost of unproved properties not being amortized is assessed quarterly to determine whether the value has been impaired below the capitalized cost. Any impairment assessed is added to the cost of proved properties being amortized.
The unamortized cost of oil and gas properties, net of related deferred income taxes, is limited to the sum, calculated on a quarterly basis, of the estimated future net revenues from proved properties using current prices, discounted at 10%, and the lower of cost or fair value of unproved properties, adjusted for related income tax effects.
All other equipment is depreciated by the straight-line method at rates based on the estimated useful lives of the property. Repairs and maintenance are charged to expense as incurred. Renewals and betterments are capitalized.
Deferred Charges. Legal and accounting fees, underwriting fees, printing costs, and other direct expenses associated with the issuance of the Company’s Convertible Subordinated Debentures in June 1993 have been capitalized and are being amortized over the life of the Debentures, which mature on June 30, 2003. The balance at December 31, 1993, is net of accumulated amortization of $49,865.
Limited Partnerships and Joint Ventures. The Company forms limited partnerships and joint ventures for the purpose of acquiring interests in producing oil and gas properties. The Company serves as managing general partner or manager of these entities. Under the Swift Depositary Interests limited partnership offering ("SDI Offering") which commenced in March 1991, the Company receives a reimbursement of certain costs and a fee, both payable out of revenues. The Company bears all front-end costs of the offering and partnership formations for which it receives an interest in the partnerships. In addition, the Company also receives a fee ("earned interest") in the form of additional interests (which vary based on the expected levels of cash distributions to the limited partners/joint venturers) in the net revenues of the producing oil and gas properties acquired by these entities. The amount of earned interest is calculated by multiplying the estimated additional interest in the entity’s net revenues by the purchase price of the property and is recognized as revenue upon acquisition of the producing properties by the entities.
The Company acquires and transfers producing oil and gas properties to the entities at cost including interest, other carrying costs, closing costs, and screening and evaluation costs of properties not acquired, or in certain instances at fair market value based upon the opinion of an independent expert. These costs are reduced by net operating revenues from the effective date of the acquisition to the date of transfer to the entities. Such net operating revenue amounts totaled approximately $3,200,000, $2,600,000, and $1,900,000 in 1993, 1992, and 1991, respectively.
Costs of syndication, registration, and qualification of the SDI limited partnerships incurred by the Company have been deferred. Under the current SDI limited partnership offering, selling and formation costs borne by the Company serve as the Company’s general partner contribution to such partnerships.
Commencing September 15, 1993, the Company began offering on a private placement basis general and limited partnership interests in Swift Energy Drilling Ventures ("SEDV Offering"), a series of limited partnerships to be formed. As managing general partner, the Company will pay for all front-end costs incurred in connection with this offering, for which the Company will receive an interest in the partnerships. The offering is for a maximum of $12,000,000 with each partnership having a $1,000,000 minimum. The proceeds will be invested in development drilling (approximately 50%) and exploratory drilling (approximately 25%), with the remaining 25% dependent upon the results of the initial drilling activities. The first partnership closed December 8, 1993. The Company anticipates it will form two additional partnerships in 1994.
Income Per Share. Primary income per share has been computed using the weighted average number of common shares outstanding during the respective periods. Stock options and warrants outstanding do not have an effect on primary income per share. The Company’s Convertible Subordinated Debentures are not common stock equivalents for the purpose of computing primary income per share.
The calculation of fully diluted income per share assumes conversion of the Company’s Convertible Subordinated Debentures at the date of issuance and the elimination of the related after-tax interest expense and assumes, as of the beginning of the period, exercise (using the treasury stock method) of stock options and warrants. The weighted average number of shares used in the computation of fully diluted per share amounts were 7,088,782, 5,577,313, and 4,875,726 for the respective years ended December 31, 1993, 1992, and 1991.
Income Taxes. Effective January 1, 1992, the Company adopted Statement of Financial Accounting Standards (SFAS) No. 109, "Accounting for Income Taxes." SFAS No. 109 utilizes the liability method and deferred taxes are determined based on the estimated future tax effects of differences between the financial statement and tax bases of assets and liabilities given the provisions of the enacted tax laws. Prior to the adoption of SFAS No. 109, the Company accounted for income taxes using Accounting Principles Board Opinion No. 11.
Deferred Revenues. In May 1992, as discussed in Note 9 "Oil and Gas Producing Activities," the Company purchased additional interests in certain wells in which the Company has previously owned interests. The funds for this purchase were provided by the Company’s sale of a volumetric production payment in these properties. Under the terms of the production payment agreement, the Company continues to own the properties purchased but is required to deliver a minimum quantity of hydrocarbons produced from the properties (meeting certain quality and heating equivalent requirements) over a specified period. Since entering into this agreement, the Company has met all scheduled deliveries. Net proceeds from the sale of the production payment were recorded as deferred revenues. Deliveries under the production payment agreement are recorded as oil and gas sales revenues and a corresponding reduction of deferred revenues.
Cash and Cash Equivalents. The Company considers all highly liquid debt instruments with an initial maturity of three months or less to be cash equivalents. Noncash investing activities for the year ended December 31, 1993, included approximately $27,100,000 associated with producing oil and gas acquisitions that were paid for in early 1994. Of this amount, approximately $5,100,000 related to property acquisitions made for the Company’s own account. See Note 9 "Oil and Gas Producing Activities" for further discussion.
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