Edgar Filing: ARENA RESOURCES INC

UNITED STATES

UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

WASHINGTON, D.C. 20549

FORM 10-QSB

(Mark One)

[X] QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934

For the Quarterly Period Ended June 30, 2004

[ ] TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(D) OF THE SECURITIES EXCHANCE ACT OF 1934

FOR THE TRANSITION PERIOD From __________ to __________.

Commission File Number 001-31657

ARENA RESOURCES, INC.

(Exact name of registrant as specified in its charter)

Nevada

73-1596109

(State or other jurisdiction of

(I.R.S. Employer

Incorporation or organization)

Identification No.)

4920 South Lewis Street, Suite 107

Tulsa, Oklahoma 74105

(Address of principal executive officers)

(918) 747-6060

(Issuer’s telephone number)

Check whether the registrant (1) has filed all reports required to be filed by Section 13 or 15(d) of the Exchange Act during the past 12 months, and (2) has been subject to such filing requirements for the past 90 days. _X_ Yes ___ No

Indicate the number of shares outstanding of each of the issuer’s classes of common stock, as of the latest practical date:

As of August 10, 2004, the Company had outstanding 7,192,097 shares of common stock ($0.001 par value).

Transitional Small Business Disclosure Format (check one): Yes ____

No __X__

actions wi

INDEX

Arena Resources, Inc.

For the Quarter Ended June 30, 2004

Part I. Financial Information

Page

Item 1. Financial Statements (Unaudited)

Condensed Balance Sheets as of June 30, 2004 and

December 31, 2003 (Unaudited)

Condensed Statements of Operations for the Three and Six Months

Ended June 30, 2004 and 2003 (Unaudited)

Condensed Statements of Cash Flows for the Six Months

Ended June 30, 2004 and 2003 (Unaudited)

Notes to Condensed Financial Statements (Unaudited)

Item 2. Management’s Discussion and Analysis of Financial Condition and

Results of Operations

Item 3. Controls and Procedures

Part II. Other Information

Item 1. Legal Proceedings

Item 4. Submission of Matters to a Vote of Security Holders

Item 5. Other Information

Item 6. Exhibits and Reports on Form 8-K

Signatures

Part I – Financial Information

Item I. Financial Statements:

The condensed financial statements included herein have been prepared pursuant to the rules and regulations of the Securities and Exchange Commission. Certain information and footnote disclosures normally included in financial statements prepared in accordance with accounting principles generally accepted in the United States of America have been condensed or omitted pursuant to such rules and regulations, although the Company believes that the disclosures are adequate to make the information presented not misleading.

In the opinion of the Company, all adjustments, consisting of only normal recurring adjustments, necessary to present fairly the financial position of the Company and the results of its operations and its cash flows have been made. The results of its operations and its cash flows for the six months ended June 30, 2004 are not necessarily indicative of the results to be expected for the year ending December 31, 2004.

ARENA RESOURCES, INC.

CONDENSED BALANCE SHEETS

(UNAUDITED)

	June 30,	December 31,
	2004	2003

ASSETS
Current Assets
Cash	$ 1,921,984	$ 1,076,676
Account receivable	699,214	388,910
Short-term investments	25,234	25,234
Prepaid expenses	33,564	28,935

Total Current Assets	2,679,996	1,519,755

Property and Equipment, Using Full Cost Accounting
Oil and gas properties subject to amortization	19,128,135	8,463,400
Drilling advances	244,795	351,000
Equipment	26,687	48,480
Office equipment	37,013	18,978
Total Property and Equipment	19,436,630	8,881,858
Less: Accumulated depreciation and amortization	(869,347)	(559,229)

Net Property and Equipment	18,567,283	8,322,629

Deferred Offering Costs	335,573	130,872

Total Assets	$ 21,582,852	$ 9,973,256

LIABILITIES AND STOCKHOLDERS' EQUITY
Current Liabilities
Accounts payable	$ 271,529	$ 229,522
Accrued liabilities	79,089	18,440
Put option	-	2,905
Short-term note payable	2,000,000	-

Total Current Liabilities	2,350,618	250,867

Long-Term Liabilities
Notes payable	8,008,440	-
Notes payable to related parties	400,000	400,000
Asset retirement liability	664,712	607,200
Deferred income taxes	1,111,962	656,759

Total Long-Term Liabilities	10,185,114	1,663,959

Stockholders' Equity
Preferred stock - $0.001 par value; 10,000,000 shares authorized;
no shares issued or outstanding	-	-
Common stock - $0.001 par value; 100,000,000 shares authorized;
7,192,097 shares and 7,162,097 shares outstanding, respectively	7,192	7,162
Additional paid-in capital	7,142,419	6,994,925
Options and warrants outstanding	796,140	813,164
Retained earnings	1,101,369	243,179

Total Stockholders' Equity	9,047,120	8,058,430

Total Liabilities and Stockholders' Equity	$ 21,582,852	$ 9,973,256

See the accompanying notes to unaudited condensed financial statements.

ARENA RESOURCES, INC.

CONDENSED STATEMENTS OF OPERATIONS

(UNAUDITED)

		For the Three Months		For the Six Months
		Ended June 30,		Ended June 30,
		2004	2003	2004	2003

Oil and Gas Revenues		$ 1,792,414	$ 841,619	$ 2,992,814	$ 1,648,640

Costs and Operating Expenses
	Oil and gas production costs	403,531	281,546	719,820	523,618
	Oil and gas production taxes	133,026	57,374	211,733	111,324
	Depreciation, depletion and amortization	204,706	89,167	315,826	133,371
	General and administrative expense	163,569	120,451	341,771	264,082

Total Costs and Operating Expenses		904,832	548,538	1,589,150	1,032,395

Other Income (Expense)
	Gain from change in fair value of put options	2,905	31,615	2,905	36,390
	Accretion expense	(12,770)	(7,843)	(25,065)	(12,624)
	Interest expense	(58,998)	(9,973)	(68,111)	(19,836)

Net Other Income (Expense)		(68,863)	13,799	(90,271)	3,930

Income Before Provision for Income Taxes and Cumulative
Effect of Change in Accounting Principle		818,719	306,880	1,313,393	620,175

Provision for Deferred Income Taxes		270,171	114,328	455,203	225,760

Income Before Cumulative Effect of Change
in Accounting Principle		548,548	192,552	858,190	394,415

Cumulative Effect of Change in Accounting Principle		-	-	-	(11,813)

Net Income		$ 548,548	$ 192,552	$ 858,190	$ 382,602

Basic Income Per Common Share
	Before cumulative effect of change in accounting principle	$ 0.08	$ 0.03	$ 0.12	$ 0.06
	Net Income	0.08	0.03	0.12	0.06
Diluted Income Per Common Share
	Before cumulative effect of change in accounting principle	$ 0.07	$ 0.03	$ 0.11	$ 0.06
	Net Income	0.07	0.03	0.11	0.06

See the accompanying notes to unaudited condensed financial statements.

ARENA RESOURCES, INC.

CONDENSED STATEMENTS OF CASH FLOWS

(UNAUDITED)

*For the Six Months Ended June 30,*		2004	2003


Cash Flows From Operating Activities
	Net income	$ 858,190	$ 382,602
	Adjustments to reconcile net income to net cash
	provided by operating activities:
	Shares issued for services	-	75,040
	Depreciation, depletion and amortization	315,826	133,371
	Gain from change in fair value of put option	(2,905)	(36,390)
	Cumulative effect of change in accounting principle	-	11,813
	Loss on sale of equipment	5,585	-
	Accretion of discounted liabilities	57,511	12,625
	Changes in assets and liabilities:
	Accounts receivable	(310,304)	(75,585)
	Prepaid expenses	(4,629)	(57,280)
	Accounts payable and accrued liabilities	102,657	14,354
	Deferred income taxes	455,203	225,760

	Net Cash Provided by Operating Activities	1,477,134	686,310

Cash Flows from Investing Activities
	Proceeds from sale of equipment	10,500	-
	Purchase of oil and gas properties	(1,550,090)	(1,186,971)
	Purchase of property, plant & equipment	-	(26,686)
	Purchase of office equipment	(18,035)	(643)

	Net Cash Used in Investing Activities	(1,557,625)	(1,214,300)

Cash Flows From Financing Activities
	Proceeds from issuance of common stock and warrants, net of offering costs	(204,701)	1,135,165
	Proceeds from exercise of warrants	130,500	7,000
	Issuance of note payable	1,000,000	-
	Collection of common stock subscription receivable	-	157,500
	Payment of accrued dividends to preferred stockholders	-	(114,685)

	Net Cash Provided by (Used in) Financing Activities	925,799	1,184,980

Net Increase in Cash		845,308	656,990

Cash at Beginning of Period		1,076,676	796,915

Cash at End of Period		$ 1,921,984	$ 1,453,905


Supplemental Cash Flows Information
	Cash paid for interest	$ 69,331	$ 19,836

Non-Cash Investing and Financing Activities
	Common stock issued for properties	-	52,000
	Asset retirement obligation incurred in property acquisition	-	227,308
	Acquisition of property financed through note payable	9,008,440	-

See the accompanying notes to unaudited condensed financial statements.

ARENA RESOURCES, INC.

NOTES TO UNAUDITED CONDENSED FINANCIAL STATEMENTS

MARCH 31, 2004

NOTE 1 – BASIS OF PRESENTATION AND SIGNIFICANT ACCOUNTING POLICIES

Condensed Financial Statements – The accompanying condensed financial statements have been prepared by the Company and are unaudited. In the opinion of management, the accompanying unaudited financial statements contain all adjustments necessary for fair presentation, consisting of normal recurring adjustments, except as disclosed herein.

The accompanying unaudited interim financial statements have been condensed pursuant to the rules and regulations of the Securities and Exchange Commission; therefore, certain information and disclosures generally included in financial statements have been condensed or omitted. The condensed financial statements should be read in conjunction with the Company’s annual financial statements included in its annual report on Form 10-KSB as of December 31, 2003. The financial position and results of operations for the six months ended June 30, 2004 are not necessarily indicative of the results to be expected for the full year ending December 31, 2004.

Nature of Operations – The Company owns interests in oil and gas properties located in Oklahoma, Texas, Kansas and New Mexico. The Company is engaged primarily in the acquisition, exploration and development of oil and gas properties and the production and sale of oil and gas.

Use of Estimates – The preparation of financial statements in conformity with accounting principles generally accepted in the United States of America requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities, disclosure of contingent assets and liabilities and the reported amounts of revenues and expenses during the reporting period. Actual results could differ from those estimates.

Oil and Gas Properties – The Company uses the full cost method of accounting for oil and gas properties. Under this method, all costs associated with acquisition, exploration, and development of oil and gas reserves are capitalized. Costs capitalized include acquisition costs, geological and geophysical expenditures, lease rentals on undeveloped properties and costs of drilling and equipping productive and non-productive wells. Drilling costs include directly related overhead costs. Capitalized costs are categorized either as being subject to amortization or not subject to amortization.

All capitalized costs of oil and gas properties, including the estimated future costs to develop proved reserves and estimated future costs of abandonment and site restoration, are amortized on the unit-of-production method using estimates of proved reserves as determined by independent engineers. Investments in unproved properties and major development projects are not amortized until proved reserves associated with the projects can be determined. The Company evaluates oil and gas properties for impairment at least quarterly. If the results of an assessment indicate that the properties are impaired, the amount of the impairment is added to the capitalized costs to be amortized. Amortization expense for the six months ended June 30, 2004 was $315,826 based on depletion at the rate of $3.49 per barrel of oil equivalent compared to $133,371 based on depletion at the rate of $2.06 per barrel of oil equivalent for the six months ended June 30, 2003. These amounts include $6,517 and $4,767 of depreciation on equipment during the six months ended June 30, 2004 and 2003, respectively.

In addition, capitalized costs are subject to a ceiling test which limits such costs to the estimated present value of future net revenues from proved reserves, discounted at a 10-percent interest rate, based on current economic and operating conditions, plus the lower of cost or fair market value of unproved properties. Consideration received from sales or transfers of oil and gas property is accounted for as a reduction of capitalized costs. Revenue is not recognized in connection with contractual services performed in connection with properties in which the Company holds an ownership interest.

Income Per Common Share – Basic income per common share is computed by dividing net income by the weighted-average number of common shares outstanding during the period. Diluted income per share reflects the potential dilution that could occur if all contracts to issue common stock were converted into common stock, except for those that are anti-dilutive.

Concentration of Credit Risk and Major Customer – The Company currently has cash in excess of federally insured limits at June 30, 2004. During the six months ended June 30, 2004, sales to four customers represented 39%, 33%, 13% and 6% of total sales, respectively. At June 30, 2004, these four customers made up 28%, 42%, 8% and 11% of accounts receivable, respectively.

Stock-Based Employee Compensation – The Company applies the recognition and measurement principles of Accounting Principles Board Opinion No. 25, Accounting for Stock Issued to Employees (APB 25) and related interpretations in accounting for its stock-based compensation awards to employees. Under APB 25, no stock-based compensation expense was charged to earnings, as all options granted had an exercise price equal to or greater than the adjusted fair value of the underlying common stock on the grant date.

Alternately, Statement on Financial Accounting Standards No. 123, Accounting for Stock-Based Compensation (SFAS No. 123), allows companies to recognize compensation expense over the related service period based on the grant date fair value of the stock option awards. The following table illustrates the effect on net income and basic and diluted income per common share if the Company had applied the fair value recognition provisions of SFAS No. 123 to stock-based employee compensation:

*For the Six Months Ended June 30,*		2004	2003
Net income, as reported		$ 858,190	$ 382,602
Deduct: Total stock-based employee compensation
	expense determined under the fair value based
	method for all awards, net of related tax effects	(75,098)	-

Pro Forma Net Income		$ 783,092	$ 382,602
Income per Common Share
	Basic, as reported	$ 0.12	$ 0.06
	Basic, pro forma	0.11	0.06
	Diluted, as reported	0.11	0.06
	Diluted, pro forma	0.10	0.06

NOTE 2 – EARNINGS PER SHARE INFORMATION

[TABLE]

NOTE 3 – ACQUISITION OF OIL AND GAS PROPERTIES

On May 7, 2004, the Company acquired an 82.24% working interest, 67.60% net revenue interest, in the East Hobbs San Andres Property mineral lease (“East Hobbs”) located in Lea County, New Mexico. Although the Purchase and Sales Agreement transferred the revenue and the related operating costs from East Hobbs to Arena beginning March 1, 2004, Arena did not control the property interests until May 7, 2004. As a result, the acquisition date for accounting purposes was May 7, 2004 and the operations of East Hobbs’ operations will be included in the results of operations of Arena from May 7, 2004. Revenues and operating costs for the months of March and April have been estimated and treated as adjustments to the purchase price. Those estimates are subject to adjustment when actual information is available; thus, the purchase price and the allocation of the purchase price are subject to refinement.

East Hobbs is comprised of 20 operating oil and gas wells that were unitized into one lease prior to the acquisition. The Company purchased East Hobbs for its current production and cash flow, as well as for the drilling and secondary recovery opportunities from the property. The purchase price was $10,036,440 and consisted of $10,008,440 of cash and $28,000 of estimated acquisition costs. The acquisition was funded through the use of a credit facility and bridge financing described more fully in Note 4. The purchase price was allocated to the assets acquired and the liabilities assumed as follows:

	Accounts receivable	$ 187,221
	Oil and gas properties subject to amortization	9,983,302
	Total Assets Acquired	10,170,523
	Accounts payable	(101,636)
	Asset retirement obligation	(32,447)
	Total Liabilities Assumed	(134,083)
	Net Assets Acquired	$ 10,036,440

The following pro forma information is presented to reflect the operations of the Company as if the acquisition of East Hobbs had been completed on January 1, 2004 and 2003, respectively:

For the Three Months Ended March 31,	2004	2003

Oil and Gas Revenues	$ 1,813,406	$ 1,481,834
Income from Operations Before Cumulative Effect of Change
in Accounting Principle	447,818	373,446
Net Income	447,818	361,633
Basic and Diluted Income Per Common Share
Income before cumulative effect of change in accounting princ	$ 0.06	$ 0.07
Net income	0.06	0.07

NOTE 4 – NOTES PAYABLE

On February 3, 2003, the Company established a $10,000,000 revolving credit facility with a bank with an initial borrowing base of $2,000,000. On December 31, 2003, the Company entered into an agreement that increased the revolving credit facility to $20,000,000 and increased the initial borrowing base to $4,000,000. On April 14, 2004, the Company changed financial institutions and thereby canceled this credit facility.

On April 14, 2004, the Company established a new $15,000,000 credit facility from a bank with an $8,500,000 initial borrowing base. Any increases in the borrowing base are subject to written consent by the financial institution. The interest rate is a floating rate equal to the 30, 60 or 90 day LIBOR plus 2.25%, currently 3.42% per annum, and is payable monthly. Annual fees for the facility are 1/8 of one percent of the unused portion of the borrowing base. Amounts borrowed under the revolving credit facility are due in April 2007. The revolving credit facility is secured by the Company’s principal mineral interests. In order to obtain the revolving credit facility, loans from two officers were subordinated to the position of the bank. The Company is required under the terms of the credit facility to maintain a tangible net worth of $6,000,000, maintain a 5-to-1 ratio of income before interest, taxes, depreciation, depletion and amortization to interest expense and maintain a current asset to current liability ratio of 1-to-1, not including the $2,000,000 bridge financing arrangement discussed below. On May 7, 2004, the Company drew $8,008,440 under this revolving credit facility to fund the acquisition of the East Hobbs San Andres Property interests. An additional $294,029 is reserved under the revolving credit facility as collateral for standby letters of credit issued to various states.

On April 14, 2004, the Company also entered into to a bridge financing arrangement for $2,000,000 from a bank. On May 7, 2004, the Company borrowed $2,000,000 under the terms of the bridge financing arrangement to fund the acquisition of the East Hobbs San Andres Property interests. The interest rate on the bridge financing arrangement is a floating rate equal to the 30, 60 or 90 day LIBOR plus 2.25%, currently 3.42% per annum, and is payable monthly. The bridge financing arrangement has been guaranteed by two of the Company’s officers. As disclosed in Note 8, Subsequent Events, the Company has paid all principal and accrued interest previously outstanding under the bridge financing agreement.

On April 13, 2004, the Board of Directors agreed to an extension of the notes payable to two of its officers to July 1, 2005, under the same terms as the original notes.

NOTE 5 – ASSET RETIREMENT OBLIGATION

The asset retirement obligation is adjusted each quarter for any liabilities incurred or settled during the period, accretion expense and any revisions made to the estimated cash flows. The reconciliation of the asset retirement obligation for the three months ended March 31, 2004 is as follows:

Balance, January 1, 2004		$ 607,200
Liabililities incurred		32,447
Accretion expense		25,065
Balance, March 31, 2004		$ 664,712

NOTE 6 - STOCKHOLDERS’ EQUITY

Warrants exercised – During the three months ended June 30, 2004, the Company issued 25,000 shares of common stock from the exercise of warrants. Of the 25,000 warrants, 5,000 had an exercise price of $1.75 per share and 20,000 had an exercise price of $5.00 per share; therefore, the Company received $108,750 from the exercise.

NOTE 7 – CONTINGENCIES AND COMMITMENTS

Standby Letters of Credit – A commercial bank has issued standby letters of credit on behalf of the Company to the states of Texas, Oklahoma and New Mexico totaling $299,029 to allow the Company to do business in those states. The standby letters of credit are valid through May 2005 and are collateralized by the revolving credit facility with the bank. The Company intends to renew the standby letters of credit for as long as the Company does business in those states. No amounts have been drawn under the standby letters of credit.

NOTE 8 - SUBSEQUENT EVENTS

Subsequent to June 30, 2004, the Company paid $2,001,994 in settlement of the principal and accrued interest previously outstanding under the bridge financing arrangement as described in Note 3.

Subsequent to June 30, 2004, the Company closed its secondary offering of 1,450,000 Units, each Unit consisting of one share of common stock and one common stock purchase warrant. The Unit is not separable into its components of common stock and common stock purchase warrant until the earlier of August 10, 2005 or upon thirty (30) prior written notice from Arena, but not before 60 days following the offering. The warrant has an exercise price of $7.32 and expires August 9, 2008. Proceeds before offering costs totaled $8,137,400. Net proceeds after closing costs will be allocated to the common stock and warrants on a prorata basis, based on their fair values.

Item 2. Management’s Discussion and Analysis of Financial Condition and Results of Operations

Results of Operations – For the Three Months Ended June 30, 2004

Oil and natural gas sales. For the three months ended June 30, 2004, oil and natural gas sales revenue increased $950,795 to $1,792,414, compared to $841,619 for the same period during 2003. Of the $950,795 increase, $457,935 was attributable to the East Hobbs property. Oil sales increased $831,099 and natural gas sales increased $119,696. The increase in oil sales was the result of a sales volume increase of 6,356 barrels for the three months ended June 30, 2004 compared to the same period in 2003, of which 10,593 was attributable to the East Hobbs property, and a 30% increase in the average realized per barrel oil price from $27.71 for the three months ended June 30, 2003 to $36.02 for the three months ended June 30, 2004. The increase in natural gas sales was the result of a sales volume increase of 23,584 thousand cubic feet (MCF) for the three months ended June 30, 2004 compared to the same period in 2003, of which 13,702 was attributable to the East Hobbs property, and a 8% increase in the average realized natural gas price per MCF from $3.48 for the three months ended June 30, 2003 to $3.76 for the three months ended June 30, 2004.

Lease operating expenses. Our lease operating expenses increased from $281,546 or $9.07 per barrel of oil equivalent (BOE) for the three months ended June 30, 2003 to $403,531 or $8.42 per BOE for the three months ended June 30, 2004. The increase in total was due to properties acquired in 2003 and 2004, while the decrease per BOE was primarily a result of lower average operating costs on the East Hobbs property acquired in 2004.

Production taxes. Production taxes as a percentage of oil and natural gas sales were 7% during the three months ended June 30, 2003 and remained steady at 7% for the three months ended June 30, 2004. Production taxes vary from state to state. Therefore, these taxes are likely to vary in the future depending on the mix of production we generate from various states, as well as the possibility that any state may raise its production tax.

Depreciation, depletion and amortization. Our depreciation, depletion and amortization expense increased by $115,539 to $204,706 for the three months ended June 30, 2004, compared to the same period in 2003. The increase was a result of an increase in volume and in the average depreciation, depletion and amortization rate from $2.40 per BOE during the three months ended June 30, 2003 to $3.49 per BOE during the three months ended June 30, 2004. The increased depreciation, depletion and amortization rate was the result of a revision to our reserves and increased capitalized costs and development costs from the property acquired in 2004.

General and administrative expenses. General and administrative expenses increased by $43,120 to $163,571 for the three months ended June 30, 2004, compared to the same period in 2003. This increase was primarily related to increases in compensation expense associated with an increase in personnel required to administer our growth and acquisition of a new accounting software system.

Interest expense (net of interest income). Interest expense increased $49,024 to $58,997 for the three months ended June 30, 2004 when compared to the same period in 2003. The increase was due to an increase in outstanding debt with the use of our credit facility in our latest acquisition.

Income tax expense. Our effective tax rate was 37% during the three months ended June 30, 2003 and remained steady at 37% for the three months ended June 30, 2004.

Net income. Net income increased from $192,552 for the three months ended June 30, 2003 to $548,548 for 2004. The primary reasons for this increase include higher crude oil prices between periods and an increase in volumes sold, partially offset by higher lease operating expense, income tax expense and general and administrative expenses due to our growth.

Results of Operations – For the Six Months Ended June 30, 2004

Oil and natural gas sales. For the six months ended June 30, 2004, oil and natural gas sales revenue increased $1,344,174 to $2,992,814, compared to $1,648,640 for the same period during 2003. Of the $950,795 increase, $457,935 was attributable to the East Hobbs property. Oil sales increased $1,199,218 and natural gas sales increased $144,956. The increase in oil sales was the result of a sales volume increase of 26,549 barrels for the six months ended June 30, 2004 compared to the same period in 2003,of which 10,593 was attributable to the East Hobbs property, and a 18% increase in the average realized per barrel oil price from $29.67 for the six months ended June 30, 2003 to $34.92 for the six months ended June 30, 2004. The increase in natural gas sales was the result of a sales volume increase of 32,735 thousand cubic feet (MCF) for the six months ended June 30, 2004 compared to the same period in 2003, of which 13,702 was attributable to the East Hobbs property, and a 6% increase in the average realized natural gas price per MCF from $3.98 for the six months ended June 30, 2003 to $4.22 for the six months ended June 30, 2004.

Lease operating expenses. Our lease operating expenses increased from $523,618 or $9.27 per barrel of oil equivalent (BOE) for the six months ended June 30, 2003 to $719,820 or $8.59 per BOE for the six months ended June 30, 2004. The increase in total was due to properties acquired in 2003 and 2004, while the decrease per BOE was primarily a result of lower average operating costs on the East Hobbs property acquired in 2004.

Production taxes. Production taxes as a percentage of oil and natural gas sales were 7% during the six months ended June 30, 2003 and remained steady at 7% for the three months ended June 30, 2004. Production taxes vary from state to state. Therefore, these taxes are likely to vary in the future depending on the mix of production we generate from various states, as well as the possibility that any state may raise its production tax.

Depreciation, depletion and amortization. Our depreciation, depletion and amortization expense increased by $182,455 to $315,826 for the six months ended June 30, 2004, compared to the same period in 2003. The increase was a result of an increase in volume and in the average depreciation, depletion and amortization rate from $2.40 per BOE during the six months ended June 30, 2003 to $3.49 per BOE during the six months ended June 30, 2004. The increased depreciation, depletion and amortization rate was the result of a revision to our reserves and increased capitalized costs and development costs from the property acquired in 2004.

General and administrative expenses. General and administrative expenses increased by $77,689 to $341,771 for the six months ended June 30, 2004, compared to the same period in 2003. This increase was primarily related to increases in compensation expense associated with an increase in personnel required to administer our growth, payment for Lee Keeling and Associates for preparation of our year ended December 31, 2003 and acquisition of a new accounting software system.

Interest expense (net of interest income). Interest expense increased $48,275 to $68,111 for the six months ended June 30, 2004 when compared to the same period in 2003. The increase was due to an increase in outstanding debt with the use of our credit facility in our latest acquisition.

Income tax expense. Our effective tax rate was 37% during the six months ended June 30, 2003 and remained steady at 37% for the six months ended June 30, 2004.

Net income. Net income increased from $382,602 for the six months ended June 30, 2003 to $858,190 for 2004. The primary reasons for this increase include higher crude oil prices between periods and an increase in volumes sold, partially offset by higher lease operating expense, income tax expense and general and administrative expenses due to our growth.

Revenues Year to Date by Geographic section

Arena reports its net oil and gas revenues for the year to date as applicable to the following geographic sectors:

OIL

Net Production Volume

Net Revenue

Texas Leases

17,369 BBLS

$ 604,013

Oklahoma Leases

32,427 BBLS

$ 1,153,220

New Mexico Leases

28,651 BBLS

$ 981,402

GAS

Net Production Volume

Net Revenue

Texas Leases

7,250 MCF $ 22,248

Oklahoma Leases 22,446 MCF

$ 73,631

New Mexico Leases 30,421 MCF

$ 157,979

Significant Subsequent Events occurring after March 31, 2004:

Subsequent to June 30, 2004, the Company paid $2,001,994 in settlement of the principal and accrued interest previously outstanding under the bridge financing arrangement as described in Note 3.

Subsequent to June 30, 2004, the Company closed its secondary offering of 1,450,000 Units, each Unit consisting of one share of common stock and one common stock purchase warrant. The Unit is not separable into its components of common stock and common stock purchase warrant until the earlier of August 10, 2005 or upon thirty (30) prior written notice from Arena, but not before 60 days following the offering. Each warrant has an exercise price of $7.32 and expires August 9, 2008. Proceeds before offering costs totaled $8,137,400. Net proceeds after closing costs will be allocated to the common stock and warrants on a pro rata basis, based on their fair values.

Capital Resources and Liquidity

As shown in the financial statements for the six months ended June 30, 2004, the Company had cash on hand of $1,921,984, compared to $1,076,676 as of December 31, 2003. The Company had positive net cash flows from operations for the six months ended June 30, 2004 of $1,477,134, compared to $686,310 for the same period 2003. Other significant sources of cash inflow were the issuance of notes payable in conjunction with our credit facility for $1,000,000 and proceeds from warrants exercises of $130,500 in 2004 and a common stock private placement with net proceeds in 2003 of $1,135,165 and the collection of a common stock subscription receivable, in the amount of $157,500 in 2003. The most significant cash outflows during the six months ended June 30, 2004 and 2003 were capital expenditures of $1,550,090 in 2004 and 1,186,971 in 2003 and payment of offering costs for our equity offering of $204,701 in 2004 and payment of preferred stock dividends of $114,685 in 2003.

Management plans to continue to make acquisitions, using net cash flows from operations and possibly the above referenced credit facility and additional equity capital.

Disclosures About Market Risks

Like other natural resource producers, Arena faces certain unique market risks. The two most salient risk factors are the volatile prices of oil and gas and certain environmental concerns and obligations.

Oil and Gas Prices

Current competitive factors in the domestic oil and gas industry are unique. The actual price range of crude oil is largely established by major international producers. Pricing for natural gas is more regional. Because domestic demand for oil and gas exceeds supply, there is little risk that all current production will not be sold at relatively fixed prices. To this extent Arena does not see itself as directly competitive with other producers, nor is there any significant risk that the company could not sell all production at current prices with a reasonable profit margin. The risk of domestic overproduction at current prices is not deemed significant. The primary competitive risks would come from falling international prices which could render current production uneconomical.

Secondarily, Arena is presently committed to use the services of the existing gatherers in its present areas of production. This gives to such gatherers certain short term relative monopolistic powers to set gathering and transportation costs, because obtaining the services of an alternative gathering company would require substantial additional costs since an alternative gatherer would be required to lay new pipeline and/or obtain new rights-of-way in the lease.

It is also significant that more favorable prices can usually be negotiated for larger quantities of oil and/or gas product, such that Arena views itself as having a price disadvantage to larger producers. Large producers also have a competitive advantage to the extent they can devote substantially more resources to acquiring prime leases and resources to better find and develop prospects.

Environmental

Oil and gas production is a highly regulated activity which is subject to significant environmental and conservation regulations both on a federal and state level. Historically, most of the environmental regulation of oil and gas production has been left to state regulatory boards or agencies in those jurisdictions where there is significant gas and oil production, with limited direct regulation by such federal agencies as the Environmental Protection Agency. However, while the Company believes this generally to be the case for its production activities in Texas, Oklahoma, Kansas and New Mexico, it should be noticed that there are various Environmental Protection Agency regulations which would govern significant spills, blow-outs, or uncontrolled emissions.

In Oklahoma, Texas, Kansas and New Mexico specific oil and gas regulations exist related to the drilling, completion and operations of wells, as well as disposal of waste oil. There are also procedures incident to the plugging and abandonment of dry holes or other non-operational wells, all as governed by the Oklahoma Corporation Commission, Oil and Gas Division, the Texas Railroad Commission, Oil and Gas Division, the Kansas Corporation Commission, Oil and Gas Division or the New Mexico Oil Conservation Division.

Compliance with these regulations may constitute a significant cost and effort for Arena. No specific accounting for environmental compliance has been maintained or projected by Arena to date. Arena does not presently know of any environmental demands, claims, or adverse actions, litigation or administrative proceedings in which it or the acquired properties are involved or subject to or arising out of its predecessor operations.

In the event of a breach of environmental regulations, these environmental regulatory agencies have a broad range of alternative or cumulative remedies to include: ordering a clean up of any spills or waste material and restoration of the soil or water to conditions existing prior to the environmental violation; fines; or enjoining further drilling, completion or production activities. In certain egregious situations the agencies may also pursue criminal remedies against the Company or its principals.

Forward-Looking Information

Certain statements in this Section and elsewhere in this report are forward-looking in nature and relate to trends and events that may affect the Company’s future financial position and operating results. Such statements are made pursuant to the safe harbor provision of the Private Securities Litigation Reform Act of 1995. The terms “expect,” ”anticipate,” ”intend,” and “project” and similar words or expressions are intended to identify forward-looking statements. These statements speak only as of the date of this report. The statements are based on current expectations, are inherently uncertain, are subject to risks, and should be viewed with caution. Actual results and experience may differ materially from the forward-looking statements as a result of many factors, including changes in economic conditions in the markets served by the company, increasing competition, fluctuations in raw materials and energy prices, and other unanticipated events and conditions. It is not possible to foresee or identify all such factors. The company makes no commitment to update any forward-looking statement or to disclose any facts, events, or circumstances after the date hereof that may affect the accuracy of any forward-looking statement.

Item 3. Controls and Procedures

(a)

The Company maintains controls and procedures designed to ensure that information required to be disclosed in the reports that the Company files or submits under the Securities Exchange Act of 1934 is recorded, processed, summarized and reported within the time periods specified in the rules and forms of the Securities and Exchange Commission. Specifically, the Company maintains an independent audit committee to monitor internal controls and procedures. Based upon their evaluation of those controls and procedures performed within 90 days of the filing date of this report, the chief executive officer and the principal financial officer of the Company concluded that the Company’s disclosure controls and procedures were adequate. The Company is not aware of any fraud or any material irregularities from its accounting or auditing procedures.

(b)

Changes in internal controls. The Company made no significant changes in its internal controls or in other factors that could significantly affect these controls subsequent to the date of the evaluation of those controls by the chief executive officer and principal financial officer.

Part II - Other Information

Item 1. Legal Proceedings

None.

Item 2. Changes in Securities and Small Business Issuers Purchases of Equity Securities

During the three months ended June 30, 2004, warrants holders exercised 5,000 warrants that had an exercise price of $1.75 per share and 20,000 warrants that had an exercise of price of $5.00 per share, resulting in an issuance of 25,000 shares of common stock being issued, for total consideration of $108,750. The shares were issued in transactions not involving a public offering in reliance upon the exemption from registration provided by Section 4(2) of the Securities Act of 1933. The persons to whom the shares were issued in exchange for the warrants had access to full information concerning the Company and represented that they acquired the shares for their own account and not for the purpose of distribution. The certificates for the shares contain a restricted legend advising that the shares may not be offered for sale, sold or otherwise transferred without having first been registered under the 1933 Act or pursuant to an exemption from registration under the 1933 Act. There was no underwriter involved in these transactions.

Item 3. Defaults Upon Senior Securities

None.

Item 4. Submission of Matters to a Vote of Security Holders

None.

Item 5. Other Information

None.

Item 6. Exhibits and Reports on Form 8-K

(a)

Exhibit 31.1

Section 302 Certification of CEO

Exhibit 31.2

Section 302 Certification of CFO

(b)

Exhibit 32.1

Section 1350 Certification of CEO

Exhibit 32.2

Section 1350 Certification of CFO

(c)

The Company filed a Form 8-K on May 18, 2004 reporting the acquisition of the East Hobbs property. The Form 8-K included a pro forma balance sheet as of March 31, 2004 as if the East Hobbs property acquisition and related financing had occurred on March 31, 2004 and the pro forma statements of operations for the three months ended March 31, 2004 and December 31, 2003, as though the East Hobbs property acquisition and the related financing had occurred at the beginning of each of those periods.

On May 27, 2004 the Company filed Amendment No. 1 to the Form 8-K to defer inclusion of the results of operations attributable to this acquisition until the actual date of acquisition (May 7, 2004), rather than the “effective” date of acquisition (March 1, 2004).

SIGNATURES

Pursuant to the requirements of the Securities Exchange Act of 1934, Registrant has duly caused this report to be signed on its behalf by the undersigned thereunto duly authorized.

REGISTRANT: ARENA RESOURCES, INC.

Dated: August 13, 2004

By: /s/ Lloyd Tim Rochford

Lloyd Tim Rochford

President, Chief Executive Officer

Dated: August 13, 2004

By: /s Stanley McCabe

Stanley McCabe

Treasurer, Secretary

Dated: August 13, 2004

By: /s/ William R. Broaddrick

William R. Broaddrick

Vice President, Chief Financial Officer