Form 10-Q, 03/31/04

 

UNITED STATES
SECURITIES AND EXCHANGE COMMISSION

WASHINGTON, D.C. 20549

FORM 10-Q

(Mark One)

X

QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d)
OF THE SECURITIES EXCHANGE ACT OF 1934
For the quarterly period ended March 31, 2004

OR

TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d)

OF THE SECURITIES EXCHANGE ACT OF 1934

Commission file number 0-610

 

EQUITY OIL COMPANY

(Exact name of registrant as specified in its charter)

Colorado

87-0129795

(State or other jurisdiction of incorporation or organization)

(I.R.S. Employer
Identification Number)

10 West 300 South, Suite 806

84101

Salt Lake City, Utah

(Zip Code)

(Address of principal executive offices)

Registrant’s telephone number, including area code: (801) 521-3515

Securities registered pursuant to Section 12 (b) of the Act:

Title of each class

Name of each exchange on which registered

None None

Securities registered pursuant to Section 12(g) of the Act:

Common Stock (par value, $1 per share)
(Title of class)

 

Indicate by check mark whether the registrant (1) has filed all reports required to be filed by Section 13 or 15(d) of the Securities Exchange Act of 1934 during the preceding 12 months (or for such shorter period that the registrant was required to file such reports), and (2) has been subject to such filing requirements for the past 90 days. Yes [X ] No [    ]

Indicate by check mark whether the registrant is an accelerated filer (as defined in Rule 12b-2 of the Act) Yes [    ] No [X ]

Indicate the number of shares outstanding of each of the issuer’s classes of common stock, as of the latest practicable date (May 11, 2004): 12,083,161


PART I. FINANCIAL INFORMATION

EQUITY OIL COMPANY

STATEMENTS OF OPERATIONS

for the three months ended March 31, 2004 and 2003

(Unaudited)

REVENUES and other income

2004

2003



Oil and gas sales $ 6,415,600 $ 6,728,397
Other income 489 118,577


6,416,089 6,846,974


EXPENSES
Leasehold operating costs 2,162,018 2,003,716
Depreciation, depletion and amortization 1,800,000 1,925,000
3-D seismic - 9,917
Exploration 21,585 43,393
General and administrative 631,570 795,210
Merger related costs 594,990 -
Production and exploration overhead 313,088 433,997
Accretion expense 58,500 68,000
Interest 248,962 310,589


5,830,713 5,589,822


Income from continuing operations before income taxes 585,376 1,257,152
Provision for income taxes 215,800 464,769


Income from continuing operations 369,576 792,383
Discontinued operations (Note 6):
Income from operations of properties sold, net of provision for income taxes of $52,812 - 90,041
Gain on sale of properties, net of provision for income taxes of $453,940 - 655,168


Income before cumulative effect of accounting change 369,576 1,537,592
Cumulative effect of change in accounting, net of benefit from income taxes of $622,832 - (1,061,865)


NET INCOME $ 369,576 $ 475,727


 

The accompanying notes are an integral part of the financial statements.


EQUITY OIL COMPANY

STATEMENTS OF OPERATIONS

for the three months ended March 31, 2004 and 2003

Continued

(Unaudited)

Basic income per common share:

2004

2003



Income from continuing operations

$.03

$.07

Income from discontinued operations

-

.06



Income before cumulative effect of accounting change

.03

.13

Cumulative effect of change in accounting

-

(.09)



NET INCOME

$.03

$.04



Diluted income per common share:

Income from continuing operations

$.03

$.07

Income from discontinued operations

-

.06



Income before cumulative effect of accounting change

.03

.13

Cumulative effect of change in accounting

-

(.09)



NET INCOME

$.03

$.04



Weighted average shares outstanding

Basic

12,030,551

12,008,661

Diluted

12,688,045

12,231,505

 

 

The accompanying notes are an integral part of the financial statements.


EQUITY OIL COMPANY

STATEMENTS OF COMPREHENSIVE INCOME

for the three months ended March 31, 2004 and 2003

(Unaudited)

2004

2003



Net income $ 369,576 $ 475,727
Other comprehensive income:

Unrealized gains (losses) on financial instruments, net of provision for income taxes of $87,037 in 2004 and benefit from income taxes of $125,733 in 2003

148,388 (214,363)

Reclassification adjustment for losses included in net income, net of benefit from income taxes of $217,698.

371,152 -


Comprehensive income $ 889,116 $ 261,364


 


EQUITY OIL COMPANY

BALANCE SHEETS

As of March 31, 2004 and December 31, 2003

Unaudited

ASSETS

March 31, 2004

December 31, 2003



Currents assets:

Cash and cash equivalents

$ 6,297,068 $ 5,032,922

Accounts receivable

3,971,147 3,945,189

Operator advances

508,781 494,293

Federal, state and foreign income taxes receivable

299,955 412,193

Deferred income taxes

59,300 59,300

Other current assets

139,342 117,707


Total current assets

11,275,593 10,061,604


Property and equipment, at cost (successful efforts method):

Unproved oil and gas properties

4,910,467 4,893,684

Proved oil and gas properties:

Developed leaseholds

35,315,817 35,280,714

Intangible drilling costs

72,470,638 72,033,090

Equipment

32,989,204 32,812,826

Other property and equipment

1,396,142 1,396,142


147,082,268 146,416,456

Less accumulated depreciation, depletion and amortization


(82,070,860)

 (80,270,860)


65,011,408  66,145,596


Other assets 440,085 499,335


Total assets

$ 76,727,086 $ 76,706,535


LIABILITIES AND STOCKHOLDERS’ EQUITY

Current liabilities:

Accounts payable

$ 1,013,708 $ 1,408,238

Accrued liabilities

206,648 319,821

Federal, state and foreign income taxes payable

86,399 105,393

Fair value of derivative financial instruments

144,750 969,025


Total current liabilities

1,451,505 2,802,477
Asset retirement obligation 3,300,883 3,242,383
Revolving credit facility 29,000,000 29,000,000
Deferred income taxes 6,061,903 5,657,168


Total liabilities

 39,814,291  40,702,028


Commitments (Note 6)
Stockholders’ equity:

Common stock

12,885,936 12,877,936

Paid in capital

3,769,734 3,758,562

Retained earnings

22,339,805 21,970,229

Accumulated other comprehensive loss

(91,236) (610,776)


38,904,239 37,995,951

Less treasury stock, 848,000 shares, at cost

(1,991,444)   (1,991,444)


 36,912,795 36,004,507


Total liabilities and stockholders’ equity $ 76,727,086 $ 76,706,535


 

 

The accompanying notes are an integral part of the financial statements.


 

EQUITY OIL COMPANY

STATEMENTS OF CASH FLOWS

for the three months ended March 31, 2004 and 2003

Unaudited

2004

2003



Cash flows from operating activities:
Net income $ 369,576 $ 475,727
Adjustments to reconcile net income to net cash provided by operating activities:

Depreciation, depletion and amortization

1,800,000 1,925,000

Accretion expense

58,500 68,000

Gain on sale of oil and gas properties

- (1,278,426)

Cumulative effect of change in accounting

- 1,061,865

Change in other assets

59,250 59,249

Deferred income tax expense

100,000 651,800
Increase (decrease) from changes in:

Accounts receivable and operator advances

(40,446) (339,913)

Other current assets

(21,635) (6,278)

Accounts payable and accrued liabilities

(507,703) (1,005,851)

Income taxes payable/receivable

93,244 25,172


Net cash provided by operating activities

1,910,786 1,636,345


Cash flows from investing activities:

Capital expenditures

(665,812) (1,190,261)

Proceeds from sale of oil and gas properties

- 2,332,382

Net cash (used in) provided by investing activities

(665,812) 1,142,121


Cash flows from financing activities:

Payments on revolving credit facility

- (2,000,000)

Proceeds from stock option exercises

19,172


Net cash provided by (used in) financing activities

19,172 (2,000,000)


Net increase in cash 1,264,146 778,466
Cash and cash equivalents at beginning of period 5,032,922 1,348,024


Cash and cash equivalents at end of period $ 6,297,068 $ 2,126,490


 

 

The accompanying notes are an integral part of the financial statements.


 

EQUITY OIL COMPANY

NOTES TO FINANCIAL STATEMENTS

Note 1. Interim Financial Statements

In the opinion of the Company's management, the accompanying interim financial statements reflect the necessary adjustments, all of which are of a normal and recurring nature, to present fairly the financial position of Equity Oil Company (Equity or the Company) as of March 31, 2004, and the results of its operations and its cash flows for the three month periods ended March 31, 2004 and 2003.

The financial statements and the accompanying notes to financial statements have been prepared according to rules and regulations of the Securities and Exchange Commission. Accordingly, certain notes and other information have been condensed or omitted from the interim financial statements presented in this Quarterly Report on Form 10-Q. These financial statements should be read in conjunction with the Company's 2003 Annual Report on Form 10-K.

The results for the three month period ended March 31, 2004 are not necessarily indicative of future results.

 

Note 2. Net Income Per Share

Basic net income per share is computed using the weighted average number of common shares outstanding during the period. Diluted net income per share is computed using the weighted average number of common and, if dilutive, common equivalent shares outstanding during the period. Common equivalent shares consist of the incremental common shares issuable upon the exercise of stock options (using the treasury stock method). Options to purchase approximately 1,699,000 shares of common stock at prices of $1.06 to $5.125 per share were outstanding at March 31, 2004, of which, 658,109 incremental shares (1,548,625 options) were included in the computation of diluted net income per share for the three month period ended March 31, 2004. Options to purchase approximately 1,750,000 shares of common stock at prices of $1.06 to $5.125 per share were outstanding at March 31, 2003, of which, 222,844 incremental shares (768,800 options) were included in the computation of diluted net income per share for the three month period ended March 31, 2003.

 

Note 3. Hedging Activities

The Company periodically enters into oil and gas financial instruments to manage its exposure to oil and gas price volatility. The instruments are placed with counterparties that the Company believes are minimal credit risks. It is the Company’s policy to only enter into derivative contracts with investment grade rated counterparties deemed by management to be competent and competitive market makers. The oil and gas reference prices upon which the price hedging instruments are based reflect various market indices that have historically correlated with actual prices received by the Company.

As of March 31, 2004, the Company had a commodity price hedge in place for 5,000 MMBTU of natural gas per day under a costless collar though April 30, 2004. The hedge has a floor of $3.00 per MMBTU and a ceiling of $4.43 per MMBTU. The settlement price for the hedges during the quarter ended March 31, 2004 resulted in cash payments of $588,850 from the Company to the counterparty, which are reflected as a reduction of oil and gas sales. The fair value of the hedge at March 31, 2004, as computed by the counterparty, was ($144,750). This amount is shown on the balance sheet as a current liability.

 

Note 4. Asset Retirement Obligation

In August 2001, the FASB issued SFAS No. 143 (SFAS 143), "Accounting for Asset Retirement Obligations." SFAS 143 was effective for the Company beginning January 1, 2003. The most significant impact of this standard on the Company was a change in the method of accruing for site restoration costs associated with its oil and gas properties. Under SFAS 143, the fair value of asset retirement obligations is recorded as a liability when incurred, which is typically at the time the assets are placed in service. Amounts recorded for the related assets are increased by the amount of these obligations. Over time, the liabilities are accreted for the change in their present value and the initial capitalized costs are depreciated over the useful lives of the related assets.

The Company used an expected cash flow approach to estimate its asset retirement obligations under SFAS 143. Upon adoption at January 1, 2003, the Company recorded a retirement obligation of $3,147,061, an increase in property and equipment cost of $1,997,619, an increase in accumulated depreciation, depletion and amortization of $535,255 and a cumulative effect of accounting change, net of benefit from taxes, of $1,061,865.

The following table summarizes the changes in the Company’s asset retirement obligation for the period ended March 31, 2004:

Balance, December 31, 2003 $ 3,242,383


Accretion expense 58,500
Payments                   -

Balance, March 31, 2004 $ 3,300,883

 

At March 31, 2004, there are no assets legally restricted for purposes of settling asset retirement obligations. There was no impact on the Company’s cash flows as a result of adopting SFAS 143 since the cumulative effect of change in accounting and the charges to expense for depreciation and accretion are non-cash transactions.

 

Note 5. Stock Based Compensation Plans

At March 31, 2004, the Company had one stock-based compensation plan. The Company applies APB Opinion No. 25 and related interpretations in accounting for this plan. Accordingly, no compensation cost has been recognized for options granted to employees under its fixed stock option plan.

In December 2002, the FASB issued SFAS 148, "Accounting for Stock-Based Compensation Transition and Disclosure (SFAS 148)," which amends SFAS 123 "Accounting for Stock-Based Compensation." SFAS 148 requires more prominent and frequent disclosures about the effects of stock-based compensation. The Company has adopted the disclosure provisions of SFAS 148. The Company will continue to account for its stock-based compensation according to the provisions of APB Opinion No. 25.

Had compensation cost for the Company's stock options been recognized based on the estimated fair value on the grant date under the fair value methodology prescribed by SFAS 123, the Company's net income and income per share would have been as follows:

For the three months ended

March 31, 2004

March 31, 2003



Net Income, as reported $ 396,576 $ 475,727
Less: Total stock-based employee compensation expense determined under the fair value based method for all awards, net of related tax effects 45,353 36,772


Pro forma net income $ 351,223 $ 438,955


Net Income per share
Basic: As reported $ .03 $ .04
Pro forma $ .03 $ .04
Diluted: As reported $ .03 $ .04
Pro forma $ .03 $ .04

 

Note 6. Discontinued Operations

During February and March 2003, three packages of Canadian oil and gas properties were sold for approximately $2.4 million, resulting in a gain of approximately $1.1 million ($655,168 net of tax). In accordance with the provisions of SFAS No. 144, "Accounting for the Impairment or Disposal of Long-Lived Assets", the results of operations and gain on sale of these properties have been reflected as discontinued operations. Revenue from these Canadian oil and gas properties was approximately $147,000 for the three month period ended March 31, 2003. After the sales, the Company’s remaining Canadian asset is its 50% interest in the Cessford Field located in southern Alberta.

 

Note 7. Intangible Assets

SFAS No. 141, "Business Combinations" (SFAS 141) and SFAS No. 142, "Goodwill and Intangible Assets" (SFAS 142) were issued by the FASB in June 2001 and became effective for the Company on July 1, 2001 and January 1, 2002, respectively. SFAS 141 requires all business combinations initiated after June 30, 2001 to be accounted for using the purchase method. Additionally, SFAS 141 requires companies to disaggregate and report separately from goodwill certain intangible assets. SFAS 142 establishes new guidelines for accounting for goodwill and other intangible assets. Under SFAS 142, goodwill and certain other intangible assets are not amortized, but rather are reviewed annually for impairment. One interpretation being considered relative to these standards is that oil and gas mineral rights held under lease and other contractual arrangements representing the right to extract such reserves from both undeveloped and developed leaseholds should be classified separately from oil and gas properties, as intangible assets on the Company’s balance sheets. In addition, the disclosures required by SFAS 141 and 142 relative to intangible assets would be included in the notes to financial statements. Historically, the Company, like many other oil and gas companies, has included these oil and gas mineral rights held under lease and other contractual arrangements representing the right to extract such reserves as part of oil and gas properties, even after SFAS 141 and 142 became effective.

This interpretation of SFAS 141 and 142 would only affect the Company’s balance sheet classification of oil and gas leaseholds. The Company’s results of operations and cash flows would not be affected, since these oil and gas mineral rights held under lease and other contractual arrangements representing the right to extract such reserves would continue to be amortized in accordance with accounting rules for oil and gas companies provided in SFAS No. 19, "Financial Accounting and Reporting by Oil and Gas Producing Companies" (SFAS 19).

At March 31, 2004 the Company had net undeveloped leaseholds of approximately $1,775,000 that would be classified on the Company’s balance sheet as "intangible undeveloped leaseholds" and net developed leaseholds of approximately $1,995,000 that would be classified as "intangible developed leaseholds" if the Company applied the interpretation currently being discussed.

The Company will continue to classify its oil and gas mineral rights held under lease and other contractual rights representing the right to extract such reserves as tangible oil and gas properties until further guidance is provided.

 

Note 8. Merger Agreement

On February 2, 2004 the Company announced that it had entered into a definitive merger agreement with Whiting Petroleum Corporation ("Whiting"). The merger agreement was entered into on February 1, 2004. The merger agreement provides for a stock-for-stock merger under which Equity shareholders will receive a fixed exchange ratio of 0.185 shares of Whiting stock for each share of Equity stock which they own. The merger will result in Whiting shareholders and Equity shareholders owning approximately 88.4% and 11.6% of the combined company, respectively. The merger is subject to the approval of shareholders owning two-thirds of the outstanding Equity shares and other customary closing conditions. Equity intends to call a special meeting of its shareholders late in the second quarter of 2004 to consider and vote on the merger. The parties expect to complete the merger as soon as practicable following approval by the Equity shareholders.

 

ITEM 2

 

Management's Discussion and Analysis of Financial Condition and Results of Operations

This quarterly report is for the period ended March 31, 2004, and describes our operations, assets and prospects as of that date. On February 1, 2004, we entered into an agreement and plan of merger with Whiting Petroleum Corporation "Whiting" and WPC Equity Acquisition Corp., a wholly owned subsidiary of Whiting, pursuant to which we will become a wholly-owned subsidiary of Whiting. This transaction is described in more detail in our joint press release with Whiting attached as an exhibit to our current report on Form 8-K dated February 2, 2004. See Note 8 to the financial statements included elsewhere in this report for additional information. Consummation of the merger, which is subject to customary conditions, including the approval of our shareholders, is expected to occur late in the second quarter of 2004.

 

RESULTS OF OPERATIONS

Higher commodity prices for the quarter for both oil and natural gas offset lower volumes, particularly lower natural gas volumes. During the 2004 first quarter, lower payments were made pursuant to the Company’s hedging program than during the same period of 2003. Thus the actual received price for both oil and natural gas was higher in 2004 than in 2003. Oil and gas sales were 5% lower in the first quarter of 2004 as compared to the first quarter of 2003. Total oil and gas sales for the three month period ended March 31, 2004 were $6,415,600, compared to $6,728,397 during the first quarter of 2003.

The Company recorded net income for the 2004 first quarter of $369,576 or $.03 per share. This compares to net income for the first quarter of 2003 of $475,727, or $.04 per share. Costs associated with the proposed merger with Whiting of approximately $580,000 in the first quarter of 2004 had a significant impact on earnings for the period. Gain from the sale of certain Canadian properties of approximately $745,000 and the loss attributable to a cumulative effect of change in accounting method of approximately $1.06 million were included in the first quarter of 2003. There were no similar amounts for 2004.

Oil production in the 2004 first quarter was 140,000 barrels compared to 145,000 barrels in the first quarter of 2003. The decrease is attributable to the normal production declines of our properties as they mature. Gas production decreased during the quarter from 898 million cubic feet in the first quarter of 2003 and 712 million cubic feet in the fourth quarter of 2003 to 605 million cubic feet during the first quarter of 2004. The decline in gas production is attributable to earlier than anticipated depletion of certain of the Sacramento Basin gas properties acquired in 2002.

The average crude oil price received in the first quarter 2004 was $32.00 per barrel, compared to $24.88 per barrel received during the same period of 2003. Gas prices also increased in the first quarter of 2004, averaging $4.83 per Mcf, compared to $3.36 per Mcf received during the first quarter of 2003. The received prices are calculated net of payments made under hedging agreements. During the first quarter of 2004, the Company made payments to the counterparty for natural gas hedges of $588,850 as compared to payments made during the same period of 2003 of $663,366 on oil hedges and $1,099,079 on natural gas hedges.

As of March 31, 2004, the Company had a commodity price hedge in place for 5,000 MMBTU of natural gas per day under a costless collar. The gas hedge has a floor of $3.00 and a ceiling of $4.43 per MMBTU through April 2004. The fair value of the hedge at March 31, 2004, as computed by the counterparty, was ($144,750). This amount is shown on the balance sheet as a current liability.

Operating expenses were higher in 2004 than 2003. Lease operating costs increased from $2,003,716 in 2003 to $2,162,018 in 2004, an 8% increase. The increase is attributable primarily to higher costs associated with outside vendors for field operating related services.

Depreciation, depletion and amortization (DD&A) charges during the 2004 quarter were lower than the amount recorded during the same quarter of 2003. This decrease is attributable to lower production volumes in the 2004 first quarter when compared to the same period of 2003.

 

The decrease in general and administrative expenses is primarily attributable to lower salary expense, lower insurance costs and lower legal fees not associated with the proposed merger.

Merger related costs are cost associated with the proposed merger with Whiting. These costs include investment advisor fees of approximately $270,000, additional legal fees of approximately $250,000 and fees paid to members of the special committee of the board of directors of $75,000 for their services rendered.

The decrease in production and exploration overhead is attributable to lower salary costs for employees.

 

Lower interest costs in 2004 reflect the lower balance of the debt outstanding under the Company’s credit facility and lower interest rates. The average interest rate on debt outstanding during the 2004 first quarter was approximately 3.37% as compared to 3.55% for the same period of 2003.

During February and March 2003, three packages of Canadian oil and gas properties were sold for approximately $2.4 million, resulting in a gain of approximately $1.2 million ($745,209 net of tax). In accordance with the provisions of SFAS 144, "Accounting for the Impairment or Disposal of Long-Lived Assets", the results of operations and gain on sale of these properties have been reflected as discontinued operations. Revenue from these Canadian oil and gas properties was approximately $147,000 for the three month period ended March 31, 2003. After the sales, the Company’s remaining Canadian asset is its 50% interest in the Cessford Field located in southern Alberta.

 

CAPITAL RESOURCES AND LIQUIDITY

The Company’s cash balances increased 25% from December 31, 2003. The increase is primarily the result of no payments being made on the credit facility during the quarter in anticipation of upcoming capital spending requirements and other costs associated with the proposed merger.

Cash flow from operating activities in the first three months of 2004 increased 17% or $274,000 from $1,636,345 for the three months ended March 31, 2003 to $1,910,785 for the three months ended March 31, 2004. The increase is due primarily to changes in working capital in 2004 as compared to 2003, offset by the impact of deferred taxes.

Investment in property and equipment for the three months ended March 31, 2004 totaled $665,811 compared to $1,190,261 during the same period of 2003.

Debt outstanding at March 31, 2004 was unchanged from the year-end amount of $29 million. At March 31, 2004, our borrowing base as determined by our bank was $35 million; thus we had $6.0 million of remaining availability under the current commitment on the facility, which expires in April 2005.

We believe that existing cash balances, cash flow from operating activities, and funds available under the Company's credit facility will provide adequate resources to meet our capital and exploration spending objectives.

 

OFF BALANCE SHEET ARRANGEMENTS

We have no significant off-balance sheet arrangements.

 

TABULAR DISCLOSURE OF CONTRACTUAL OBLIGATIONS

The following table sets forth payments due by period for contractual obligations as of March 31, 2004:

Total 0-3 Years
Revolving credit facility $29,000,000 $29,000,000


 

 

 

 

OTHER ITEMS

The Company has reviewed all recently issued, but not yet adopted, accounting standards in order to determine their effects, if any, on the results of operations or financial position of the Company. Based on that review, the Company believes that none of these pronouncements will have a significant effect on our current or future financial position or results of operations.

 

CRITICAL ACCOUNTING POLICIES

A summary of our significant accounting policies is included in Note 1 of our financial statements contained in our annual report on Form 10-K for the year ended December 31, 2003. We believe the application of these accounting policies on a consistent basis enables us to provide financial statement users with useful, reliable and timely information about our results of operations, financial condition and cash flows.

The preparation of financial statements in accordance with accounting principles generally accepted in the United States of America requires management to make judgements, estimates and assumptions regarding uncertainties that affect the reported amounts presented and disclosed in the financial statements. Our management reviews these estimates and assumptions based on historical experience, changes in business conditions and other relevant factors that they believe to be reasonable under the circumstances. In any given reporting period, actual results could differ from the estimates and assumptions used in preparing our financial statements.

Critical accounting policies are those that may have a material impact on our financial statements and also require management to exercise significant judgement due to a high degree of uncertainty at the time the estimate is made. Our senior management has discussed the development and selection of our accounting policies, related accounting estimates and the related disclosures with the Audit Committee of our Board of Directors. We believe our critical accounting policies include those addressing the recoverability and useful lives of assets, and oil and gas reserve estimates. A summary of our critical accounting policies is included in the Management’s Discussion and Analysis portion of our annual report on Form 10-K for the year ended December 31, 2003.

 

FORWARD LOOKING STATEMENTS

This report contains statements that we believe to be "forward-looking statements" within the meaning of the Private Securities Litigation Reform Act of 1995. All statements other than historical facts, including, without limitation, statements regarding our future financial position, business strategy, projected revenues, earnings, costs, capital expenditures and debt levels, and plans and objectives of management for future operations, are forward-looking statements. When used in this report, words such as we "expect," "intend," "plan," "estimate," "anticipate," "believe" or "should" or, the negative thereof or variations thereon or similar terminology, are generally intended to identify forward-looking statements. Such forward-looking statements are subject to risks and uncertainties that could cause actual results to differ materially from those expressed in, or implied by, such statements. Some, but not all, of the risks and uncertainties include: the uncertainties relating to and consequences of completing a proposed transaction (described in more detail below) with Whiting Petroleum Corporation ("Whiting"); declines in oil or natural gas prices; our level of success in exploitation, exploration, development and production activities; our ability to obtain external capital to finance acquisitions; our ability to identify and complete acquisitions and to successfully integrate acquired businesses; unforeseen underperformance of or liabilities associated with acquired properties; inaccuracies of our reserve estimates or our assumptions underlying them; failure of our properties to yield oil or natural gas in commercially viable quantities; uninsured or underinsured losses resulting from our oil and natural gas operations; our inability to access oil and natural gas markets due to market conditions or operational impediments; the impact and costs of compliance with laws and regulations governing our oil and natural gas operations; risks related to our level of indebtedness and periodic redeterminations of our borrowing base under our credit facility; our ability to replace our oil and natural gas reserves; any loss of our senior management or technical personnel; competition in the oil and natural gas industry; and risks arising out of any hedging transactions we have entered into or may enter into in the future. We assume no obligation, and disclaim any duty, to update the forward-looking statements in this report.

 

ITEM 3

Quantitative and Qualitative Disclosures about Market Risk

The primary objective of the following information is to provide forward-looking quantitative and qualitative information about our potential exposure to market risks. We are exposed to various market risks, principally fluctuating interest rates and changes in commodity prices. These risks can impact our results of operations, cash flows and financial position. We manage these risks through regular operating and financing activities and periodically use derivative financial instruments such as commodity price hedging agreements.

The following analysis presents the effect on earnings, cash flows and financial position as if the hypothetical changes in market risk factors occurred on March 31, 2004. Only the potential impacts of hypothetical assumptions are analyzed. This analysis does not consider other possible effects that could impact our business.

 

Interest rate risk. At March 31, 2004, the amount outstanding under our credit facility was $29.0 million. The weighted average interest rate for this facility was 3.37%. Assuming constant debt levels, earnings and cash flow impacts for the next twelve month period from March 31, 2004 due to a one percent change in interest rates would be approximately $290,000 before taxes.

 

Commodity price risk. Oil and gas commodity markets are influenced by global as well as regional supply and demand. Worldwide political events can also impact commodity prices. Pricing for oil and natural gas production has been volatile and unpredictable for many years. In accordance with our current lending facility and to hedge exposure to changing commodity prices, we periodically enter into financial hedge contracts. Hedging may limit the Company’s exposure to adverse price limits. However, hedging also limits the benefit of price increases and is subject to a number of risks, including credit risk of the counterparty to the hedge. For additional information, see note 3 to the financial statements.

The terms of our current credit facility required that not later than thirty days subsequent to the date of such facility (April 12, 2002) not less than 50% of our projected monthly production be hedged at price levels and terms acceptable to the lender. Our current hedging activity satisfies all lender requirements and there are no further hedging obligations. During 2004, the Company made net payments to the counterparty of $588,850 under the hedge agreements in place. This amount is netted against our oil and gas revenue. During the same period of 2003, the Company made net payments of $1,762,445 to the counterparty.

We account for our hedging activity pursuant to SFAS 133, accordingly we include the fair value of these hedges ($144,750 liability at March 31, 2004) on our balance sheet. "Fair value" represents the value computed by the counterparty using a financial modeling technique including a type of Black-Scholes method. As these contracts qualify and have been designated as cash flow hedges, we determine gains and losses on them resulting from market price changes at least quarterly and reflect them in accumulated other comprehensive income (loss) until the period in which the hedge is settled. At that time, the amount paid to or received from the counterparty is included in oil and gas revenue. We do not intend to terminate our current commodity hedges prior to their expiration date.

The hedge we had in place at March 31, 2004 was a costless collar. The Company utilizes collars that establish a price between a floor and ceiling to hedge oil and natural gas prices. The table below sets forth our natural gas collar in place at March 31, 2004

Per
Day
Mmbtu

Average
Floor
MMbtu

Average
Ceiling
MMbtu

Fair
Value of
Financial
Instrument
Asset/
(Liability)
(thousands)





Gas
04/01/04 - 04/30/04

5,000

$ 3.00 $ 4.43

$

(145)

 

 

 

ITEM 4

Controls and Procedures

As of the end of the period covered by this report, the Company's principal executive officer ("CEO") and principal financial officer ("CFO") carried out an evaluation of the effectiveness of the Company's disclosure controls and procedures. Based on those evaluations, the Company's CEO and CFO believe

(i) that the Company's disclosure controls and procedures are designed to ensure that information required to be disclosed by the Company in the reports it files under the Securities Exchange Act of 1934 is recorded, processed, summarized and reported within the time periods specified in the SEC's rules and forms and that such information is accumulated and communicated to the Company's management, including the CEO and CFO, as appropriate to allow timely decisions regarding required disclosure; and

(ii) that the Company's disclosure controls and procedures are effective.

There have been no significant changes in the Company's internal controls or in other factors that could significantly affect the Company's internal controls subsequent to the evaluation referred to in Item 4, above, nor have there been any corrective actions with regard to significant deficiencies or material weaknesses.

 

 

PART II

OTHER INFORMATION

The answers to items one through five listed under Part II are inapplicable or negative, except as shown below

 

 

ITEM 6. Exhibits and Reports on Form 8-K

(b)

Reports on Form 8-K

Filing Date

Contents

February 2, 2004

 

February 25, 2004

Press release regarding merger with Whiting Petroleum Corporation


Press release regarding year-end 2003 financial results.

(c) Exhibits
(3) (i) Amendment to Article III of Restated Articles of Incorporation adopted on May 21, 2003 and Restated Articles of Incorporation as amended incorporated by reference from the Form 10-Q for the period ended June 30, 2003.
(ii) Amended By-Laws incorporated by reference from the annual report on Form 10-K for the year-ended December 31, 1997.
(10.1) Loan agreement between Equity Oil Company and Bank One, NA incorporated by reference from the Form 10-Q for the period ended June 30, 2002.
(10.2) Change in Control Compensation Agreement for David P. Donegan incorporated by reference from the Form 10-Q for the period ended June 30, 2001. Change in Control Compensation Agreement for Russell V. Florence, incorporated by reference from the annual report on Form 10-K for the year-ended December 31, 2000. Change in Control Compensation Agreements for Paul M. Dougan and James B. Larson, incorporated by reference from the annual report on Form 10-K for the year-ended December 31, 1997.
(10.3) Equity Oil Company 2000 Stock Option Plan incorporated by reference from Appendix A of the proxy statement dated May 10, 2000.
(10.4) Cash bonus plan for key employees incorporated by reference from the Form 10-K for the year ended December 31, 2002.
(14) Code of Business Conduct and Ethics incorporated by reference from the Form 10-K for the year ended December 31, 2003.
(21) Subsidiaries.
Incorporated by reference from the annual report on Form 10-K for the year-ended December 31, 1995.
(31) Certifications required by Rule 13a-15(e) and 15d-15(e).
(32) Section 1350 Certifications.

 

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.

 

EQUITY OIL COMPANY
By: /s/ Paul M. Dougan
Paul M. Dougan
President
Chief Executive Officer
Director
By: /s/ Russell V. Florence
Russell V. Florence
Treasurer
Chief Financial Officer

 

Date: May 12, 2004