Helmerich & Payne 10K/A 2004 Annual report (amended)

UNITED STATES SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

FORM 10-K/A

Amendment No. 1

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

FOR THE FISCAL YEAR ENDED SEPTEMBER 30, 2004 OR

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

FOR THE TRANSITION PERIOD FROM TO

COMMISSION FILE NUMBER 1-4221

HELMERICH & PAYNE, INC.

(Exact name of registrant as specified in its charter)


DELAWARE		73-0679879
(State or other jurisdiction of		(I.R.S. employer
incorporation or organization)		identification no.)

1437 S. BOULDER AVE., SUITE 1400, TULSA, OKLAHOMA 74119


(Address of principal executive offices)		(Zip code)

Registrant’s telephone number, including area code (918) 742-5531

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


TITLE OF EACH CLASS		NAME OF EXCHANGE ON WHICH REGISTERED

Common Stock ($0.10 par value)		New York Stock Exchange

Common Stock Purchase Rights		New York Stock Exchange

Securities registered Pursuant to Section 12(g) of the Act: NONE

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 if disclosure of delinquent filers pursuant to Item 405 of Regulation S-K is not contained herein, and will not be contained, to the best of the Registrant’s knowledge, in definitive proxy or information statements incorporated by reference in Part III of this Form 10-K or any amendment to this Form 10-K. [ ]

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

At March 31, 2004, the aggregate market value of the voting stock held by non-affiliates was $1,378,913,985.

Number of shares of common stock outstanding at December 3, 2004: 50,610,987.

DOCUMENTS INCORPORATED BY REFERENCE

Certain portions of the following documents have been incorporated by reference into this Form 10-K as indicated:


Documents		10-K Parts
(1) Annual Report to Stockholders for the fiscal year ended September 30, 2004		Parts I and II

(2) Proxy Statement for Annual Meeting of Stockholders to be held March 2, 2005		Part III

TABLE OF CONTENTS


PART I
	ITEM 1. BUSINESS
	ITEM 2. PROPERTIES
	ITEM 3. LEGAL PROCEEDINGS
	ITEM 4. SUBMISSION OF MATTERS TO A VOTE OF SECURITY HOLDERS
PART II
	ITEM 5. MARKET FOR THE COMPANY’S COMMON STOCK AND RELATED STOCK HOLDER MATTERS
	ITEM 6. SELECTED FINANCIAL DATA
	ITEM 7. MANAGEMENT’S DISCUSSION & ANALYSIS OF RESULTS OF OPERATIONS AND FINANCIAL CONDITION
	ITEM 7A. QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK
	ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA
	ITEM 9. CHANGES IN AND DISAGREEMENTS WITH ACCOUNTANTS ON ACCOUNTING AND FINANCIAL DISCLOSURE
	ITEM 9A. CONTROLS AND PROCEDURES
	ITEM 9B. OTHER INFORMATION
PART III
	ITEM 10. DIRECTORS AND EXECUTIVE OFFICERS OF THE COMPANY
	ITEM 11. EXECUTIVE COMPENSATION
	ITEM 12. SECURITY OWNERSHIP OF CERTAIN BENEFICIAL OWNERS AND MANAGEMENT AND RELATED STOCKHOLDER MATTERS
	ITEM 13. CERTAIN RELATIONSHIPS AND RELATED TRANSACTIONS
	ITEM 14. PRINCIPAL ACCOUNTANT FEES AND SERVICES
PART IV
	ITEM 15. EXHIBITS, FINANCIAL STATEMENT SCHEDULES, AND REPORTS ON FORM 8-K
SIGNATURES
Annual Report to Shareholders for Fiscal 2004
Consent of Independent Auditors
Certification of CEO Pursuant to Section 302
Certification of CFO Pursuant to Section 302
Certification of CEO and CFO Pursuant to Section 906

This Amendment No. 1 to the Annual Report of Helmerich & Payne, Inc. on Form 10-K for the fiscal year ended September 30, 2004 is being filed solely for the following purposes:

	1.	To restate the sentence on pages 3 and 4 of Item 1 of Part I, under the caption “INTERNATIONAL DRILLING” and sub-caption “Venezuela”, that reads “Revenues generated from all Venezuelan drilling operations contributed approximately 37 percent of the Company’s consolidated revenues during 2004, compared with 29 percent of consolidated revenues during fiscal 2003 and 34 percent of consolidated revenues during 2002.”, as follows: “Revenues generated from all Venezuelan drilling operations contributed approximately nine percent of the Company’s consolidated revenues during 2004, compared with six percent of consolidated revenues during fiscal 2003 and nine percent of consolidated revenues during 2002.”

	2.	To delete the bottom two rows and the footnote from the table with the caption “INTEREST RATE RISK” on page 37 of the Annual Report filed as Exhibit 13 to the Form 10-K, which table incorrectly reflected the existence of variable rate debt.

	3.	To amend the header in the table in Note 1 to the Consolidated Financial Statements, under the caption “INVESTMENTS”, which summarized certain financial information of Atwood Oceanics, Inc. The column headers have been restated as September 30, 2004, 2003 and 2002 in place of the previous incorrect header of September 30, 2003, 2002 and 2001.

	4.	In addition, also filed herewith are the following exhibits:

	13	The Company’s Annual Report to Shareholders for fiscal 2004 (to reflect the amendments described above).

	23.1	Consent of Independent Auditors.

	31.1	Certification of Chief Executive Officer, as adopted pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.

	31.2	Certification of Chief Financial Officer, as adopted pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.

	32	Certification of Chief Executive Officer and Chief Financial Officer pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002.

The information contained in Helmerich & Payne, Inc.’s Form 10-K for the fiscal year ended September 30, 2004 as originally filed with the Securities and Exchange Commission is not otherwise updated or amended by this Amendment No. 1 and this Amendment No. 1 does not reflect events occurring after the filing of the Company’s original Form 10-K for fiscal 2004.

DISCLOSURE REGARDING FORWARD — LOOKING STATEMENTS

THIS REPORT INCLUDES “FORWARD-LOOKING STATEMENTS” WITHIN THE MEANING OF THE SECURITIES ACT OF 1933, AS AMENDED, AND THE SECURITIES EXCHANGE ACT OF 1934, AS AMENDED. ALL STATEMENTS OTHER THAN STATEMENTS OF HISTORICAL FACTS INCLUDED IN THIS REPORT, INCLUDING, WITHOUT LIMITATION, STATEMENTS REGARDING THE REGISTRANT’S FUTURE FINANCIAL POSITION, BUSINESS STRATEGY, BUDGETS, PROJECTED COSTS AND PLANS AND OBJECTIVES OF MANAGEMENT FOR FUTURE OPERATIONS, ARE FORWARD-LOOKING STATEMENTS. IN ADDITION, FORWARD-LOOKING STATEMENTS GENERALLY CAN BE IDENTIFIED BY THE USE OF FORWARD-LOOKING TERMINOLOGY SUCH AS “MAY”, “WILL”, “EXPECT”, “INTEND”, “ESTIMATE”, “ANTICIPATE”, “BELIEVE”, OR “CONTINUE” OR THE NEGATIVE THEREOF OR SIMILAR TERMINOLOGY. ALTHOUGH THE REGISTRANT BELIEVES THAT THE EXPECTATIONS REFLECTED IN SUCH FORWARD-LOOKING STATEMENTS ARE REASONABLE, IT CAN GIVE NO ASSURANCE THAT SUCH EXPECTATIONS WILL PROVE TO BE CORRECT. IMPORTANT FACTORS THAT COULD CAUSE ACTUAL RESULTS TO DIFFER MATERIALLY FROM THE REGISTRANT’S EXPECTATIONS ARE DISCLOSED IN THIS REPORT UNDER THE CAPTION “RISK FACTORS” BEGINNING ON PAGE 6, AS WELL AS IN MANAGEMENT’S DISCUSSION & ANALYSIS OF RESULTS OF OPERATIONS AND FINANCIAL CONDITION ON PAGES 10 THROUGH 38 OF THE COMPANY’S ANNUAL REPORT. ALL SUBSEQUENT WRITTEN AND ORAL FORWARD-LOOKING STATEMENTS ATTRIBUTABLE TO THE REGISTRANT, OR PERSONS ACTING ON ITS BEHALF, ARE EXPRESSLY QUALIFIED IN THEIR ENTIRETY BY SUCH CAUTIONARY STATEMENTS. THE REGISTRANT ASSUMES NO DUTY TO UPDATE OR REVISE ITS FORWARD-LOOKING STATEMENTS BASED ON CHANGES IN INTERNAL ESTIMATES OR EXPECTATIONS OR OTHERWISE.

PART I

ITEM 1. BUSINESS

Helmerich & Payne, Inc. (the “Company”), was incorporated under the laws of the State of Delaware on February 3, 1940, and is successor to a business originally organized in 1920. The Company is primarily engaged in contract drilling of oil and gas wells for others. The contract drilling business accounts for almost all of the Company’s operating revenues. The Company is also engaged in the ownership, development, and operation of commercial real estate.

The Company is organized into two separate operating entities, contract drilling and real estate. Both businesses operate independently of the other through wholly owned subsidiaries. Operating decentralization is balanced by a centralized finance division, which handles all accounting, information technology, budgeting, insurance, cash management, and related activities.

The Company’s contract drilling business is composed of three business segments: U.S. land drilling, U.S. offshore platform drilling and international drilling. The Company’s U.S. land drilling is conducted primarily in Oklahoma, Texas, Wyoming, Colorado, and Louisiana, and offshore from platforms in the Gulf of Mexico and California. The Company also operated in eight international locations during fiscal 2004: Venezuela, Ecuador, Colombia, Argentina, Bolivia, Equatorial Guinea, Chad, and Hungary. In addition, the Company is providing drilling consulting services for one customer in Russia.

The Company’s real estate investments are located in Tulsa, Oklahoma, where the Company maintains its executive offices.

Prior to October 1, 2002, the Company was engaged in the exploration, production and sale of crude oil and natural gas business (“exploration and production business”). During fiscal 2002, the Company transferred the assets and liabilities of its exploration and production business to its wholly owned subsidiary, Cimarex Energy Co. On September 30, 2002, the Company distributed the common stock of Cimarex Energy Co. to the Company’s stockholders and completed a merger of Key Production Company, Inc. with a subsidiary of Cimarex Energy Co. As a result of this transaction, Cimarex Energy Co. became a separate publicly-traded company that owned and operated the exploration and production business. The Company does not own any common stock of Cimarex Energy Co.

During fiscal 2004, the Company incorporated in Vermont a wholly-owned captive insurance subsidiary. The Company believes that the use of this captive will reduce its insurance costs.

CONTRACT DRILLING

The Company believes that it is one of the major land and offshore platform drilling contractors in the western hemisphere. Operating principally in North and South America, the Company specializes in medium to deep drilling in major gas producing basins of the United States and in drilling for oil and gas in international locations. In the United States, the Company draws its customers primarily from the major oil companies and the larger independents. In South America, the Company’s current customers include the Venezuelan state petroleum company and major international oil companies.

In fiscal 2004, the Company received approximately 56 percent of its consolidated revenues from the Company’s ten largest contract drilling customers. BP plc, ExxonMobil Corporation, and Shell Oil Company (respectively, “BP”, “ExxonMobil” and “Shell”), including their affiliates, are the Company’s three largest contract drilling customers. The Company performs drilling services for BP, ExxonMobil, and Shell on a world-wide basis. Revenues from drilling services performed for BP, ExxonMobil and Shell in fiscal 2004 accounted for approximately 10.8 percent, 10.7 percent and 8.4 percent, respectively, of the Company’s consolidated revenues for the same period.

The Company provides drilling rigs, equipment, personnel, and camps on a contract basis. These services are provided so that the Company’s customers may explore for and develop oil and gas from onshore areas and from fixed

platforms, tension-leg platforms and spars in offshore areas. Each of the drilling rigs consists of engines, drawworks, a mast, pumps, blowout preventers, a drillstring, and related equipment. The intended well depth and the drilling site conditions are the principal factors that determine the size and type of rig most suitable for a particular drilling job. A land drilling rig may be moved from location to location without modification to the rig. A helicopter rig is one that can be disassembled into component part loads of approximately 4,000-20,000 pounds and transported to remote locations by helicopter, cargo plane, or other means. A platform rig is specifically designed to perform drilling operations upon a particular platform. While a platform rig may be moved from its original platform, significant expense is incurred to modify a platform rig for operation on each subsequent platform. In addition to traditional platform rigs, the Company operates self-moving minimum-space platform drilling rigs and drilling rigs to be used on tension-leg platforms and spars. The minimum-space rig is designed to be moved without the use of expensive derrick barges. The tension-leg platforms and spars allow drilling operations to be conducted in much deeper water than traditional fixed platforms.

During fiscal 1998, the Company put to work a new generation of six highly mobile/depth flexible land drilling rigs (individually the “FlexRig^®”). The FlexRig has been able to significantly reduce average rig move times compared to similar depth-rated traditional land rigs. In addition, the FlexRig allows a greater depth flexibility of between 8,000 to 18,000 feet and provides greater operating efficiency. The original six rigs were designated as FlexRig1 rigs. Subsequently, the Company built and completed 12 new FlexRig2 rigs. During fiscal 2001, the Company announced that it would build an additional 25 new FlexRigs. These new rigs, known as “FlexRig3”, were the next generation of FlexRigs which incorporated new drilling technology and new environmental and safety design. This new design included integrated top drive, AC electric drive, hydraulic BOP handling system, hydraulic tubular make-up and break-out system, split crown and traveling blocks and an enlarged drill floor that enables simultaneous crew activities. All 25 of these FlexRig3s were completed by June of 2003. Subsequently, the Company constructed seven more FlexRig3s at an approximate cost of $11,250,000 each. Construction of these rigs was completed by March of 2004. All FlexRigs are available for work in the Company’s U.S. and international drilling operations.

The Company’s drilling contracts are obtained through competitive bidding or as a result of negotiations with customers, and sometimes cover multi-well and multi-year projects. Each drilling rig operates under a separate drilling contract. During fiscal 2004, all drilling services were performed on a “daywork” contract basis, under which the Company charges a fixed rate per day, with the price determined by the location, depth, and complexity of the well to be drilled, operating conditions, the duration of the contract, and the competitive forces of the market. The Company has previously performed contracts on a combination “footage” and “daywork” basis, under which the Company charged a fixed rate per foot of hole drilled to a stated depth, usually no deeper than 15,000 feet, and a fixed rate per day for the remainder of the hole. Contracts performed on a “footage” basis involve a greater element of risk to the contractor than do contracts performed on a “daywork” basis. Also, the Company has previously accepted “turnkey” contracts under which the Company charges a fixed sum to deliver a hole to a stated depth and agrees to furnish services such as testing, coring, and casing the hole which are not normally done on a “footage” basis. “Turnkey” contracts entail varying degrees of risk greater than the usual “footage” contract. The Company did not accept any “footage” or “turnkey” contracts during fiscal 2004. The Company believes that under current market conditions “footage” and “turnkey” contract rates do not adequately compensate contractors for the added risks. The duration of the Company’s drilling contracts are “well-to-well” or for a fixed term. “Well-to-well” contracts are cancelable at the option of either party upon the completion of drilling at any one site. Fixed-term contracts customarily provide for termination at the election of the customer, with an “early termination payment” to be paid to the contractor if a contract is terminated prior to the expiration of the fixed term.

While the duration for current fixed-term contracts are for six month to three year periods, some fixed-term and well-to-well contracts are expected to be continued for longer periods than the original terms. However, the contracting parties have no legal obligation to extend the contracts. Contracts generally contain renewal or extension provisions exercisable at the option of the customer at prices mutually agreeable to the Company and the customer. In most instances contracts provide for additional payments for mobilization and demobilization.

U.S. LAND DRILLING

At the end of September, 2004 and 2003, the Company had 87 and 83, respectively, of its land rigs available for work in the United States. The total number of rigs owned at the end of the period increased by a net of four rigs, resulting from five additional FlexRigs being completed during the year and removing from service one older conventional rig. The Company’s U.S. land operations contributed approximately 56 percent of the Company’s consolidated revenues during fiscal 2004, compared with 53 percent of consolidated revenues during fiscal 2003 and 42 percent of consolidated revenues during fiscal 2002. Rig utilization in fiscal 2004 was 87 percent, up from 81 percent in fiscal 2003. The Company’s fleet of FlexRigs and highly mobile rigs maintained an average utilization of approximately 97 percent during fiscal 2004 while the Company’s conventional rigs had an average utilization rate of approximately 67 percent. At the close of fiscal 2004, 80 land rigs were working out of 87 available rigs.

In November of 2004, the Company sold two conventional 2,000 horsepower U.S. land rigs for a total of $23.9 million.

U.S. OFFSHORE PLATFORM DRLLING

The Company’s offshore platform operations contributed approximately 14 percent of the Company’s consolidated revenues during fiscal 2004, compared with 22 percent of consolidated revenues during fiscal 2003 and 24 percent of consolidated revenues during fiscal 2002. Rig utilization in fiscal 2004 was 48 percent, down from 51 percent in fiscal 2003. At the end of this fiscal year, the Company had six of its 11 offshore platform rigs under contract and it continued to work under management contracts for three customer-owned rigs. Revenues from drilling services performed for the Company’s largest offshore platform drilling customer totaled approximately 61 percent of U.S. offshore platform revenues during fiscal 2004.

It is likely during the first six months of calendar 2005 that one additional platform rig will be stacked and one management contract will be terminated.

As a result of declining financial trends and unfavorable market conditions in the Gulf of Mexico, the Company completed an analysis of its offshore platform business in the Gulf of Mexico. Based on this analysis, the Company recorded a pre-tax asset impairment charge of $51.5 million in the fourth quarter of 2004.

INTERNATIONAL DRILLING

General

The Company’s international drilling operations began in 1958 with the acquisition of Sinclair Oil Company’s drilling rigs in Venezuela. Helmerich & Payne de Venezuela, C.A., a wholly owned subsidiary of the Company, is one of the leading drilling contractors in Venezuela. Beginning in 1972, with the introduction of its first helicopter rig, the Company expanded into other Latin American countries.

The Company’s international operations contributed approximately 24 percent of the Company’s consolidated revenues during fiscal 2004, compared with 21 percent of consolidated revenues during fiscal 2003 and 27 percent of consolidated revenues during fiscal 2002. Rig utilization in fiscal 2004 was 54 percent, up from 39 percent in fiscal 2003.

Venezuela

Venezuelan operations continue to be a significant part of the Company’s operations. During fiscal 2004, the Company moved two additional deep drilling rigs into the country, bringing the Company rig count to 13 land drilling rigs in Venezuela at the end of fiscal 2004. However, in early fiscal 2005, the Company moved a highly mobile rig to the United States, leaving the rig count at twelve. The Company worked primarily for the Venezuelan state petroleum company, PDVSA, during fiscal 2004, and revenues from this work accounted for approximately eight percent of the Company’s consolidated revenues during the fiscal year and 33 percent of international drilling revenues. Revenues

generated from all Venezuelan drilling operations contributed approximately nine percent of the Company’s consolidated revenues during 2004, compared with six percent of consolidated revenues during fiscal 2003 and nine percent of consolidated revenues during 2002. The Company had nine rigs working in Venezuela at the end of fiscal 2004.

The Company’s rig utilization rate in Venezuela has increased from approximately 33 percent during fiscal 2003 to approximately 65 percent in fiscal 2004. Even though the Company is, at this time, unable to predict future fluctuations in its utilization rates during fiscal 2005, the Company believes that the prospects are good for returning at least one of its idle rigs back to work in Venezuela during fiscal 2005.

Ecuador

At the end of fiscal 2004, the Company owned eight rigs in Ecuador. The Company’s utilization rate was approximately 74 percent during fiscal 2004, down from approximately 85 percent in fiscal 2003. Revenues generated by Ecuadorian drilling operations contributed approximately seven percent of the Company’s consolidated revenues during fiscal 2004, as compared with 10 percent of consolidated revenues during fiscal 2003 and nine percent of consolidated revenues during fiscal 2002. Revenues from drilling services performed for the Company’s largest customer in Ecuador totaled approximately 15 percent of international drilling revenues during fiscal 2004. The Ecuadorian drilling contracts are primarily with large international oil companies.

Colombia

During fiscal 2004, the Company moved one rig from Colombia to Venezuela, leaving two rigs in Colombia. The Company’s utilization rate in Colombia was approximately 13 percent during fiscal 2004, down from approximately 21 percent in fiscal 2003. The revenues generated by Colombian drilling operations contributed approximately one percent of the Company’s consolidated revenues in fiscal 2004, as compared with one percent of consolidated revenues during fiscal 2003 and two percent of consolidated revenues during fiscal 2002. At the end of fiscal 2004, the Company was operating one rig in Colombia, with a commitment for the second rig to begin work in early fiscal 2005.

Other Locations

In addition to its operations in Venezuela, Ecuador and Colombia, in fiscal 2004, the Company owned six rigs in Bolivia, one rig in Argentina, one rig in Hungary and one rig in Chad. At the end of fiscal 2004, two rigs were working in Bolivia, one in Argentina and one in Hungary. As of the end of November, 2004, one rig was working in Bolivia.

At the end of fiscal 2004 one rig was moved from Chad to the United States. During November of 2004, three rigs were moved from Bolivia to the United States.

During fiscal 2004, the Company continued operations under a management contract for a customer-owned platform rig located offshore Equatorial Guinea. Also, during the fiscal year, the Company commenced a drilling consulting services contract in Russia.

REAL ESTATE OPERATIONS

The Company’s real estate operations are conducted exclusively within the metropolitan area of Tulsa, Oklahoma. Its major holding is Utica Square Shopping Center, consisting of 15 separate buildings, with parking and other common facilities covering an area of approximately 30 acres. Utica Square contains approximately 441,588 usable square feet, composed of retail space of 379,018 usable square feet, office space of 38,785 usable square feet, storage space of 6,600 usable square feet and common area space of 17,185 usable square feet. The Company’s real estate operations occupy approximately 4,140 square feet of general office and storage space within the shopping center. Occupancy in the shopping center increased from 85 percent in fiscal 2003 to 91 percent in fiscal 2004 with the additions of an upscale salon and day spa, and a clothing store for teens and young adults.

At the end of the 2004 fiscal year, the Company owned 11 of a total of 73 units in The Yorktown, a 16-story luxury residential condominium with approximately 150,940 square feet of living area located on a six-acre tract adjacent to Utica Square Shopping Center. Six of the Company’s units are currently leased.

The Company owns and leases to third parties multi-tenant warehouse space. Three warehouses known as Space Center, each containing approximately 165,000 square feet of net leasable space, are situated in the southeast part of Tulsa at the intersection of two major limited-access highways. Present occupancy is 82 percent, which is down from 98 percent in fiscal 2003. Reduced occupancy is the result of the relocation of one tenant’s research facility to a university. The Company also owns approximately 1.5 acres of undeveloped land lying adjacent to such warehouses.

In August of 2004, the Company sold approximately 1.73 acres of undeveloped land in Southpark. The sales price totaled approximately $1 million. Southpark is located in a high growth area of southeast Tulsa and is suitable for mixed commercial and light industrial. Subsequent to such sale and at the end of fiscal 2004, the Company owned approximately 218 acres in Southpark consisting of approximately 205 acres of undeveloped real estate and approximately 13 acres of multi-tenant warehouse area. The warehouse area is known as Space Center East and consists of two warehouses, one containing approximately 90,000 square feet and the other containing approximately 112,500 square feet. Present occupancy decreased to 82 percent in 2004 from 93% in fiscal 2003 due to the loss of one tenant and a reduction of space by another. The Company believes that a high quality office park, with peripheral commercial, office/warehouse, and hotel sites, is the best development use for the remaining land. The Company has contracted with a professional engineering and planning firm to prepare a comprehensive master plan to aid in the possible future development of Southpark.

The Company owns a five-building complex called Tandem Business Park. The property is located adjacent to and east of the Space Center East facility and contains approximately six acres, with approximately 88,084 square feet of office/warehouse space. Occupancy has decreased from 84 percent to 69 percent during fiscal 2004 due to the departure of five small tenants. The Company also owns a 12-building complex, consisting of approximately 204,600 square feet of office/warehouse space, called Tulsa Business Park. The property is located south and east of the Space Center facility, separated by a city street, and contains approximately 12 acres. During fiscal 2004, occupancy has decreased from 86 percent to 81 percent.

The Company owns two service center properties located adjacent to arterial streets in south central Tulsa. The first, called Maxim Center, consists of one office/warehouse building containing approximately 40,800 square feet and is located on approximately 2.5 acres. During fiscal 2004, occupancy has remained at 94%. The second, called Maxim Place, consists of one office/warehouse building containing approximately 33,750 square feet and is located on approximately 2.25 acres. During fiscal 2004, occupancy has increased from 17 percent to 44 percent with the addition of two tenants. In addition, the Company has established an offsite disaster recovery center at this facility which occupies approximately 3,517 square feet.

The Company, during fiscal 2004, completed relocation within Tulsa of its executive offices. The razing of its former headquarters building will be completed in the first quarter of fiscal 2005. No development plans for the site are pending.

FINANCIAL

Information relating to revenues, total assets and operating profit or loss by business segments may be found on pages 64 through 66 of the Company’s Annual Report.

EMPLOYEES

The Company had 3,056 employees within the United States (six of which were part-time employees) and 1,195 employees in international operations as of September 30, 2004.

AVAILABLE INFORMATION

Information relating to the Company’s internet address and the Company’s SEC filings may be found on page 68 of the Company’s Annual Report.

RISK FACTORS

In addition to the risk factors discussed elsewhere in this report, the Company cautions that the following “Risk Factors” could affect its actual results in the future.

1. Competition

Competition in the Contract Drilling Business

The contract drilling business is highly competitive. Competition in contract drilling involves such factors as price, rig availability, efficiency, condition of equipment, reputation, operating safety, and customer relations. Competition is primarily on a regional basis and may vary significantly by region at any particular time. Land drilling rigs can be readily moved from one region to another in response to changes in levels of activity, and an oversupply of rigs in any region may result, leading to increased price competition.

Although many contracts for drilling services are awarded based solely on price, the Company has been successful in establishing long-term relationships with certain customers which have allowed the Company to secure drilling work even though the Company may not have been the lowest bidder for such work. The Company has continued to attempt to differentiate its services based upon its engineering design expertise, operational efficiency, and safety and environmental awareness. This strategy is less effective when lower demand for drilling services intensifies price competition and makes it more difficult or impossible to compete on any basis other than price. Also, future improvements in operational efficiency and safety by the Company’s competitors could negatively affect the Company’s ability to differentiate its services.

Competition in the Real Estate Business

The Company has numerous competitors in the multi-tenant leasing business. The size and financial capacity of these competitors range from one property sole proprietors to large international corporations. The primary competitive factors include price, location, and configuration of space. The Company’s competitive position is enhanced by the location of its properties, its financial capability and the long-term ownership of its properties. However, many competitors have financial resources greater than the Company and have more contemporary facilities. Also, current economic conditions have encouraged prospective tenants to construct owner-occupied buildings rather than lease third party space.

2. Operating Risks

The drilling operations of the Company are subject to the many hazards inherent in the business, including inclement weather, blowouts and well fires. These hazards could cause personal injury, suspend drilling operations, seriously damage or destroy the equipment involved, and cause substantial damage to producing formations and the surrounding areas. The Company’s offshore platform drilling operations are also subject to potentially greater environmental liability, adverse sea conditions and platform damage or destruction due to collision with aircraft or marine vessels.

3. Indemnification and Insurance Coverage

The Company has insurance coverage for comprehensive general liability, public liability, property damage, workers compensation, and employer’s liability. Generally, deductibles are $2 million per occurrence on claims that fall under these coverages, except that property damage deductibles on rig properties are generally $1 million per occurrence. Excess insurance is purchased over these coverages to limit the Company’s exposure to catastrophic claims. No insurance is carried against loss of earnings or business interruption. The Company is unable to obtain significant amounts of insurance

to cover risks of underground reservoir damage, however, the Company is generally indemnified under its drilling contracts from this risk. The majority of the Company’s insurance coverage has been purchased through fiscal 2005. No assurance can be given that all or a portion of the Company’s coverage will not be cancelled during fiscal 2005 or that insurance coverage will continue to be available at rates considered reasonable. Additionally, no assurance can be given that the Company’s insurance and indemnification arrangements will adequately protect it against all liabilities that could result from the hazards of its drilling operations. Incurring a liability for which the Company is not fully insured or indemnified could materially affect the Company’s results of operations.

4. Volatility of Oil and Gas Prices

The Company’s operations can be materially affected by low oil and gas prices. The Company believes that any significant reduction in oil and gas prices could depress the level of exploration and production activity and result in a corresponding decline in demand for the Company’s services. Worldwide military, political and economic events, including initiatives by the Organization of Petroleum Exporting Countries, may affect both the demand for, and the supply of, oil and gas. Fluctuations during the last few years in the demand and supply of oil and gas have contributed to, and are likely to continue to contribute to, price volatility. Any prolonged reduction in demand for the Company’s services could have a material and adverse effect on the Company.

5. International Uncertainties and Local Laws

International operations are subject to certain political, economic, and other uncertainties not encountered in U.S. operations, including increased risks of terrorism, kidnapping of employees, expropriation of equipment as well as expropriation of a particular oil company operator’s property and drilling rights, taxation policies, foreign exchange restrictions, currency rate fluctuations, and general hazards associated with foreign sovereignty over certain areas in which operations are conducted. There can be no assurance that there will not be changes in local laws, regulations, and administrative requirements or the interpretation thereof which could have a material adverse effect on the profitability of the Company’s operations or on the ability of the Company to continue operations in certain areas.

Because of the impact of local laws, the Company’s future operations in certain areas may be conducted through entities in which local citizens own interests and through entities (including joint ventures) in which the Company holds only a minority interest, or pursuant to arrangements under which the Company conducts operations under contract to local entities. While the Company believes that neither operating through such entities nor pursuant to such arrangements would have a material adverse effect on the Company’s operations or revenues, there can be no assurance that the Company will in all cases be able to structure or restructure its operations to conform to local law (or the administration thereof) on terms acceptable to the Company.

Although the Company attempts to minimize the potential impact of such risks by operating in more than one geographical area, during fiscal 2004, approximately 24 percent of the Company’s consolidated revenues were generated from the international contract drilling business. Approximately 78 percent of the international revenues were from operations in South America and approximately 85 percent of South American revenues were from Venezuela and Ecuador.

6. Currency Risk

General

Contracts for work in foreign countries generally provide for payment in United States dollars, except for amounts required to meet local expenses. However, government owned petroleum companies are more frequently requesting that a greater proportion of these payments be made in local currencies. Based upon current information, the Company believes that exposure to potential losses from currency devaluation is minimal in Colombia, Ecuador, Bolivia, and Equatorial Guinea. In those countries, all receivables and payments are currently in U.S. dollars. Cash balances are kept at a minimum which assists in reducing exposure.

Argentina

In 2002, Argentina suffered a 60% devaluation of the peso. As a consequence, the Company secured agreements with customers that limited the portion of the accounts receivable that was paid in pesos with the balance of such accounts receivable paid in U.S. dollars. The Company did not experience Argentine currency losses in fiscal 2004.

Venezuela

The Company is exposed to risks of currency devaluation in Venezuela primarily as a result of bolivar receivable balances and bolivar cash balances. In Venezuela, approximately 60% of the Company’s invoice billings are in U.S. dollars and 40% are in the local currency, the bolivar. The significance of this arrangement is that even though the dollar-based invoices may be paid in bolivars, the Company, historically, has usually been able to convert the bolivars into U.S. dollars in a timely manner and thus avoid, in large measure, devaluation losses pertaining to the dollar-based invoices. However, this arrangement is effective only in the absence of exchange controls. In January 2003, the Venezuelan government put into effect exchange controls that fixed the exchange rate and also prohibited the Company, as well as other companies, from converting the bolivar into U.S. dollars through the Central Bank.

As part of the exchange controls regulation, the Venezuelan government provided a mechanism by which companies could request conversion of bolivars into U.S. dollars. In compliance with such regulations, the Company in October of 2003, submitted a request to the Venezuelan government seeking permission to dividend earnings, which would convert 14 billion bolivars into U.S. dollars. In January 2004, the Venezuelan government approved the Company’s request to convert bolivar cash balances to U.S. dollars and allowed the remittance of $8.8 million U.S. dollars as dividends to the U.S. based parent. As a consequence, the Company’s exposure to currency devaluation was reduced by this amount.

As stated above, the Company is exposed to risks of currency devaluation in Venezuela primarily as a result of bolivar receivable balances and bolivar cash balances. As a result of the 20 percent devaluation of the bolivar during fiscal 2004, the Company experienced total devaluation losses of $1.9 million during that same period.

These devaluation losses may not be reflective of the actual potential for future devaluation losses because of the exchange controls that are currently in place. There have been recent press reports of a potential devaluation in calendar 2005. However, the amount and exact timing of such devaluation is uncertain. While the Company is unable to predict future devaluation in Venezuela, if fiscal 2005 activity levels are similar to fiscal 2004 and if a ten percent to twenty percent devaluation were to occur, the Company could experience potential currency devaluation losses ranging from approximately $1.2 million to $2.3 million.

In late August 2003, the Venezuelan state petroleum company agreed, on a prospective basis, to pay a portion of the Company’s dollar-based invoices in U.S. dollars. While this is a positive development in light of the existing exchange controls, there is no guarantee as to how long this arrangement will continue. Were this agreement to end, the Company would again receive these payments in bolivars and thus increase bolivar cash balances and exposure to devaluation.

7. Governmental Instability in Venezuela

Governmental instability continues to exist in Venezuela. In the event that extended labor strikes occur or turmoil increases, the Company could experience shortages in material and supplies necessary to operate some or all of its Venezuelan drilling rigs.

During the mid-1970s, the Venezuelan government nationalized the exploration and production business. At the present time it appears the Venezuelan government will not nationalize the contract drilling business. Any such nationalization could result in the Company’s loss of all or a portion of its assets and business in Venezuela.

8. Government Regulation and Environmental Risks

Many aspects of the Company’s operations are subject to government regulation, including those relating to drilling practices and methods and the level of taxation. In addition, the United States and various other countries have environmental

regulations which affect drilling operations. Drilling contractors may be liable for damages resulting from pollution. Under United States regulations, drilling contractors must establish financial responsibility to cover potential liability for pollution of offshore waters. Generally, the Company is indemnified under drilling contracts from liability arising from pollution, except in certain cases of surface pollution. However, the enforceability of indemnification provisions in foreign countries may be questionable.

The Company believes that it is in substantial compliance with all legislation and regulations affecting its operations in the drilling of oil and gas wells and in controlling the discharge of wastes. To date, compliance has not materially affected the capital expenditures, earnings, or competitive position of the Company, although these measures may add to the costs of drilling operations. Additional legislation or regulation may reasonably be anticipated, and the effect thereof on operations cannot be predicted.

9. Interest Rate Risk

In 2002, the Company entered into a $200 million intermediate-term unsecured debt obligation with staged maturities from five to 12 years with varying fixed interest rates for each maturity series. There was $200 million outstanding at September 30, 2004, of which $25 million is due in 2007 and the remaining $175 million is due 2009 through 2014. The average interest rate during the next four years on this debt is 6.3%, after which it increases to 6.4%. The fair value of this debt at September 30, 2004 was approximately $216.4 million.

At September 30, 2004, the Company had in place a committed unsecured line of credit totaling $50 million with no outstanding borrowings. The Company, as of September 30, 2004, had letters of credit totaling $13 million outstanding against such line of credit. The Company’s line of credit interest rate is based on LIBOR plus 87 to 112.5 basis points or prime minus 1.75 to 1.50 basis points based on the Company’s EBITDA to net debt ratio. As the Company draws on this line of credit, it is subject to the interest rates prevailing during the term at which the Company had outstanding borrowings. Although market interest rates were at historical lows during fiscal year 2004, interest rates could rise for various reasons in the future and increase the Company’s total interest expense, depending upon the amount borrowed against the credit line.

10. Equity Price Risk

At September 30, 2004, the Company owned stocks in other publicly held companies with a total market value of $240.7 million. These securities are subject to a wide variety of market-related risks that could substantially reduce or increase the market value of the Company’s holdings. Except for the Company’s holdings in Atwood Oceanics, Inc., the portfolio is recorded at fair value on its balance sheet with changes in unrealized after-tax value reflected in the equity section of its balance sheet. Any reduction in market value would have an impact on the Company’s debt ratio and financial strength. In October 2004, the Company sold 1,000,000 shares of its position in Atwood Oceanics, Inc. as part of a 2,175,000 share public offering by Atwood. The sale generated approximately $16.5 million ($0.32 per diluted share) of net income for the first quarter of fiscal 2005. The Company owns 2,000,000 shares of Atwood after the sale.

11. Reliance on Small Number of Customers

In fiscal 2004, the Company received approximately 56 percent of its consolidated revenues from the Company’s ten largest contract drilling customers and approximately 30 percent of its consolidated revenues from the Company’s three largest customers (including their affiliates). The Company believes that its relationship with all of these customers is good; however, the loss of one or more of its larger customers would have a material adverse effect on the Company’s results of operations.

12. Key Personnel

The Company utilizes highly skilled personnel in operating and supporting its businesses. In times of high utilization, it can be difficult to find qualified individuals. Although to date the Company’s operations have not been materially affected by competition for personnel, an inability to obtain a sufficient number of qualified personnel could materially impact the Company’s results of operations.

13. Changes in Technologies

Although the Company takes measures to ensure that it uses advanced oil and natural gas drilling technology, changes in technology or improvements in competitors’ equipment could make the Company’s equipment less competitive or require significant capital investments to keep its equipment competitive.

14. Concentration of Credit

The concentration of the Company’s customers in the energy industry could cause them to be similarly affected by changes in industry conditions and, as a result, could impact the Company’s exposure to credit risk. The Company cannot offer assurances that losses due to uncollectible receivables will be consistent with expectation.

ITEM 2. PROPERTIES

CONTRACT DRILLING

The following table sets forth certain information concerning the Company’s U.S. drilling rigs as of September 30, 2004:


						Drawworks:
Location	Rig		Optimum Depth		Rig Type	Horsepower
*FLEXRIGS*
Texas		164		18,000	SCR (FlexRig1)		1,500
Texas		165		18,000	SCR (FlexRig1)		1,500
Texas		166		18,000	SCR (FlexRig1)		1,500
Texas		169		18,000	SCR (FlexRig1)		1,500
Texas		178		18,000	SCR (FlexRig2)		1,500
Wyoming		179		18,000	SCR (FlexRig2)		1,500
Wyoming		180		18,000	SCR (FlexRig2)		1,500
Texas		181		18,000	SCR (FlexRig2)		1,500
Texas		182		18,000	SCR (FlexRig2)		1,500
Texas		183		18,000	SCR (FlexRig2)		1,500
Texas		184		18,000	SCR (FlexRig2)		1,500
Texas		185		18,000	SCR (FlexRig2)		1,500
Texas		186		18,000	SCR (FlexRig2)		1,500
Texas		187		18,000	SCR (FlexRig2)		1,500
Texas		188		18,000	SCR (FlexRig2)		1,500
Oklahoma		189		18,000	SCR (FlexRig2)		1,500
Texas		210		18,000	AC (FlexRig3)		1,500
Texas		211		18,000	AC (FlexRig3)		1,500
Texas		212		18,000	AC (FlexRig3)		1,500
Texas		213		18,000	AC (FlexRig3)		1,500
Texas		214		18,000	AC (FlexRig3)		1,500
Colorado		215		18,000	AC (FlexRig3)		1,500
Texas		216		18,000	AC (FlexRig3)		1,500
Texas		217		18,000	AC (FlexRig3)		1,500
Oklahoma		218		18,000	AC (FlexRig3)		1,500
Texas		219		18,000	AC (FlexRig3)		1,500
Texas		220		18,000	AC (FlexRig3)		1,500
Louisiana		221		18,000	AC (FlexRig3)		1,500
Oklahoma		222		18,000	AC (FlexRig3)		1,500


						Drawworks:
Location	Rig		Optimum Depth		Rig Type	Horsepower
Texas		223		18,000	AC (FlexRig3)		1,500
Texas		224		18,000	AC (FlexRig3)		1,500
Oklahoma		225		18,000	AC (FlexRig3)		1,500
Texas		226		18,000	AC (FlexRig3)		1,500
Texas		227		18,000	AC (FlexRig3)		1,500
Texas		228		18,000	AC (FlexRig3)		1,500
Texas		229		18,000	AC (FlexRig3)		1,500
Texas		230		18,000	AC (FlexRig3)		1,500
Texas		231		18,000	AC (FlexRig3)		1,500
Texas		232		18,000	AC (FlexRig3)		1,500
Texas		233		18,000	AC (FlexRig3)		1,500
Texas		234		18,000	AC (FlexRig3)		1,500
Texas		235		18,000	AC (FlexRig3)		1,500
Texas		236		18,000	AC (FlexRig3)		1,500
Texas		237		18,000	AC (FlexRig3)		1,500
Texas		238		18,000	AC (FlexRig3)		1,500
Colorado		239		18,000	AC (FlexRig3)		1,500
Texas		240		18,000	AC (FlexRig3)		1,500
Wyoming		241		18,000	AC (FlexRig3)		1,500
*HIGHLY MOBILE RIGS*
Oklahoma		158		10,000	SCR		900
Texas		156		12,000	Mechanical		1,200
Wyoming		159		12,000	Mechanical		1,200
Oklahoma		141		14,000	Mechanical		1,200
Texas		142		14,000	Mechanical		1,200
Oklahoma		143		14,000	Mechanical		1,200
Texas		145		14,000	Mechanical		1,200
Texas		155		14,000	SCR		1,200
Wyoming		146		16,000	SCR		1,200
Texas		147		16,000	SCR		1,200
Wyoming		154		16,000	SCR		1,500
*CONVENTIONAL RIGS*
Texas		110		12,000	SCR		700
Oklahoma		96		16,000	SCR		1,000
Texas		118		16,000	SCR		1,200
Oklahoma		119		16,000	SCR		1,200
Texas		120		16,000	SCR		1,200
Texas		162		18,000	SCR		1,500
Louisiana		79		20,000	SCR		2,000
Oklahoma		80		20,000	SCR		1,500
Texas		89		20,000	SCR		1,500
Oklahoma		92		20,000	SCR		1,500
Texas		94		20,000	SCR		1,500


						Drawworks:
Location	Rig		Optimum Depth		Rig Type	Horsepower
Oklahoma		98		20,000	SCR		1,500
Texas		122		16,000	SCR		1,700
Oklahoma		97		20,000	SCR		2,000
Texas		99		26,000	SCR		2,000
Texas		137		26,000	SCR		2,000
Texas		149		26,000	SCR		2,000
Texas		191		26,000	SCR		2,000
Texas		192		26,000	SCR		2,000
Texas		72		30,000	SCR		3,000
Texas		73		30,000	SCR		3,000
Texas		125		30,000	SCR		3,000
Texas		134		30,000	SCR		3,000
Louisiana		136		30,000	SCR		3,000
Texas		157		30,000	SCR		3,000
Louisiana		161		30,000	SCR		3,000
Louisiana		163		30,000	SCR		3,000
Texas		139		30,000+	SCR		3,000
*OFFSHORE PLATFORM RIGS*
Louisiana		91		20,000	Conventional		3,000
Louisiana		203		20,000	Self-Erecting		2,500
Gulf of Mexico		205		20,000	Tension-leg		2,000
Louisiana		206		20,000	Self-Erecting		1,500
Gulf of Mexico		100		30,000	Conventional		3,000
Louisiana		105		30,000	Conventional		3,000
Louisiana		106		30,000	Conventional		3,000
Louisiana		107		30,000	Conventional		3,000
Gulf of Mexico		201		30,000	Tension-leg		3,000
Gulf of Mexico		202		30,000	Tension-leg		3,000
Gulf of Mexico		204		30,000	Tension-leg		3,000

The following table sets forth information with respect to the utilization of the Company’s U.S. land drilling rigs for the periods indicated:


Years ended September 30,	2000			2001			2002			2003			2004
Number of rigs owned at end of period		38			49			66			83			87
Average rig utilization rate during period*		85	%		97	%		84	%		81	%		87	%

*A rig is considered to be utilized when it is operated or being moved, assembled, or dismantled under contract.

The following table sets forth certain information concerning the Company’s international drilling rigs as of September 30, 2004:


							Draw-Works:
Location	Rig		Optimum Depth			Rig Type	Horsepower
Argentina		177		30,000		SCR		3,000
Bolivia*		171		16,000		Mechanical		1,000
Bolivia*		172		16,000		Mechanical		1,000
Bolivia*		173		20,000		Mechanical		2,000
Bolivia		123		26,000		SCR		2,100
Bolivia		151		30,000	+	SCR		3,000
Bolivia		175		30,000		SCR		3,000
Chad		167		18,000		SCR (FlexRig1)		1,500
Colombia		133		30,000		SCR		3,000
Colombia		152		30,000	+	SCR		3,000
Ecuador		22		18,000		SCR (Heli Rig)		1,700
Ecuador		23		18,000		SCR (Heli Rig)		1,500
Ecuador		132		18,000		SCR		1,500
Ecuador		176		18,000		SCR		1,500
Ecuador		121		20,000		SCR		1,700
Ecuador		117		26,000		SCR		2,500
Ecuador		138		26,000		SCR		2,500
Ecuador		190		26,000		SCR		2,000
Hungary		168		18,000		SCR (FlexRig1)		1,500
Venezuela*		140		10,000		Mechanical		900
Venezuela		148		26,000		SCR		2,000
Venezuela		160		26,000		SCR		2,000
Venezuela		113		30,000		SCR		3,000
Venezuela		115		30,000		SCR		3,000
Venezuela		116		30,000		SCR		3,000
Venezuela		127		30,000		SCR		3,000
Venezuela		128		30,000		SCR		3,000
Venezuela		129		30,000		SCR		3,000
Venezuela		135		30,000		SCR		3,000
Venezuela		150		30,000		SCR		3,000
Venezuela		174		30,000		SCR		3,000
Venezuela		153		30,000	+	SCR		3,000

*Rig was returned to the United States during November of 2004.

The following table sets forth information with respect to the utilization of the Company’s international drilling rigs for the periods indicated:


Years ended September 30,	2000			2001			2002			2003			2004
Number of rigs owned at end of period		40			37			33			32			32
Average rig utilization rate during period*^†		47	%		56	%		51	%		39	%		54	%

* A rig is considered to be utilized when it is operated or being moved, assembled, or dismantled under contract.

^† Does not include rigs returned to United States for major modifications and upgrades.

REAL ESTATE OPERATIONS

See Item 1. BUSINESS, pages 4 through 5 of this Report.

STOCK PORTFOLIO

Information required by this item regarding the stock portfolio held by the Company may be found on page 31 of the Company’s Annual Report under the caption, “Management’s Discussion and Analysis of Results of Operations and Financial Condition.”

ITEM 3. LEGAL PROCEEDINGS

The Company is subject to various claims that arise in the ordinary course of its business. In the opinion of management, the amount of ultimate liability with respect to these actions will not materially affect the financial position, results of operations, or liquidity of the Company. The Company is not a party to, and none of its property is subject to, any material pending legal proceedings.

ITEM 4. SUBMISSION OF MATTERS TO A VOTE OF SECURITY HOLDERS

None.

EXECUTIVE OFFICERS OF THE COMPANY

The following table sets forth the names and ages of the Company’s executive officers, together with all positions and offices held with the Company by such executive officers. Officers are elected to serve until the meeting of the Board of Directors following the next Annual Meeting of Stockholders and until their successors have been elected and have qualified or until their earlier resignation or removal.

W. H. Helmerich, III, 81

Chairman of the Board
Director since 1949; Chairman of the Board
since 1960

Hans Helmerich, 46

President and Chief Executive Officer
Director since 1987; President and Chief Executive
Officer since 1989

George S. Dotson, 63

Vice President
Director since 1990; Vice President since 1977 and
President and Chief Operating Officer of Helmerich
& Payne International Drilling Co. since 1977

Douglas E. Fears, 55

Vice President and Chief Financial Officer
since 1988

Steven R. Mackey, 53

Vice President, Secretary and General Counsel
Secretary since 1990; Vice President and
General Counsel since 1988

PART II

ITEM 5. MARKET FOR THE COMPANY’S COMMON STOCK AND RELATED STOCK HOLDER MATTERS

The principal market on which the Company’s common stock is traded is the New York Stock Exchange under the symbol “HP”. The high and low sale prices per share for the common stock for each quarterly period during the past two fiscal years as reported in the NYSE-Composite Transaction quotations follow:


	2003				2004
Quarter	High		Low		High		Low
First	$	30.23	$	23.45	$	28.37	$	23.77
Second		28.94		22.60		30.61		27.02
Third		32.80		24.72		29.55		24.25
Fourth		30.30		25.70		29.07		24.01

The Registrant paid quarterly cash dividends during the past two years as shown in the following table:


	Paid per Share				Total Payment
	Fiscal				Fiscal
Quarter	2003		2004		2003		2004
First	$	0.080	$	0.080	$	4,000,982	$	4,011,879
Second		0.080		0.080		4,002,239		4,017,204
Third		0.080		0.080		4,002,971		4,032,709
Fourth		0.080		0.0825		4,009,076		4,160,221

The Company paid a cash dividend of $0.0825 per share on December 1, 2004, to shareholders of record on November 15, 2004. Payment of future dividends will depend on earnings and other factors.

As of December 3, 2004, there were 860 record holders of the Company’s common stock as listed by the transfer agent’s records.

SUMMARY OF ALL EXISTING EQUITY COMPENSATION PLANS

The following chart sets forth information concerning the equity compensation plans of the Company as of September 30, 2004.

Number of securities to

Weighted-average

Number of securities remaining

be issued upon exercise

exercise price of

available for future issuance under

of outstanding options,

outstanding options,

equity compensation plans (excluding

warrants and rights

securities reflected in column (a))

(a)

(b)

(c)

Plan Category:

Equity compensation plans approved by security holders⁽¹⁾

4,456,665

22.028

1,157,805

Equity compensation plans not approved by security holders⁽²⁾

—

Total

4,456,665

22.028

1,157,805

(1)

Includes the 1990 Stock Option Plan, the 1996 Stock Incentive Plan and the 2000 Stock Incentive Plan of the Company.

(2)

The Company does not maintain any equity compensation plans that have not been approved by the stockholders.

ITEM 6. SELECTED FINANCIAL DATA

The following table summarizes selected financial information and should be read in conjunction with the Consolidated Financial Statements and the Notes thereto and the related Management’s Discussion and Analysis of Results of Operations and Financial Condition contained at pages 10 through 38 of the Company’s Annual Report. On September 30, 2002, the Company spun off Cimarex Energy Co. The historical financial data for the business conducted by Cimarex Energy Co. for 2002 has been reported as discontinued operations which is not included in the five-year summary of selected financial data.

FIVE - YEAR SUMMARY OF SELECTED FINANCIAL DATA


	2000		2001		2002		2003		2004
			(in thousands except per share amounts)
Sales, operating, and other revenues	$	416,272	$	542,571	$	551,879	$	515,284	$	620,928
Asset Impairment Charge		—		—		—		—		51,516
Income from continuing operations		36,470		80,467		53,706		17,873		4,359
Income from continuing operations per common share:
Basic		0.74		1.61		1.08		0.36		0.09
Diluted		0.73		1.58		1.07		0.35		0.09
Total assets		1,200,854		1,300,121		1,227,313		1,417,770		1,406,844
Long-term debt		50,000		50,000		100,000		200,000		200,000
Cash dividends declared per common share		0.285		0.30		0.31		0.32		0.3225

ITEM 7. MANAGEMENT’S DISCUSSION & ANALYSIS OF RESULTS OF OPERATIONS AND FINANCIAL CONDITION

Information required by this item may be found on pages 10 through 38 of the Company’s Annual Report under the caption “Management’s Discussion & Analysis of Results of Operations and Financial Condition.”

ITEM 7A. QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK

Information required by this item may be found on the following pages of the Company’s Annual Report under Management’s Discussion & Analysis of Results of Operations and Financial Condition and in Notes to Consolidated Financial Statements:


MARKET RISK	PAGE
• Foreign Currency Exchange Rate Risk		34-36
• Commodity Price Risk		36-37
• Interest Rate Risk		37-38
• Equity Price Risk		38

ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA

Information required by this item may be found on pages 40 through 67 of the Company’s Annual Report.

ITEM 9. CHANGES IN AND DISAGREEMENTS WITH ACCOUNTANTS ON ACCOUNTING AND FINANCIAL DISCLOSURE

None.

ITEM 9A. CONTROLS AND PROCEDURES

a) Evaluation of disclosure controls and procedures. As of the end of the period covered by this Annual Report on Form 10-K, the Company’s management, under the supervision and with the participation of the Company’s Chief Executive Officer and Chief Financial Officer, evaluated the effectiveness of the design and operation of the Company’s disclosure controls and procedures. Based on that evaluation, the Company’s Chief Executive Officer and Chief Financial Officer believe 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 or submits 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

•		the Company’s disclosure controls and procedures operate such that important information flows to appropriate collection and disclosure points in a timely manner and are effective to ensure that such information is accumulated and communicated to the Company’s management, and made known to the Company’s Chief Executive Officer and Chief Financial Officer, particularly during the period when this Annual Report on Form 10-K was prepared, as appropriate to allow timely decision regarding the required disclosure.

b) Changes in internal controls. There have been no changes in the Company’s internal controls over financial reporting during the Company’s last fiscal quarter of 2004 that have materially affected, or are reasonably likely to materially affect, the Company’s internal control over financial reporting.

ITEM 9B. OTHER INFORMATION

None.

PART III

ITEM 10. DIRECTORS AND EXECUTIVE OFFICERS OF THE COMPANY

Information required under this item with respect to Directors and with respect to delinquent filers pursuant to Item 405 of Regulation S-K is incorporated by reference from the Company’s definitive Proxy Statement for the Annual Meeting of Stockholders to be held March 2, 2005, to be filed with the Commission not later than 120 days after September 30, 2004. The information required by this Item with respect to the Company’s Executive Officers appears on page 14 of this Report.

The Company has adopted a Code of Ethics for Principal Executive Officers and Senior Financial Officers. The text of such Code is located on the Company’s website under “Investor Relations - Corporate Governance.” The Company’s Internet address is www.hpinc.com.

ITEM 11. EXECUTIVE COMPENSATION

This information is incorporated by reference from the Company’s definitive Proxy Statement for the Annual Meeting of Stockholders to be held March 2, 2005, to be filed with the Commission not later than 120 days after September 30, 2004.

ITEM 12. SECURITY OWNERSHIP OF CERTAIN BENEFICIAL OWNERS AND MANAGEMENT AND RELATED STOCKHOLDER MATTERS

ITEM 13. CERTAIN RELATIONSHIPS AND RELATED TRANSACTIONS

ITEM 14. PRINCIPAL ACCOUNTANT FEES AND SERVICES

PART IV

ITEM 15. EXHIBITS, FINANCIAL STATEMENT SCHEDULES, AND REPORTS ON FORM 8-K

1.Financial Statements: The following appear in the Company’s Annual Report at the pages indicated below and are incorporated herein by reference:


Report of Independent Auditors			39
Consolidated Statements of Income for the Years Ended September 30, 2004, 2003 and 2002			40
Consolidated Balance Sheets at September 30, 2004 and 2003			41-42
Consolidated Statements of Shareholders’ Equity for the Years Ended September 30, 2004, 2003 and 2002			43
Consolidated Statements of Cash Flows for the Years Ended September 30, 2004, 2003 and 2002			44
Notes to Consolidated Financial Statements			45-67

2.		Financial Statement Schedules: All schedules are omitted as inapplicable or because the required information is contained in the financial statements or included in the notes thereto.

3.		Exhibits. The following documents are included as exhibits to this Form 10-K. Exhibits incorporated by reference herein are duly noted as such. Unless so noted, each exhibit is filed herewith.

3.1Restated Certificate of Incorporation and Amendment to Restated Certificate of Incorporation of the Company are incorporated herein by reference to Exhibit 3.1 of the Company’s Annual Report on Form 10-K to the Securities and Exchange Commission for fiscal 1996, SEC File No. 001-04221.

3.2Amended and Restated By-Laws of the Company are incorporated herein by reference to Exhibit 3.2 of the Company’s Quarterly Report on Form 10-Q to the Securities and Exchange Commission for the quarter ended March 31, 2002, SEC File No. 001-04221.

4.1Rights Agreement dated as of January 8, 1996, between the Company and The Liberty National Bank and Trust Company of Oklahoma City, N.A. is incorporated herein by reference to the Company’s Form 8-A, dated January 18, 1996, SEC File No. 001-04221.

*10.1Consulting Services Agreement between W. H. Helmerich, III, and the Company effective January 1, 1990, is incorporated herein by reference to Exhibit 10.3 of the Company’s Annual Report on Form 10-K to the Securities and Exchange Commission for fiscal 1996, SEC File No. 001-04221.

*10.2Supplemental Retirement Income Plan for Salaried Employees of Helmerich & Payne, Inc. is incorporated herein by reference to Exhibit 10.6 of the Company’s Annual Report on Form 10-K to the Securities and Exchange Commission for fiscal 1996, SEC File No. 001-04221.

*10.3Helmerich & Payne, Inc. 1990 Stock Option Plan is incorporated herein by reference to Exhibit 10.7 of the Company’s Annual Report on Form 10-K to the Securities and Exchange Commission for fiscal 1996, SEC File No. 001-04221.

*10.4Form of Nonqualified Stock Option Agreement for the 1990 Stock Option Plan is incorporated by reference to Exhibit 99.2 to the Company’s Registration Statement No. 33-55239 on Form S-8, dated August 26, 1994.

*10.5Supplemental Savings Plan for Salaried Employees of Helmerich and Payne, Inc. is incorporated herein by reference to Exhibit 10.9 to the Company’s Annual Report on Form 10-K to the Securities and Exchange Commission for fiscal 1999, SEC File No. 001-04221.

*10.6Helmerich & Payne, Inc. 1996 Stock Incentive Plan is incorporated herein by reference to Exhibit 99.1 to the Company’s Registration Statement No. 333-34939 on Form S-8 dated September 4, 1997.

*10.7Form of Nonqualified Stock Option Agreement for the Helmerich & Payne, Inc. 1996 Stock Incentive Plan is incorporated by reference to Exhibit 99.2 to the Company’s Registration Statement No. 333-34939 on Form S-8 dated September 4, 1997.

*10.8Form of Restricted Stock Agreement for the Helmerich & Payne, Inc. 1996 Stock Incentive Plan is incorporated by reference to Exhibit 10.12 to the Company’s Annual Report on Form 10-K to the Securities and Exchange Commission for fiscal 1997, SEC File No. 001-04221.

*10.9Helmerich & Payne, Inc. 2000 Stock Incentive Plan is incorporated herein by reference to Exhibit 99.1 to the Company’s Registration Statement No. 333-63124 on Form S-8 dated June 15, 2001.

*10.10Form of Agreements for Helmerich & Payne, Inc. 2000 Stock Incentive Plan being (i) Restricted Stock Award Agreement, (ii) Incentive Stock Option Agreement and (iii) Nonqualified Stock Option Agreement are incorporated by reference to Exhibit 99.2 to the Company’s Registration Statement No. 333-63124 on Form S-8 dated June 15, 2001.

*10.11Form of Director Nonqualified Stock Option Agreement for the 2000 Helmerich & Payne, Inc. Stock Incentive Plan is incorporated herein by reference to Exhibit 10.1 of the Company’s Quarterly Report on Form 10-Q to the Securities and Exchange Commission for the quarter ended June 30, 2002, SEC File No. 001-04221.

*10.12Form of Change of Control Agreement for Helmerich & Payne, Inc. is incorporated herein by reference to Exhibit 10.3 of the Company’s Quarterly Report on Form 10-Q to the Securities and Exchange Commission for the quarter ended June 30, 2002, SEC File No. 001-04221.

10.13Second Amendment to Credit Agreement, dated as of July 16, 2002, by and among Helmerich & Payne International Drilling Co., Helmerich & Payne, Inc. and Bank One, Oklahoma, N.A. is incorporated herein by reference to Exhibit 10.4 of the Company’s Quarterly Report on Form 10-Q to the Securities and Exchange Commission for the quarter ended June 30, 2002, SEC File No. 001-04221.

10.14Credit Agreement, dated as of July 16, 2002, among Helmerich & Payne International Drilling Co., Helmerich & Payne, Inc., the several lenders from time to time party thereto, and Bank of Oklahoma, National Association is incorporated herein by reference to Exhibit 10.5 of the Company’s Quarterly Report on Form 10-Q to the Securities and Exchange Commission for the quarter ended June 30, 2002, SEC File No. 001-04221.

10.15Note Purchase Agreement dated as of August 15, 2002, among Helmerich & Payne International Drilling Co., Helmerich & Payne, Inc. and various insurance companies is incorporated herein by reference to Exhibit 10.20 of the Company’s Annual Report on Form 10-K to the Securities and Exchange Commission for fiscal 2002, SEC File No. 001-04221.

10.16Office Lease dated May 30, 2003, between K/B Fund IV and Helmerich & Payne, Inc. is incorporated herein by reference to Exhibit 10.18 of the Company’s Annual Report on Form 10-K to the Securities and Exchange Commission for fiscal 2003, SEC File No. 001-04221.

*10.17Helmerich & Payne, Inc. Director Deferred Compensation Plan is incorporated herein by reference to Exhibit 10.1 of the Company’s Form 8-K filed on September 9, 2004.

10.18Shareholders Agreement and Registration Rights Agreement dated July 19, 2004 between Helmerich & Payne International Drilling Co. and Atwood Oceanics, Inc. is incorporated herein by reference to Exhibit 1.1 of the Company’s Amended Schedule 13D filed on July 21, 2004.

10.19Underwriting Agreement dated October 13, 2004, between Helmerich & Payne International Drilling Co. and various underwriters is incorporated herein by reference to Exhibit 1.1 of the Company’s Form 8-K filed on October 14, 2004.

*10.20Helmerich & Payne, Inc. Annual Bonus Plan for Executive Officers is incorporated herein by reference to Exhibit 10.1 of the Company’s Form 8-K filed on December 6, 2004.

13.The Company’s Annual Report to Shareholders for fiscal 2004.

21.List of Subsidiaries of the Company is incorporated herein by reference to Exhibit 21 of the Company’s Annual Report on Form 10-K to the Securities and Exchange Commission for fiscal 2003, SEC File No. 001-04221.

23.1Consent of Independent Registered Public Accounting Firm.

31.1Certification of Chief Executive Officer, as Adopted Pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.

31.2Certification of Chief Financial Officer, as Adopted Pursuant to Section 302 of the Sarbanes- Oxley Act of 2002.

32Certification of Chief Executive Officer and Chief Financial Officer Pursuant to 18 U.S.C. Section 1350, as Adopted Pursuant to Section 906 of the Sarbanes-Oxley Act of 2002.

* Management or Compensatory Plan or Arrangement.

(b) Reports on Form 8-K

The Company filed two reports on Form 8-K during the last quarter of fiscal 2004 as follows:

•		Form 8-K dated July 22, 2004, containing a Press Release with attached Unaudited Consolidated Condensed Balance Sheets, Consolidated Statements of Income and Financial Results – Lines of Business, announcing the Company’s third quarter 2004 earnings.

•		Form 8-K dated September 2, 2004, disclosing the approval by the Company’s Board of Directors of the Helmerich & Payne, Inc. Director Deferred Compensation Plan, to become effective October 1, 2004.

SIGNATURES

Pursuant to the requirements of Section 13 or 15(d) of the Securities Exchange Act of 1934, the Company has duly caused this Report to be signed on its behalf by the undersigned, thereunto duly authorized:


HELMERICH & PAYNE, INC.

By		/s/ Hans Helmerich
Hans Helmerich, President and Chief Executive Officer
Date: February 11, 2005

INDEX TO EXHIBITS