Helmerich & Payne
Annual Report 1995

Plain-text annual report

Helmerich & Payne, Inc. Annual Report for 1995 Highlights Years Ended September 30, 1995 1994 Revenues Net Income $ 325,776,000 $ 329,001,000 $ 9,751,000 $ 24,971,000 Earnings Per Share Dividends Paid Per Share $ .40 $ .50 $ 1.02 $ .485 Capital Expenditures $ 111,776,000 $ 105,883,000 Total Assets $ 710,165,000 $ 624,827,000 HELMERICH & PAYNE, INC. IS A DIVERSIFIED, ENERGY-ORIENTED COMPANY ENGAGED IN CONTRACT DRILLING, OIL AND GAS EXPLORATION AND PRO- DUCTION, CHEMICALS MANUFACTURING, AND REAL ESTATE DEVELOPMENT AND MANAGEMENT. THE COMPANY ALSO HOLDS SUBSTANTIAL EQUITY INVESTMENTS IN SEVERAL OTHER PUBLICLY OWNED CORPORATIONS. President’s Letter To the Co-owners of Helmerich & Payne, Inc. In our fast paced lives, we easily forget to pause long enough to reflect on our significant milestones. The Company’s celebration of its 75th year anniversary provided such an opportunity during 1995. The theme of that celebration is captured by Peter Drucker when he suggests that people are a Company’s only strategic asset. From the first days of the partnership between my grandfather and Bill Payne, the Company has been built on the principle that success springs from the character and competency of its people. The acceleration of change in today’s world and the challenge of generating growth and economic returns in a stagnate energy industry only act to underscore that our future will be measured by our ability to carry forward the successful combination of talent and integrity characteristic of the people that have served the Company during its first 75 years. On the first score, I am convinced we will continue to recruit and develop a team with superior skills and training. In fact, today we are stronger than ever and are building a roster loaded with talent as we face the opportunities ahead. But talent is not enough. It must be teamed together with the inner qualities of integrity and trustworthiness. This elusive quality of heart is more a matter of daily habit than a slogan or catch phrase. It is not scripted by company policy, but from deep inside, a kind of internal reflex of character. My grandfather was fond of saying that you must always hire good people and that life was just too short to do business with the wrong people. Over the years, our nation has produced a good- ness, a strength of character in its people that has fueled the greatest economy and quality of life ever before in all of history. 2 Looking forward, does de Tocqueville’s classic observation that America’s greatness is secured from the wellspring of her basic goodness still hold true for our children? In his tour across America, Colin Powell lamented that our society had lost its sense of shame. Our young people are paying a terrible price. We lead the industrialized world in illegitimate births, abortions, teenage suicide, and violent crime while ranking at the bottom in our elementary and secondary school achievement scores. By its nature, the government cannot impart goodness, and displacing parental responsibility with political compassion is doomed to fail. We see our prisons and welfare rolls dominated by the fatherless. If a young person’s core principles and goodness of heart are nurtured from early childhood, shaped and cultivated within families, then every business person and citizen has a stake in their success. Strong families drive our future. Scripture speaks of turning the hearts of the fathers to the children and an African proverb says the raising of a child is so important that it takes an entire village to do it. While the government can play a role by reforming welfare and reducing the crushing tax burden, only parents, families, rela- tives, pastors, troop leaders, coaches, and teachers can build and safeguard our nation’s most strategic asset, our children. December 15, 1995 Sincerely, Hans Helmerich President 3 Drilling H E L M E R I C H & PAY N E I N T E R N AT I O N A L D R I L L I N G C O. SUMMARY At the close of 1995, Helmerich & Payne International Drilling Co. owned 30 land rigs and 11 off- shore platform rigs in the United States, and 35 land rigs in the countries of Venezuela (18), Colombia (10), Ecuador (4), Bolivia (2), and Trinidad (1). Financial results in 1995 improved considerably over 1994 with revenues and pre-tax operating profit increasing 11 and 38 percent, respectively. INTERNATIONAL OPERATIONS The Company has had operations in South America since the 1950’s and today the region ranks among the most active contract drilling arenas in the world. A total of nine rigs were moved to South America in 1995, three of which were deployed to Colombia for the Cusiana/Cupiagua development operated by BP Exploration, and two rigs were moved to Bolivia for Exxon and Total. Four rigs were sent to Venezuela and one more was en route at the close of the fiscal year. For the first time in several decades, Venezuela is encouraging outside investment to develop its prolific oil and gas resources. This change in policy is expected to stimulate additional demand for drilling services in the future. DOMESTIC OPERATIONS Land rig utilization aver- aged 73 percent in 1995, compared with 66 percent the previous year. An average of five more rigs worked throughout the year than in 1994, primarily due to the Company’s acquisition of ENSCO’s domestic land drilling business in the third quarter of last year. Offshore platform activity declined in 1995, with Company- owned rigs averaging 66 percent utilization compared with 79 percent in 1994. Five rigs worked continually in the Gulf of Mexico and two rigs offshore California. The Company 4 also provided labor and other services for two Exxon-owned platform rigs located offshore California. In the spring of 1995, Helmerich & Payne International Drilling Co. was awarded a contract to design, build, and operate an offshore platform rig for Shell Offshore Inc.’s (SOI) Mars tension leg platform (TLP) in the Gulf of Mexico. The Mars project, considered by many to be the largest discovery in the Gulf of Mexico in more than 20 years, is scheduled to begin in the spring of 1996 and will be set at a water depth exceeding 2,900 feet. The Company was also awarded a letter of intent to build a similar rig for SOI’s Ram-Powell project which is sched- uled to begin in 1997. The Ram-Powell TLP will be set at a water depth of approximately 3,200 feet. Deepwater developments like these will be pivotal to the future of the offshore oil and gas industry, and the Company is well posi- tioned to participate at the forefront of this trend. OUTLOOK Four points stand out among the myriad issues and challenges facing the Company and this industry. First, safety and the prevention of accidents is and will continue to be a crucial objective. Second, the organiza- tional structure needs to have the agility to respond effectively in periods of both high and low demand. Third, as customers continue to hone their organizations to achieve better efficiency and productivity, this will create opportunities for contractors to provide additional services. Finally, each of these three points is contributing to the formation of alliances between operators, contractors, and other service companies. The Company is leading and participating in several of these relationships, and is committed to further enhancing its ability to add value to the customer. 5 Exploration & Production H E L M E R I C H & PAY N E , I N C . SUMMARY Helmerich & Payne, Inc. explores for, develops, and acquires oil and natural gas reserves pri- marily in the states of Oklahoma, Kansas, Texas, and Louisiana. Additionally, the Company provides natural gas marketing services through its wholly-owned sub- sidiary, Helmerich & Payne Energy Services, Inc. At year-end, the Company reported proved reserves of approximately 280 billion cubic feet (Bcf) of natural gas and 6.3 million barrels of oil. Reserves were approxi- mately 290.7 Bcf and 6.7 million barrels in 1994. PRODUCTION OVERVIEW Natural gas production averaged 72,387 thousand cubic feet (Mcf) per day in 1995, compared with a 72,953 Mcf per day average in 1994. The average price received for natural gas fell by 45 cents per Mcf to $1.27 in 1995, reducing natural gas revenue by 25 percent for the year. Oil production aver- aged 2,214 barrels per day compared with 2,431 barrels in 1994. The average price received per barrel of oil increased to $16.37 per barrel in 1995, from $14.83 the previous year. FINANCIAL OVERVIEW Effective in 1995, the Company adopted Statement of Financial Accounting Standards No. 121 (SFAS 121) “Accounting for the Impairment of Long-Lived Assets” which resulted in a $20 million non-cash charge to pre-tax operating profit. Under SFAS 121, the Company measures impairment to oil and gas assets on a field-by-field basis, rather than using a single cost center. This impairment charge, coupled with the collapse of natural gas prices, had a significant negative impact on the year’s financial results. 6 Financial Summary Years Ended September 30, 1995 1994 1993 Oil Revenue . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Natural Gas Revenue . . . . . . . . . . . . . . . . . . . . . . . Pre-tax Operating Profit (Loss) . . . . . . . . . . . . . . . . Depreciation and Depletion . . . . . . . . . . . . . . . . . . SFAS 121 Impairment . . . . . . . . . . . . . . . . . . . . . . Capital Expenditures . . . . . . . . . . . . . . . . . . . . . . . $13,227 33,851 (23,961) 19,913 19,982 20,956 (in thousands) $13,161 45,261 3,245 19,523 45,809 $15,392 52,446 19,495 18,294 25,551 DRILLING AND EXPLORATION The Company partici- pated in the drilling of 59 (27.4 net) wells in 1995, 46 (24.1 net) of which were development wells, and 13 (3.3 net) were classified as exploratory wells. A total of 42 wells (21.5 net) were productive and 17 (5.9 net) wells were dry holes. During 1995, the Company increased its investment in exploration prospects. The Company had working inter- ests in several high profile, yet unsuccessful wells including the Sealind 1-11 in Wyoming, and the Shadyside A-1 and the Miami Fee #5 in Louisiana. In the Louisiana Austin Chalk, the Company is exchanging or pooling some of its acreage on the western side of this prospect for overriding royalties or carried interests in exploratory drilling efforts. The Company intends to minimize its financial exposure to the exploratory phase of this prospect, while retaining an acreage position for potential development opportunities. OUTLOOK In September of 1995, the Company restructured its Exploration and Production Division around geographically focused teams. Each team will review and develop drilling, workover, and acquisition prospects for a specific region. The objective is to enhance performance by refocusing on the Company’s strengths in key geographic regions. 7 Real Estate H E L M E R I C H & PAY N E P R O P E R T I E S , I N C . The purchase of Utica Square Shopping SUMMARY Center in 1964 marked the beginning of the Company’s active involvement in Tulsa’s commercial real estate market. Through its wholly-owned subsidiary, Helmerich & Payne Properties, Inc., the Company owns 1,652,311 square feet of leasable space and approximately 257 acres of undevel- oped land. An increase in industrial leasing activity helped move the Company’s occupancy level from an average of 83 percent in 1994, to 87 percent in 1995. Pre-tax operating profit fell sharply in 1995, as the Company adopted Statement of Financial Accounting Standards No. 121 (SFAS 121) which resulted in a write- down in the book value of two combination office/ware- house properties acquired in the mid-1980’s. Financial Highlights Years Ended September 30, 1995 1994 1993 Gross Revenues............................................................................ Pre-Tax Operating Profit ............................................................... Depreciation Expense ................................................................... SFAS 121 Impairment ................................................................... Capital Expenditures..................................................................... Year-End Book Value .................................................................... Average Occupancy...................................................................... $ 7,570 2,157 1,623 2,000 907 23,353 87% (in thousands) $ 7,803 4,460 1,624 916 26,065 83% $ 7,630 4,149 1,679 458 27,006 86% UTICA SQUARE SHOPPING CENTER With its unique outdoor design spread over 30 landscaped acres, Utica Square Shopping Center is the cornerstone of the Company’s real estate portfolio and a landmark in the Tulsa community. Nearly 70 merchants and restaurants reside at Utica Square including Ann Taylor, Banana Republic, The Disney Store, Miss Jackson’s, The Limited, Pier 1, Saks Fifth Avenue and Williams-Sonoma. 8 INDUSTRIAL PROPERTIES The Company’s industrial real estate holdings consist of two bulk warehouse developments encompassing 697,500 square feet and four combination office/warehouse developments with a total of 367,234 square feet. All of the Company’s properties are located in the southeastern section of Tulsa, proximate to major trans- portation arteries. During 1994, the Company reorganized its marketing strategy for these properties by outsourcing leasing activities to a local broker specializing in industrial properties. The additional exposure derived from this effort, combined with an improved leasing climate, helped increase occupancy from 77 percent at the end of 1994, to 90 percent at the close of 1995. Summary of Property Owned Property Name Description Square Feet Utica Square Shopping Center Utica Square Offices and Medical Center Plaza Office Building Space Center Space Center East Tandem Business Park Tulsa Business Park Maxim Center Maxim Place Southpark Upscale Retail Professional Offices Corporate Offices Industrial Warehouses Industrial Warehouses Office/Warehouse Complex Office/Warehouse Complex Office/Warehouse Complex Office/Warehouse Complex Undeveloped 257 Acres Total Square Feet 405,709 94,969 86,899 495,000 202,500 88,084 204,600 40,800 33,750 1,652,311 OUTLOOK There are a number of positive signs in the Tulsa economy which should help to continue the absorption of excess commercial space into the next year. Tulsa was the beneficiary of some significant expansion and relocation decisions in 1995 and the aviation industry, one of the area’s largest employers, appears to be enjoying a modest recov- ery. While a development boom is not anticipated anytime soon, the Company’s property holdings are well positioned in the market to benefit from future growth of the Tulsa area. 9 Chemicals N AT U R A L G A S O D O R I Z I N G , I N C . SUMMARY Natural Gas Odorizing, Inc. (NGO), is a leading producer of mercaptan-based chemicals used as warning agents in natural and liquified petroleum gas (LPG). In most North American jurisdictions natural gas and LPG odorization is required by law before the fuels can be sold for commercial or residential purposes. On a smaller scale, NGO produces simi- larly composed products which are used as sulfides or feed stock in other processes within the chemical and refining industries. The Company’s Baytown, Texas, plant neighbors an Exxon refinery from which the Company receives its key raw materials, hydrogen sulfide and olefins. Products are shipped in Company- owned tank trucks or in returnable or non-returnable cylinders to a customer base primarily made up of natural gas utilities and LPG distribution companies. NGO competes with two other suppliers in this small but highly competitive market. Approximately nine percent of NGO’s sales came from outside of North America in 1995, compared with eight percent in 1994. Financial Highlights Years Ended September 30, 1995 Gross Revenues............................................................................ Pre-Tax Operating Profit ............................................................... Depreciation Expense................................................................... Capital Expenditures..................................................................... Pounds of Product Sold ................................................................ $ 19,055 6,221 672 859 7,670 1994 (in thousands) $ 18,849 5,994 654 619 8,071 1993 $ 14,374 3,665 594 630 7,930 Total revenue and operating profit finished at record levels for the respective sixth and fifth consecutive years in 1995. Product price increases were the major reason for improved results over the past three years. During 1995, an investment banking firm was retained to advise the Company regarding the potential sale of Natural Gas Odorizing, Inc. 10 Revenues and Income by Business Segments HELMERICH & PAYNE, INC. Years Ended September 30, 1995 1994 1993 (in thousands) SALES AND OTHER REVENUES: Contract Drilling - Domestic ...................................... Contract Drilling - International .................................. Total Contract Drilling Division ..................................... $ 93,890 110,695 204,585 $ 86,521 98,111 184,632 Exploration and Production....................................... Natural Gas Marketing............................................. Total Oil and Gas Division .................................... Chemical Division ................................................... Real Estate Division ................................................ Investments and Other Income .................................. 47,986 35,301 83,287 19,055 7,570 11,279 58,884 51,889 110,773 18,849 7,803 6,944 $ 60,328 89,618 149,946 69,795 63,858 133,653 14,374 7,630 9,494 Total Revenues ............................................................ $325,776 $329,001 $315,097 OPERATING PROFIT (LOSS): Contract Drilling - Domestic ...................................... Contract Drilling - International .................................. Total Contract Drilling Division ............................... $ 7,127 21,110 28,237 $ 5,874 14,645 20,519 $ 122 15,281 15,403 Exploration and Production....................................... Natural Gas Marketing............................................. Total Oil and Gas Division.......................................... Chemical Division ................................................... Real Estate Division ................................................ Total Operating Profit ................................................... OTHER: Miscellaneous operating .......................................... Income from investments ......................................... General corporate expense ...................................... Interest expense..................................................... Corporate depreciation ............................................ Total Other ........................................................ INCOME BEFORE INCOME TAXES, EQUITY IN INCOME (LOSS) OF AFFILIATE, AND CUMULATIVE EFFECT OF CHANGE IN ACCOUNTING PRINCIPLE:........................ (23,961) 1,892 (22,069) 6,221 2,157 14,546 (1,624) 10,846 (8,801) (407) (851) (837) 3,245 1,525 4,770 5,994 4,460 35,743 (1,292) 6,303 (8,908) (385) (1,162) (5,444) 19,495 667 20,162 3,665 4,149 43,379 (687) 9,050 (6,820) (925) (766) (148) $ 13,709 $ 30,299 $ 43,231 Note: This schedule is an integral part of Note 11 (pages 27-28) of the financial statements that follow. 11 Management’s Discussion & Analysis of Results of Operations and Financial Condition HELMERICH & PAYNE, INC. Results of Operations Helmerich & Payne, Inc.’s net income for 1995 was $9,751,000 ($0.40 per share), compared with net income of $24,971,000 ($1.02 per share) in 1994, and $24,550,000 ($1.01 per share) in 1993. Net income in 1995 includes a non-cash, non-recurring charge of $13,600,000 ($0.55 per share) as a result of the Company’s adoption of Statement of Financial Accounting Standards (SFAS) No. 121, Accounting for the Impairment of Long-Lived Assets and for Long-Lived Assets to be Disposed Of. Results for 1994 included $4 million ($0.16 per share) of income due to a one-time reduction in the Company’s deferred income taxes from the cumulative effect of adopting SFAS No. 109, Accounting for Income Taxes. Included in the Company’s net income, but not related to its operations, were after-tax gains from the sale of investment securities of $3,481,000 ($0.14 per share) in 1995, and $1,780,000 ($0.07 per share) in 1993. Also included was the Company’s portion of income or losses of its equity affiliate, Atwood Oceanics, Inc., which was $0.04 per share of income in both 1995 and 1994, and a loss of $0.02 per share in 1993. Company revenues declined slightly to $325,776,000 in 1995, from $329,001,000 in 1994, and $315,097,000 in 1993. Although contract drilling revenues rose by 11 percent this past year, oil and gas division revenues declined by almost 25 percent, primarily due to lower natural gas prices and production volumes. Total revenue increased by 4 per- cent from 1993 to 1994, as a result of increases in domestic drilling (43 percent), international drilling (9 percent), and chemical (31 percent) segments. Revenues from exploration and production (16 percent decrease) and natural gas marketing (19 percent decrease) also fell appreciably in 1994 as oil and natural gas prices and natural gas pro- duction volume declined. Total revenues for 1996 are expected to be slightly higher than for 1995 due to increased activity in international contract drilling operations. Revenues from investments rose to $10,846,000 in 1995, after declining to $6,303,000 in 1994, from $9,050,000 in 1993. Gains from the sale of investment securities were $5,697,000 in 1995, $124,000 in 1994 and $2,914,000 in 1993. Dividend income was stable during 1995, 1994 and 1993, but interest income steadily decreased as cash balances and interest rates generally declined during these periods. 12 Costs and expenses in 1995 were $312,067,000, 96 percent of total revenues, compared with 91 percent in 1994, and 86 percent in 1993. Total costs for 1995 were abnormally high due to the adoption of SFAS No. 121 which resulted in a total pre-tax impairment charge of $22,000,000 recorded as additional depreciation, depletion, and amorti- zation. Operating costs as a percentage of operating revenues declined in 1995 to 1993 levels (64 percent) after rising slightly to 66 percent in 1994. The operating cost percentages rose slightly in 1994 because of increased activity in the lower margin domestic land drilling business and an increase in operating expenses in the international contract drilling business. General and administrative expenses of $8,801,000 in 1995 were down slightly from $8,908,000 in 1994, and up significantly from $6,820,000 in 1993. The increase in 1994 was due primarily to increased costs of employee healthcare benefits and, to a lesser degree, a net increase in pension expense. It is anticipated that 1996 general and administrative expenses will increase slightly from 1995. Income tax expense, as a percentage of pre-tax income, rose to 37 per- cent in 1995, from 34 percent in 1994. The effective tax rate for 1994 was lower because of the usage of foreign tax credit carryforwards, tight sands tax credits, and a reduction in Venezuelan taxes as a result of the monetary correction tax law enacted there. The effective tax rate was 42 percent in 1993, prior to the enactment of the monetary correction tax law in Venezuela. CONTRACT DRILLING DIVISION revenues increased by 11 percent this year, following a 23 percent increase from 1993 to 1994. Domestic drilling operating profit increased to $7,127,000 in 1995, from $5,874,000 in 1994 and $122,000 in 1993. From 1993 to 1994, the Company’s U.S. offshore platform rig business improved significantly, thereby helping boost revenue and income. During that time and con- tinuing into 1995, the land rig operations also improved substantially, aided by the 1994 purchase of Ensco’s south Texas land rig operations. However, it is anticipated that 1996 domestic revenues and income will not materially change from 1995 levels. International revenues climbed to $110,695,000 in 1995, from $98,111,000 in 1994, and $89,618,000 in 1993. Operating profit for the international contract drilling sector improved by 44 percent to $21,110,000 for 1995, compared with $14,645,000 in 1994 and $15,281,000 in 1993. Revenues and profit margins in the Company’s two most active international operations, Venezuela and Colombia, improved significantly in 1995. The Company sent four new rigs to Venezuela and three to Colombia, bringing rig counts in those countries to 18 and 10, respectively. The Company anticipates its operating 13 profit from international operations will improve for the coming year based on higher activity levels in both Colombia and Venezuela. In 1994, the Venzuelan government fixed the exchange rate which resulted in exchange losses for the Company totaling approximately $2,764,000. During fiscal 1995, the currency exchange rates remained fixed, however, the Company’s operating costs increased due to hyperinflation in the Venezuelan economy. These higher costs were partially offset by the purchase of currency at market rates using Brady Bonds. During the first week of December 1995, the government reset the exchange rate, increasing it from 170 Bolivars to 290 Bolivars to the U.S. dollar. It is estimated that the Company will not experience a material loss, if any, from this devaluation. It is uncertain when the government will reset the exchange rate again but the Company does not expect losses from future fluctuations in the exchange rate during 1996 to be material. The Company will continue to purchase Brady Bonds to help offset a portion of any future exchange losses or higher operating costs as a result of inflation. OIL AND GAS DIVISION revenues and operating profit have declined over the past two years due to a significant decrease in natural gas prices from $1.84 per Mcf in 1993, to $1.72 in 1994 and $1.27 in 1995. Natural gas production volumes also declined over the same period of time from approximately 78 milion cubic feet a day (Mmcf/d) in 1993, to 73 Mmcf/d in 1994, and 72.4 Mmcf/d in 1995. During 1995, the Company elected to adopt SFAS No. 121, resulting in a $19,982,000 charge to the Oil and Gas Division. Because of the decline in natural gas volumes and prices, revenues fell from $69,795,000 in 1993, to $58,884,000 in 1994, and to $47,986,000 in 1995. Operating profit over the same period fell from $19,495,000 in 1993, to $3,245,000 in 1994, and to a loss of $23,961,000 in 1995, which includes the $19,982,000 charge discussed above. Dry-hole and abandonment charges for the oil and gas division rose from $6,938,000 in 1993, to $8,932,000 in 1994, and to $8,981,000 in 1995. Abandonment charges in 1994 increased significantly due to the reduction in the carrying value of the Company’s leasehold position in its Austin Chalk prospect in south central Louisiana. Dry-hole expense was up in 1995 due to increased exploratory activity during the year. A lawsuit was filed in an Oklahoma state court in November of 1995 against Helmerich & Payne, Inc., in which five named plaintiffs, on behalf of themselves and other unnamed plaintiffs, are demanding their royalty share of a gas contract settlement. The plaintiffs are attempting to certify a class which would contain certain of the Company’s lessors and certain other mineral owners who own an interest in wells covered by such gas contract settlement. The Company intends to vigorously defend this law- suit. However, if a certified class is awarded a royalty share of the gas contract settlement, then any such award could have a material impact 14 on income from continuing operations for the applicable quarter. Management believes that any such award should not exceed approxi- mately $2.7 million. Natural gas marketing revenues, which are primarily derived from sell- ing natural gas produced by other companies (third party), declined to $35,301,000 in 1995, from $51,889,000 in 1994, and $63,858,000 in 1993. Operating profit was $1,892,000 in 1995, $1,525,000 in 1994, and $667,000 in 1993. The Company’s approach has been to use the existing capacity of its personnel and facilities to derive additional profit from matching its customers with third party producers when the mar- keting situation is not conducive for the sale of the Company’s own natural gas. It is expected that competition will continue to limit fees and pre- miums for third party natural gas sales. Therefore, the Company does not anticipate significant growth in revenue and income from third party sales in the coming year. CHEMICAL DIVISION revenues increased by 1 percent from 1994 to 1995 to $19,055,000, and by 31 percent from 1993 to 1994. Operating profit increased by 4 percent from 1994 to 1995 to $6,221,000, and by 64 percent from 1993 to 1994. Product price increases and improved margins accounted for the significant rise in revenues and income in 1994. Growth flattened during 1995 as prices remained stable. The Company has engaged an investment banking firm for the purpose of advising the Company regarding the potential sale of its chemical opera- tions in 1996. Specialty chemical companies appear to be valued at premium prices at this time and the Company believes that, given an attractive price, the timing may be appropriate to sell the Division. REAL ESTATE DIVISION revenues for 1994 were up, compared to 1995 and 1993, due to the sale of a small parcel of land which resulted in a $450,000 gain. Operating profit for 1995 was down significantly due to a $2,000,000 charge to two properties in connection with the adoption of SFAS No. 121. However, occupancy for 1995 was slightly improved and it is anticipated that the division will return to normal levels of rev- enues and income during 1996. FINANCIAL CONDITION The Company has maintained a very strong balance sheet for many years with current ratios above 1.65 for the last three years and long- term debt to total capitalization remaining below 2 percent for that same period. During 1995, the Company signed a three-year agreement with a syndicate of banks for a line of credit totaling $75 million. At year end, $21,700,000 had been borrowed under the facility. This was the first time the Company had gone to outside sources for capital funding since the early 1980’s. Capital expenditures for the last two years were over $100 million and exceeded the funds generated internally. It is 15 anticipated that during 1996 the capital expenditures will again exceed $100 million and that additional borrowings will be necessary to fund those expenditures. Cash flow provided by operating activities totaled $88,572,000 for 1995, $79,909,000 for 1994, and $74,619,000 for 1993. It is anticipated that cash generated by operating activities will increase again during the coming year due to improvement in rig utiliza- tion and profitability in South America. As it did in 1993 and 1995, the Company may choose to sell a portion of its investment portfolio to aid in the funding of capital expenditures. Capital expenditures budgeted for 1996 include continued exploration and development drilling activities, major offshore platform rig construction projects for Gulf of Mexico operations, and the completion of the Company’s investment in a joint venture with its equity affiliate, Atwood Oceanics. The joint venture will construct a new generation offshore platform rig for work offshore Australia. The Company manages a large portfolio of marketable securities which had a cost basis of $87,299,000 at September 30, 1995, and a total market value at that time of $158,201,000, including its investment in Atwood. During 1995, the Company adopted SFAS No. 115, Accounting for Certain Investments in Debt and Equity Securities, which resulted in the balance sheet adjustment to market values for investments in com- panies owned less than 20 percent. Accordingly, a deferred tax estimate was added to deferred taxes under the liability section and the net unrealized holding gains were reflected in the shareholders’ equity sec- tion of the balance sheet. During 1995, the Company paid a dividend of $.50 per share which represented the 24th consecutive year of dividend increases. Stock Portfolio Held by the Company September 30, 1995 Number of Shares Book Value Market Value Schlumberger, Ltd.................................................... Atwood Oceanics, Inc...................................................... Sun Company, Inc. .......................................................... Sun Company PFD A ......................................................... Phillips Petroleum Company ............................................ Liberty Bancorp............................................................... Oryx Energy Company .................................................... Oneok............................................................................. Other .............................................................................. Total.................................................................... 740,000 1,600,000 466,451 329,053 240,000 395,000 625,000 225,000 (in thousands,except share amounts) $ 23,511 22,495 5,742 3,192 5,976 5,743 6,032 2,751 11,857 $ 87,299 $ 48,378 32,100 12,011 9,172 7,800 14,516 8,125 5,231 20,868 $158,201 16 Consolidated Statements of Income HELMERICH & PAYNE, INC. Years Ended September 30, 1995 1994 1993 (in thousands, except per share amounts) REVENUES: Sales and other operating revenues .................................... Income from investments .................................................. $314,930 10,846 $322,698 6,303 $306,047 9,050 COSTS AND EXPENSES: Operating costs .............................................................. Depreciation, depletion and amortization ............................. Dry holes and abandonments ............................................ Taxes, other than income taxes .......................................... General and administrative................................................ Interest ......................................................................... 325,776 329,001 315,097 200,240 77,115 10,096 15,408 8,801 407 213,427 50,068 10,369 15,545 8,908 385 194,856 48,609 6,893 13,763 6,820 925 312,067 298,702 271,866 INCOME BEFORE INCOME TAXES, EQUITY IN INCOME (LOSS) OF AFFILIATE AND CUMULATIVE EFFECT OF CHANGE IN ACCOUNTING PRINCIPLE ................................. 13,709 30,299 43,231 INCOME TAX EXPENSE .............................................................. 5,044 10,232 18,279 EQUITY IN INCOME (LOSS) OF AFFILIATE, net of income taxes ......................................................... 1,086 904 (402) INCOME BEFORE CUMULATIVE EFFECT OF CHANGE IN ACCOUNTING PRINCIPLE ..................................................... 9,751 20,971 24,550 CUMULATIVE EFFECT OF CHANGE IN ACCOUNTING PRINCIPLE ... 4,000 NET INCOME..................................................................... $ 9,751 $ 24,971 $ 24,550 PER COMMON SHARE: INCOME BEFORE CUMULATIVE EFFECT OF CHANGE IN ACCOUNTING PRINCIPLE ........................................................ $ .40 $ .86 $ 1.01 CUMULATIVE EFFECT OF CHANGE IN ACCOUNTING PRINCIPLE .... .16 NET INCOME..................................................................................... $ .40 $ 1.02 $ 1.01 AVERAGE COMMON SHARES OUTSTANDING ......................... 24,536 24,416 24,307 The accompanying notes are an integral part of these statements. 17 Consolidated Balance Sheets HELMERICH & PAYNE, INC. Assets CURRENT ASSETS: September 30, 1995 1994 (in thousands) Cash and cash equivalents.................................................................. $ 19,661 8,989 Short-term investments....................................................................... 59,314 Accounts receivable, less reserve of $489 and $1,480 .............................. 21,313 Inventories ....................................................................................... 5,717 Prepaid expenses and other ................................................................ 114,994 Total current assets ..................................................................... $ 29,447 8,997 59,897 20,995 3,603 122,939 INVESTMENTS..................................................................................... 156,908 87,414 PROPERTY, PLANT AND EQUIPMENT, at cost: Contract drilling equipment .................................................................. Oil and gas properties ........................................................................ Real estate properties ........................................................................ Other .............................................................................................. Less__Accumulated depreciation, depletion and amortization..................... 501,682 392,806 46,642 69,592 1,010,722 586,960 444,432 389,100 47,827 61,743 943,102 542,451 Net property, plant and equipment .................................................. 423,762 400,651 OTHER ASSETS ................................................................................... 14,501 13,823 TOTAL ASSETS .................................................................................... $ 710,165 $624,827 The accompanying notes are an integral part of these statements. 18 Liabilities and Shareholders’ Equity September 30, 1995 1994 (in thousands) CURRENT LIABILITIES: Accounts payable .............................................................................. Accrued liabilities .............................................................................. Notes payable................................................................................... Total current liabilities ................................................................ $ 26,382 21,529 21,700 69,611 $ 22,645 24,056 46,701 NONCURRENT LIABILITIES: Deferred income taxes........................................................................ Other .............................................................................................. Total noncurrent liabilities............................................................ 66,047 12,072 78,119 44,462 9,330 53,792 SHAREHOLDERS’ EQUITY: Common stock, $.10 par value, 80,000,000 shares authorized, 26,764,476 shares issued ................................................................ 2,677 2,677 Preferred stock, no par value, 1,000,000 shares authorized, no shares issued............................................................................ Additional paid-in capital ..................................................................... Net unrealized holding gains ................................................................ Retained earnings ............................................................................. Lesstreasury stock, 1,999,856 shares in 1995 and 2,054,364 shares in 1994, at cost ...... Total shareholders’ equity............................................................ 48,436 38,004 495,692 584,809 22,374 562,435 48,196 496,280 547,153 22,819 524,334 TOTAL LIABILITIES AND SHAREHOLDERS’ EQUITY .................................. $710,165 $624,827 The accompanying notes are an integral part of these statements. 19 Consolidated Statements of Shareholders’ Equity HELMERICH & PAYNE, INC. Additional Unrealized Net Common Stock Shares Amount Paid-In Capital Holding Gains Retained Earnings Treasury Stock Shares Amount (in thousands) Balance, September 30, 1992 ............. 26,764 $2,677 $46,764 $ Cash dividends ($.48 per share) ...... Exercise of stock options.................... Lapse of restrictions on Restricted Stock Awards ................................ Amortization of deferred compensation ............................... Net income ....................................... 888 (240) Balance, September 30, 1993 ............. 26,764 2,677 47,412 Cash dividends ($.49 per share) ...... Exercise of stock options ................... Lapse of restrictions on Restricted Stock Awards ................................ Stock issued under Restricted Stock Award Plan.......................... Amortization of deferred compensation ............................... Net income ....................................... 549 (246) 481 $467,954 (11,815) 2,188 $(24,109) (61) 542 1,716 24,550 482,405 (12,097) 2,127 (23,567) (43) 415 (814) (30) 333 1,815 24,971 Balance, September 30, 1994 ............. 26,764 2,677 48,196 496,280 2,054 (22,819) Adjustment to beginning balance for change in accounting method, net of income taxes of $21,106 ........... Change in net unrealized holding gains, net of income taxes of $2,187 Cash dividends ($.50 per share) ...... Exercise of stock options.................. Lapse of restrictions on Restricted Stock Awards ................................. Forfeiture of restricted stock award .. Amortization of deferred compensation ............................... Net income ...................................... 34,435 3,569 859 (229) (390) (12,372) (69) 615 560 15 (170) 1,473 9,751 Balance, September 30, 1995 ............. 26,764 $2,677 $48,436 $38,004 $495,692 2,000 $(22,374) The accompanying notes are an integral part of these statements. 20 Consolidated Statements of Cash Flows HELMERICH & PAYNE, INC. Years Ended September 30, 1995 1994 1993 (in thousands) CASH FLOWS FROM OPERATING ACTIVITIES: Net income ........................................................................ Adjustments to reconcile net income to net cash provided by operating activities- Depreciation, depletion and amortization........................... Dry holes and abandonments ......................................... Cumulative effect of change in accounting principle................ Equity in (income) loss of affiliate before income taxes ......... Amortization of deferred compensation ............................. Gain on sale of securities............................................... Gain on sale of fixed assets, other ................................... Change in assets and liabilities- (Increase) decrease in accounts receivable..................... Increase in inventories................................................ (Increase) decrease in prepaid expenses and other ............... Increase (decrease) in accounts payable........................ Increase (decrease) in accrued liabilities ........................ Increase (decrease) in deferred income taxes........................ Increase (decrease) in other noncurrent liabilities............. Total adjustments ...................................................... Net cash provided by operating activities..................... $ 9,751 $ 24,971 $ 24,550 77,115 10,096 (1,752) 1,473 (5,697) (1,115) 583 (318) (2,792) 2,675 (2,481) (1,708) 2,742 78,821 88,572 50,068 10,369 (4,000) (1,458) 1,815 (124) (2,465) (3,592) (3,349) 5,050 (1,191) 1,617 3,739 (1,541) 54,938 79,909 48,609 6,893 435 1,716 (2,914) (557) (13,486) (35) (492) 7,523 (1,619) 5,600 (1,604) 50,069 74,619 CASH FLOWS FROM INVESTING ACTIVITIES: Capital expenditures, including dry hole costs ........................... Proceeds from sale of property, plant and equipment .................. Purchase of investments....................................................... Proceeds from sale of investments.......................................... Purchase of short-term investments ........................................ Proceeds from sale of short-term investments ........................... (110,760) 2,923 (12,858) 11,713 7 (102,883) 5,971 (1,500) 373 (12) 124 (54,209) 4,801 (2,400) 7,904 (3,036) 7,055 Net cash used in investing activities............................ (108,975) (97,927) (39,885) CASH FLOWS FROM FINANCING ACTIVITIES: Proceeds from issuance of long-term debt................................ Payments made on long-term debt.......................................... Proceeds from notes payable................................................. Payments made on notes payable........................................... Dividends paid.................................................................... Proceeds from exercise of stock options................................... Net cash provided by (used in) financing activities ......... NET INCREASE (DECREASE) IN CASH AND CASH (3,139) 2,070 (2,180) (11,965) 913 (14,191) (11,808) 1,254 (10,664) 37,100 (15,400) (12,365) 1,282 10,617 EQUIVALENTS................................................................... CASH AND CASH EQUIVALENTS, beginning of period ................. CASH AND CASH EQUIVALENTS, end of period ......................... (9,786) 29,447 $ 19,661 (32,209) 61,656 $ 29,447 24,070 37,586 $ 61,656 The accompanying notes are an integral part of these statements. 21 Notes to Consolidated Financial Statements HELMERICH & PAYNE, INC. September 30, 1995,1994 and 1993 NOTE 1 SUMMARY OF ACCOUNTING POLICIES CONSOLIDATION - The consolidated financial statements include the accounts of Helmerich & Payne, Inc. (the Company), and all of its wholly-owned subsidiaries. Fiscal years of the Company’s foreign consolidated operations are August 31 to facilitate reporting of consolidated accounts. TRANSLATION OF FOREIGN CURRENCIES - The Company has determined that the functional currency for its foreign subsidiaries is the U.S. dollar. Foreign cur- rency transaction gain for 1995 was $1,845,000 with losses for the years 1994 and 1993 of $2,764,000, and $493,000, respectively. PROPERTY, PLANT AND EQUIPMENT - The Company follows the successful efforts method of accounting for oil and gas properties. Under this method, the Company capitalizes all costs to acquire mineral inter- ests in oil and gas properties, to drill and equip exploratory wells which find proved reserves and to drill and equip development wells. Geological and geophysical costs, delay rentals and costs to drill exploratory wells which do not find proved reserves are expensed. Capitalized costs of producing oil and gas properties are depreciated and depleted by the unit-of-production method based on proved developed oil and gas reserves determined by the Company and reviewed by independent engineers. Undeveloped leases are amortized based on management’s estimate of recoverability. Costs of surrendered leases are charged to the amortization reserve. Effective July 1, 1995, the Company adopted Statement of Financial Accounting Standards (SFAS) No. 121, “Accounting for the Impairment of Long-Lived Assets and for Long-Lived Assets to be Disposed Of”, which requires impairment losses to be recognized for long-lived assets used in operations when indicators of impairment are pre- sent and the undiscounted cash flows are not sufficient to recover the assets carrying amount. The impairment loss is measured by comparing the fair value of the asset to its carrying amount. Under the new statement, the Company now evaluates impairment of exploration and production assets on a field by field basis rather than using one world- wide cost center for its proved properties. Fair values are based on discounted future cash flows or information pro- vided by sales and purchases of similar assets. Substantially all other property, plant and equipment is depreciated using the straight-line method based on the following estimated useful lives: 22 YEARS Contract drilling equipment ............................................. 4-10 Chemical plant and equipment ....................................... 10-25 Real estate buildings and equipment.............................. 10-50 Other ............................................................................... 3-33 CASH AND CASH EQUIVALENTS - Cash and cash equivalents consist of cash in banks and investments readily convertible into cash which mature within three months from the date of purchase. INVENTORIES - Inventories, primarily materials and supplies, are valued at the lower of cost (moving average or actual) or market. DRILLING REVENUE - Substantially all drilling contracts are daywork contracts and drilling revenues and expenses are recognized as work progresses. GAS IMBALANCES - The Company recognizes revenues from gas wells on the sales method, and a liability is recorded for permanent imbalances. INVESTMENTS - Prior to October 1, 1994, investments in companies owned less than 20 percent were carried at the lower of cost or market. The Company adopted SFAS No. 115, “Accounting for Certain Investments in Debt and Equity Securities”, effective October 1, 1994. SFAS No. 115 requires that the Company’s investments in companies owned less than 20 percent, all of which are consid- ered available-for-sale securities, be carried at their fair value. Upon adoption of SFAS No. 115, the Company recorded an increase to shareholders’ equity of $34 million, which is net of income taxes of $21 million. The Company determines fair value of its investments in com- panies owned less than 20 percent based on quoted market prices. The cost of securities used in determining realized gains and losses is based on average cost of the security sold. Investments in companies owned from 20 to 50 percent are accounted for using the equity method with the Company recog- nizing its proportionate share of the income or loss of each investee. The Company owned 24.14 percent and 24.3 percent of Atwood Oceanics, Inc. (Atwood) at September 30, 1995 and 1994, respectively. The quoted market value of the Company’s investment was $32,100,000 and $22,800,000 at September 30, 1995 and 1994, respectively. Retained earnings at September 30, 1995 include approximately $10,315,000 of undistributed earnings of Atwood. At September 30, 1995, the Company also had invest- ed $8.3 million in a joint venture with Atwood to build and operate a new generation offshore platform drilling rig, which is currently under construction. The Company has a receivable from Atwood of $2.2 million related to the construction of the drilling rig. Summarized financial information of Atwood is as follows: Gross revenues .............................................................. Costs and expenses ........................................................ Net income ( loss) ........................................................... Helmerich & Payne, Inc.’s equity in net income (loss) of affiliates, net of income taxes ............................ Current assets ................................................................ Noncurrent assets ........................................................... Current liabilities ............................................................. Noncurrent liabilities ........................................................ Shareholders’ equity ........................................................ Helmerich & Payne, Inc.’s investment................................... 1995 $ 77,315 (70,255) $ 7,060 $ 1,086 $ 34,266 118,587 20,505 37,456 94,892 $ 22,495 1994 (in thousands) $ 68,045 (62,045) $ 6,000 $ 904 $ 37,965 115,065 13,752 53,000 86,278 $ 20,743 1993 $ 54,219 (56,010) $ (1,791) $ (402) $ 27,903 122,356 11,900 58,609 79,750 $ 19,285 INCOME TAXES - Effective October 1, 1993, the Company adopted FASB Statement No. 109, “Accounting for Income Taxes.” Under Statement No. 109, deferred income taxes are computed using the liability method and are provided on all temporary differences between the financial basis and the tax basis of assets and liabilities. For the year ended September 30, 1993, deferred income taxes are computed using the deferred method and are provided on timing differences between financial and taxable income. OTHER POST EMPLOYMENT BENEFITS - The Company provides medical benefits to employees who retired before November 1, 1992. The Company does not provide any other benefits to these retirees. The liability for the benefits provided is not material. Effective October 1, 1995, the Company offered medical benefits to employees who retired after November 1, 1992, with retirees to pay the entire estimated cost of such benefits. The Company has accrued a liability for estimated workers compensation claims incurred. The liability for other benefits to former or inactive employees after employment but before retirement is not material. EARNINGS PER SHARE - Earnings per share are based on the weighted average number of shares of common stock outstanding during the year. Common stock equivalents are insignificant, and therefore, have not been considered in the earnings per share computation. NOTE 2 SHORT-TERM BORROWINGS AND CREDIT ARRANGEMENTS The Company maintains a line of credit agreement with certain banks which provides for maximum borrowing of $75,000,000 at adjustable interest rates. Under the agreement, $75,000,000 may be borrowed through May 1996, and $45,000,000 may be bor- rowed through May 1998. As of September 30, 1995, the Company had borrowed $21,700,000 at a weighted average interest rate of 7.27%, leaving an unused portion of $53,300,000. Under the line of credit agreement, the Company must meet certain requirements regarding levels of debt, net worth and earnings. The Company has an additional $8.5 million uncommitted line of credit with a bank which can be used primarily for letters of credit. 23 NOTE 3 INCOME TAXES Effective October 1, 1993, the Company changed its method of accounting for income taxes from the deferred method to the liability method required by FASB Statement No. 109, “Accounting for Income Taxes.” The cumulative effect of adopting Statement No. 109 as of October 1, 1993 was to increase net income by $4,000,000. As permitted under the new rules, prior years financial statements have not been restated. The components of the provision for income taxes are as follows: Years Ended September 30, 1995 1993 1994 (in thousands) CURRENT: Federal . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ 1,102 6,442 Foreign . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 370 State . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 7,914 DEFERRED: Federal . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Foreign . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . State . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . TOTAL PROVISION: The amounts of domestic and foreign income are as follows: (3,155) 534 (249) (2,870) $ 5,044 $ $ 3,645 2,763 777 7,185 (292) 3,430 (91) 3,047 10,232 $ $ 6,190 5,106 911 12,207 3,174 2,616 282 6,072 18,279 Years Ended September 30, 1995 1994 (in thousands) 1993 INCOME BEFORE INCOME TAXES, EQUITY IN INCOME (LOSS) OF AFFILIATE, AND CUMULATIVE EFFECT OF CHANGE IN ACCOUNTING PRINCIPLE: Domestic . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ (5,816) 19,525 Foreign . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ 13,709 $ $ 17,513 12,786 30,299 $ $ 29,051 14,180 43,231 Effective income tax rates as compared to the U.S. Federal income tax rate are as follows: Years Ended September 30, 1995 1994 1993 U.S. Federal income tax rate . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Dividends received deduction . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Excess statutory depletion . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Effect of higher foreign tax rates . . . . . . . . . . . . . . . . . . . . . . . . . . . Non-conventional fuel source credits utilized . . . . . . . . . . . . . . . . . Other, net . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Effective income tax rate . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 35% (4) (2) 11 (5) 2 37% 35% (2) (1) 3 (1) - 34% 35% (1) (1) 7 - 2 42% The components of the Company’s net deferred tax liabilities are as follows: 1995 Years Ended September 30, 1994 (in thousands) DEFERRED TAX LIABILITIES: Property, plant and equipment Available-for-sale securities Pension provision Equity Investment Other Total deferred tax liabilities DEFERRED TAX ASSETS: Financial accruals Other Total deferred tax assets Valuation allowance Net deferred tax assets NET DEFERRED TAX LIABILITIES 24 $ 40,702 23,293 4,774 3,920 846 73,535 5,376 2,112 7,488 7,488 $ 66,047 $ 42,406 4,632 3,254 744 51,036 4,419 2,155 6,574 6,574 $ 44,462 The deferred income tax provision (benefit) for 1993 results from timing differences in the recognition of revenue and expense for income tax and financial reporting purposes. The sources of these differences and the related income tax effect of each, are as follows: Year Ended September 30, 1993 (in thousands) Effect of intangible development costs expensed for income tax purposes over (under) costs amortized for financial reporting purposes Financial under income tax depreciation ..................... Pension income ........................................................... Geophysical expense................................................... Insurance expense ...................................................... Amortization of deferred compensation ....................... Restricted stock options vesting .................................. Deferred mobilization revenues ................................... Sales of long-term investments ................................... Excess depletion.......................................................... Oil and gas revenue recognition timing differences ..... Other............................................................................ $ 1,302 2,134 128 (51) (36) (652) 609 566 484 589 262 737 $ 6,072 NOTE 4 STOCK OPTIONS, AWARD PLAN AND RIGHTS The Company has reserved 1,361,681 shares of its treasury stock to satisfy the exercise of stock options issued under the 1982 and 1990 Stock Option Plans. Options awarded under these plans are granted at prices equal to at least market price on the date of grant. Options granted under the 1982 plan have a term of nine years while options granted under the 1990 plan have a term of seven years. Options granted under both plans become exercisable in increments as outlined in the plans. Activity for the incentive stock option plans, was as follows: Years Ended September 30, Outstanding at October 1, ................................................ Granted............................................................................. Exercised.......................................................................... Cancelled ......................................................................... Outstanding at September 30, ......................................... Exercisable at September 30, .......................................... Weighted average exercise price of options outstanding . Weighted average exercise price of options exercised..... 1995 835,879 107,750 (78,094) (24,264) 841,271 110,399 $ 26.39 $ 19.68 1994 780,079 110,250 (46,510) (7,940) 835,879 70,889 $ 25.65 $ 21.77 1993 860,713 __ (67,112) (13,522) 780,079 19,782 $ 25.20 $ 21.53 As of September 30, 1995, the Company has issued 360,000 shares of treasury stock under a Restricted Stock Award Plan (the “Plan”). The Company recognized deferred compensation totalling $12,832,000, which was the fair market value of the stock at the time of issuance, as a reduction of retained earnings. The deferred compensation is being amortized over a seven-year period as compensation expense. The unamortized balance at September 30, 1995 and 1994 was $3,189,000 and $5,223,000, respectively. In 1995, 1994, and 1993, restrictions lapsed with respect to 61,000 shares, and the shares were released to Plan participants. In 1995 there was a forfeiture of 15,000 shares. On September 30, 1995, the Company had 24,764,620 outstanding common stock purchase rights (“Rights”). Each Right entitles the holder thereof, until January 8, 1996, to buy one share of common stock at an exercise price of $60.00. The exercise price and the number of shares of common stock issuable upon the exercise of the Rights are subject to adjustment in certain cases to prevent dilution. The Rights are evidenced by the common stock certificates and are not exercisable or transferable apart from the common stock, until 15 days after a person acquires 15 percent or more of the common stock. In the event the Company is acquired in a merger or other business combination transaction (including one in which the Company is the surviving corporation), it is provided that each Right will entitle its holder to purchase, at the then current exercise price of the Right, that number of shares of common stock of the surviving company, which at the time of such transaction, would have a market value of two times the exercise price of the Right. The Rights do not have any voting rights and are redeemable, at the option of the Company, at a price of $.05 per Right prior to any person or entity acquiring beneficial ownership of at least 15 percent of the common stock. The Rights expire on January 8, 1996. As long as the Rights are not separately transferable, the Company will issue one Right with each new share of common stock issued. NOTE 5 FINANCIAL INSTRUMENTS Short-term investments consist mainly of U.S. treasury notes carried at cost, which approximates fair value, and are pledged as collateral for a renewable letter of credit. Notes payable bear interest at market rates and is carried at cost which approximates fair value. The following is a summary of available-for-sale securities, which excludes those accounted for under the equity method of accounting (see Note 1): Gross Gross Estimated Unrealized Unrealized Fair Cost Gains Losses Value (in thousands) Equity Securities, September 30, 1995 $64,804 $61,455 $158 $126,101 25 During the years ended September 30, 1995, 1994, and 1993, marketable equity available-for-sale securities with a fair value at the date of sale of $11,713,000, $373,000 and $7,904,000, respectively, were sold. The gross realized gains on such sales of available-for-sale securities totaled $5,734,000, $124,000, and $3,579,000, respectively, and the gross realized losses totaled $37,000, $0, and $665,000, respectively. NOTE 6 IMPAIRMENT OF LONG-LIVED ASSETS Adoption of SFAS No. 121, effective July 1, 1995, resulted in a before-tax charge of $22 million which is included in depreciation, depletion and amortization expense. The charge reduced 1995 after-tax net income by $13.6 million, or $.55 per share. The before-tax charges included $20 million for proved Exploration and Production properties and $2 million for Real Estate proper- ties. The fair values of the proved properties were determined using the present value of expected future net cash flows. The fair values of the impaired real estate properties were determined based on the estimated sales price of comparable assets. NOTE 7 EMPLOYEE BENEFIT PLANS Defined Benefit Plans: The Company has noncontributory pension plans covering substantially all of its employees, including certain employees in foreign countries. The Company makes annual contributions to the plans equal to the maximum amount allowable for tax reporting purposes. Future service benefits are determined using a 1.5 percent career average formula. The net periodic pension credit included the following components: Years Ended September 30, 1995 Service cost-benefits earned during the year .......................... Interest cost on projected benefit obligations .......................... Return on plan assets.............................................................. Net amortization and deferral .................................................. Net pension credit ........................................................... $ 1,589 1,301 (2,798) (301) $ (209) 1994 (in thousands) $ 1,557 1,191 (2,639) (302) $ (193) 1993 $ 1,304 1,105 (522) (2,477) $ (590) The discount rate used in determining the actuarial value of the projected benefit obligation for 1995, 1994 and 1993 was 7.25%, 7.5% and 7.0%, respectively. The average expected rate of return on plan assets was 8.5% for 1995, 1994 and 1993. The assumed rate of increase in compensation was 5.0% for 1995 and 1994, and 5.5% for 1993. The following table sets forth the plans’ funded status and amounts recognized in the balance sheet: Years Ended September 30, 1995 1994 (in thousands) Actuarial present value of benefit obligations: Vested benefit obligation .................................................................... Accumulated benefit obligation .......................................................... Projected benefit obligation................................................................ $ 16,199 $ 19,215 $ 21,735 $ 13,323 $ 15,758 $ 17,755 Plan assets at fair value, primarily listed stocks, U.S. Government securities and guaranteed insurance contracts ................................. $ 38,114 $ 33,317 Projected benefit obligation less than plan assets ..................................... Unrecognized net gain, including unrecognized net assets existing at October 1, 1987............................................... Unrecognized prior service cost ................................................................. Prepaid pension cost.................................................................................. $ 16,379 $ 15,562 (5,959) 1,978 $ 12,398 (5,589) 2,216 $ 12,189 Defined Contribution Plan: Substantially all employees on the United States payroll of the Company may elect to participate in the Company sponsored Thrift/401(k) Plan by contributing a portion of their earnings. The Company contributes amounts equal to 100 percent of the first five percent of the participant’s compensation subject to certain limitations. Expensed Company contributions were $1,735,000, $1,588,000 and $1,304,000 in 1995, 1994 and 1993, respectively. 26 NOTE 8 ACCRUED LIABILITIES Accrued liabilities consist of the following: Years Ended September 30, 1995 1994 Accrued royalties payable........................................................................... Accrued taxes payable ............................................................................... Accrued workers compensation claims ..................................................... Accrued equipment cost............................................................................. Other accrued liabilities .............................................................................. (in thousands) $ 5,977 3,109 2,430 4,017 5,996 $ 21,529 $ 6,293 4,669 2,364 3,000 7,730 $ 24,056 NOTE 9 CONCENTRATIONS OF CREDIT RISK Years Ended September 30, 1995 1994 1993 Cash payments: Interest paid ............................................................................ Income taxes paid.................................................................... $ 408 4,624 (in thousands) $ 371 9,516 Noncash investing activity: Accrued equipment cost ..................................................... $ 1,016 $ 3,000 370 15,924 $ $ NOTE 10 CONCENTRATIONS OF CREDIT RISK Financial instruments which potentially subject the Company to concentrations of credit risk consist primarily of temporary cash investments and trade receivables. The Company places its temporary cash investments with high credit financial institutions and limits the amount of credit exposure to any one financial institution. The Company’s trade receivables are primarily with a variety of companies in the oil and gas industry. Management requires collateral for certain receivables of customers in its natural gas marketing operations. NOTE 11 SEGMENT INFORMATION The Company operates principally in the contract drilling and oil and gas industries. The contract drilling operations consist of contracting Company-owned drilling equipment primarily to major oil and gas exploration companies. Oil and gas activities con- sist of ownership of mineral interests in productive oil and gas leases and undeveloped leases located primarily in Oklahoma, Texas, Kansas and Louisiana. Intersegment sales, which are accounted for in the same manner as sales to unaffiliated cus- tomers, are not material. Operating profit is total revenue less operating expenses. In computing operating profit, the following items have not been considered: equity in earnings of Atwood Oceanics, Inc.; income from investments; general corporate expenses; interest expense; and domestic and foreign income taxes. Identifiable assets by segment are those assets that are used in the Company’s operations in each segment. Corporate assets are principally cash and cash equivalents, short-term investments and investments in marketable securities. Revenues from one company doing business with the contract drilling segment accounted for approximately 18 percent, 14 per- cent, and 11.8 percent of the total consolidated revenues during the years ended September 30, 1995, 1994 and 1993, respec- tively. Collectively, revenues from three companies controlled by the Venezuelan government accounted for approximately 13.4 percent of total consolidated revenues for the year ended September 30, 1995. Summarized revenues and operating profit by industry segment for the years ended September 30, 1995, 1994 and 1993 are located on page 11. Additional financial information by industry segment is as follows: 27 Years Ended September 30, 1995 1994 1993 Identifiable assets: Contract drilling - Domestic .................................................. Contract drilling - International ............................................. Exploration and Production .................................................. Natural Gas Marketing ......................................................... Chemical division ................................................................. Real Estate division ............................................................. Corporate and other............................................................. Depreciation, depletion and amortization: Contract drilling - Domestic .................................................. Contract drilling - International ............................................. Exploration and Production .................................................. Natural Gas Marketing ......................................................... Chemical division ................................................................. Real Estate division ............................................................. Corporate and other............................................................. Intersegment elimination ...................................................... Capital expenditures: Contract drilling - Domestic .................................................. Contract drilling - International ............................................. Exploration and Production .................................................. Natural Gas Marketing ......................................................... Chemical division ................................................................. Real Estate division ............................................................. Corporate and other............................................................. $138,359 188,587 142,184 10,192 9,822 24,380 196,641 $710,165 $ 12,213 19,557 39,895 298 672 3,623 959 (102) $ 77,115 $ 32,503 55,044 20,956 252 859 907 1,255 $111,776 (in thousands) $132,804 131,767 175,003 8,846 9,532 26,958 139,917 $624,827 $ 11,085 15,722 19,523 290 654 1,624 1,265 (95) $ 50,068 $ 31,692 25,723 45,809 76 619 916 1,048 $105,883 $112,435 113,844 162,618 13,289 9,753 27,845 171,151 $610,935 $ 10,126 16,929 18,294 279 594 1,679 864 (156) $ 48,609 $ 16,261 10,375 25,551 205 630 458 729 $ 54,209 NOTE 12 SUPPLEMENTARY FINANCIAL INFORMATION FOR OIL AND GAS PRODUCING ACTIVITIES All of the Company’s oil and gas producing activities are located in the United States. Results of Operations from Oil and Gas Producing Activities - Years Ended September 30, 1995 1994 1993 Revenues ............................................................................ Production costs .................................................................. Exploration expense and valuation provisions ....................... Depreciation, depletion and amortization .............................. Income tax expense ............................................................. Total cost and expenses.................................................... Results of operations (excluding corporate overhead $ 47,986 18,035 14,017 39,895 (7,243) 64,704 and interest costs) ............................................................ $(16,718) (in thousands) $58,884 18,854 17,262 19,523 890 56,529 $ 2,355 $69,795 19,378 12,628 18,294 6,481 56,781 $13,014 Capitalized Costs - At September 30, 1995 1994 (in thousands) Properties being amortized: Proved properties ................................................................................................. Unproved properties ............................................................................................. Total costs being amortized .............................................................................. Accumulated depreciation, depletion and amortization........................................ Net Capitalized Costs ....................................................................................... $384,755 8,051 392,806 257,988 $134,818 $377,371 11,729 389,100 225,902 $163,198 28 Costs Incurred Relating to Oil and Gas Producing Activities - Years Ended September 30, 1995 1994 1993 (in thousands) Property acquisition: Proved ............................................................................. Unproved.......................................................................... Exploration........................................................................... Development........................................................................ Total.............................................................................. $ 1,228 1,565 13,497 9,703 $25,993 $23,115 4,893 12,418 12,888 $53,314 $ 3,100 2,409 11,769 13,964 $31,242 Estimated Quantities of Proved Oil and Gas Reserves (Unaudited) - Proved reserves are estimated quantities of crude oil, natural gas, and natural gas liquids which geological and engineering data demon- strate with reasonable certainty to be recoverable in future years from known reservoirs under existing economic and operating conditions. Proved developed reserves are those which are expected to be recovered through existing wells with existing equipment and operating methods. The following is an analysis of proved oil and gas reserves as estimated by the Company and reviewed by independent engineers. OIL (Bbls.) GAS (Mmcf) Proved reserves at September 30, 1992 ................................................................... Revisions of previous estimates ................................................................................ Extensions, discoveries and other additions.............................................................. Production.................................................................................................................. Purchases of reserves-in-place ................................................................................. Sales of reserves-in-place ......................................................................................... Proved reserves at September 30, 1993 ................................................................... Revisions of previous estimates ................................................................................ Extensions, discoveries and other additions.............................................................. Production.................................................................................................................. Purchases of reserves-in-place ................................................................................. Sales of reserves-in-place ......................................................................................... Proved reserves at September 30, 1994 ................................................................... Revisions of previous estimates ................................................................................ Extensions, discoveries and other additions.............................................................. Production.................................................................................................................. Purchases of reserves-in-place ................................................................................. Sales of reserves-in-place ......................................................................................... 7,507,586 (15,550) 168,051 (875,713) 140,411 (41,586) 6,883,199 302,200 261,114 (887,455) 159,580 (8,427) 6,710,211 124,361 328,539 (808,058) 310 (26,251) 294,596 9,568 10,083 (28,479) 4,196 (519) 289,445 (819) 8,818 (26,628) 19,900 (64) 290,652 5,222 8,775 (26,421) 1,934 (116) Proved reserves at September 30, 1995 ................................................................... 6,329,112 280,046 Proved developed reserves at September 30, 1993............................................................................................... September 30, 1994............................................................................................... September 30, 1995............................................................................................... 6,882,783 6,649,672 6,270,216 282,033 267,688 262,319 Standardized Measure of Discounted Future Net Cash Flows Relating to Proved Oil and Gas Reserves (Unaudited) - The “Standardized Measure of Discounted Future Net Cash Flows Relating to Proved Oil and Gas Reserves” (Standardized Measure) is a disclosure requirement under Financial Accounting Standards Board Statement No. 69. The Standardized Measure does not purport to present the fair market value of a company’s proved oil and gas reserves. This would require consideration of expected future economic and operating conditions, which are not taken into account in calculating the Standardized Measure. Under the Standardized Measure, future cash inflows were estimated by applying year-end prices to the estimated future produc- tion of year-end proved reserves. Future cash inflows were reduced by estimated future production and development costs based on year-end costs to determine pre-tax cash inflows. Future income taxes were computed by applying the statutory tax rate to the excess of pre-tax cash inflows over the Company’s tax basis in the associated proved oil and gas properties. Tax credits and per- manent differences were also considered in the future income tax calculation. Future net cash inflows after income taxes were dis- counted using a ten percent annual discount rate to arrive at the Standardized Measure. 29 At September 30, 1995 1994 Future cash inflows .................................................................................................... Future costs - Future production and development costs ............................................................ Future income tax expense ................................................................................... Future net cash flows................................................................................................. 10% annual discount for estimated timing of cash flows ........................................... Standardized Measure of discounted future net cash flows ...................................... (in thousands) $429,259 $478,426 (173,633) (63,183) 192,443 (81,509) $110,934 (191,464) (71,320) 215,642 (91,019) $124,623 Changes in Standardized Measure Relating to Proved Oil and Gas Reserves (Unaudited) _ Years Ended September 30, 1995 1994 1993 Standardized Measure - Beginning of year............................ Increases (decreases) - Sales, net of production costs ............................................ Net change in sales prices, net of production costs ........... Discoveries and extensions, net of related future development and production costs................................. Changes in estimated future development costs ............... Development costs incurred ............................................... Revisions of previous quantity estimates ........................... Accretion of discount .......................................................... Net change in income taxes ............................................... Purchases of reserves-in-place.......................................... Sales of reserves-in-place.................................................. Other .................................................................................. Standardized Measure - End of year ..................................... $124,623 (29,951) (12,917) 8,179 (4,672) 9,703 2,825 16,171 (7,538) 1,202 (51) 3,360 $110,934 (in thousands) $178,757 (40,030) (80,347) 9,653 (14,571) 12,888 483 23,678 20,942 11,219 (62) 2,013 $124,623 $173,644 (50,417) 16,292 12,439 (7,624) 13,964 6,820 22,619 (12,656) 3,820 (652) 508 $178,757 NOTE 13 SELECTED QUARTERLY FINANCIAL DATA (UNAUDITED) Quarter Ended Dec. 31, March 31, June 30, Sept. 30, 1994 1995 1995 1995 (in thousands, except per share amounts) Revenues ............................................................................. Gross profit (loss) .................................................................. Net income (loss)1 ................................................................. Earnings (loss) per share....................................................... $79,944 8,909 4,416 .18 $79,301 11,550 5,820 .24 $78,756 9,389 4,584 .19 $87,775 (6,931) (5,069) (.21) Quarter Ended Dec. 31, March 31, June 30, Sept. 30, 1993 1994 1994 1994 (in thousands, except per share amounts) Revenues ............................................................................... Gross profit ............................................................................ Income before cumulative effect of change in accounting principle........................................................ Net income 2 .......................................................................... Earnings per common share before cumulative effect of change in accounting principle ............................. Earnings per share ................................................................ $82,186 14,149 7,253 11,253 .30 .46 $87,883 12,701 $78,698 8,688 $80,234 4,054 6,155 6,155 .25 .25 4,660 4,660 .19 .19 2,903 2,903 .12 .12 Gross profit (loss) represents total revenues less operating costs, depreciation, depletion and amortization, dry holes and abandon- ments, and taxes, other than income taxes. 1 The quarter ended September 30, 1995 included an after-tax charge of $13.6 million ($.55 per share) related to the Company adopting SFAS No. 121 (see note 6). 2 The quarter ended September 30, 1994 included an after-tax charge of $2.7 million ($.11 per share) for impairment of leases ($1.35 million) and dry-hole costs ($1.35 million) in the Austin Chalk prospect in Louisiana. 30 Report of Independent Auditors HELMERICH & PAYNE, INC. The Board of Directors and Shareholders Helmerich & Payne, Inc. We have audited the accompanying consolidated balance sheets of Helmerich & Payne, Inc. as of September 30, 1995 and 1994, and the related consolidated state- ments of income, shareholders’ equity, and cash flows for the years then ended. These financial statements are the responsibility of the Company’s management. Our responsibility is to express an opinion on these financial statements based on our audits. The consolidated statements of income, shareholders’ equity, and cash flows for the year ended September 30, 1993, were audited by other auditors whose report dated November 16, 1993, expressed an unqualified opinion on those statements. We conducted our audits in accordance with generally accepted auditing standards. Those standards require that we plan and perform the audit to obtain reasonable assurance about whether the financial statements are free of material misstatement. An audit includes examining, on a test basis, evidence supporting the amounts and disclosures in the financial statements. An audit also includes assessing the accounting principles used and significant estimates made by management, as well as evaluating the overall financial statement presentation. We believe that our audits provide a reasonable basis for our opinion. In our opinion, the 1995 and 1994 financial statements referred to above present fairly, in all material respects, the consolidated financial position of Helmerich & Payne, Inc. at September 30, 1995 and 1994, and the consolidated results of its oper- ations and its cash flows for the years then ended, in conformity with generally accepted accounting principles. As discussed in Note 6 to the financial statements, effective July 1, 1995, the Company adopted Statement of Financial Accounting Standards (SFAS) No. 121, “Accounting for the Impairment of Long-Lived Assets and for Long-Lived Assets to be Disposed Of”. As discussed in Note 1 to the financial statements, effective October 1, 1994, the Company adopted SFAS No., 115, “Accounting for Cer tain Investments in Debt and Equity Securities.” As discussed in Note 3 to the financial statements, effective October 1, 1993, the Company adopted SFAS No. 109, “Accounting for Income Taxes.” Tulsa, Oklahoma November 17, 1995 Stock Price Information Closing Market Price Per Share 1995 1994 QUARTERS HIGH LOW HIGH First .................................................. Second ............................................. Third ................................................. Fourth............................................... $ 311/4 271/2 31 30 $ 255/8 $ 341/2 241/2 30 265/8 27 5/8 271/8 281/8 LOW $261/2 26 251/8 255/8 Dividend Information QUARTERS Paid Per Share Total Payment 1995 1994 1995 1994 First .................................................. $.125 $.120 .120 Second .............................................. .125 .120 .125 Third ................................................. .125 Fourth................................................ .125 $3,089,758 3,087,958 3,092,973 3,094,813 $2,956,498 2,960,098 2,960,314 3,087,902 STOCKHOLDERS’ MEETING The annual meeting of stockholders will be held on March 6, 1996. A formal notice of the meet- ing, together with a proxy statement and form of proxy, will be mailed to shareholders on or about January 25, 1996. STOCK EXCHANGE LISTING Helmerich & Payne, Inc. Common Stock is traded on the New York Stock Exchange with the ticker symbol “HP.” The newspaper abbreviation most commonly used for financial reporting is “HelmP.” Options on the Company’s stock are also traded on the New York Stock Exchange. STOCK TRANSFER AGENT AND REGISTRAR As of Decemer 15, 1995, there were 1,656 record holders of Helmerich & Payne, Inc. com- mon stock as listed by the transfer agent’s records. Our Transfer Agent is responsible for our share- holder records, issuance of stock certificates, and distribution of our dividends and the IRS Form 1099. Your requests, as shareholders, concerning these matters are most efficiently answered by corresponding directly with The Liberty Bank of Oklahoma City at the following address: The Liberty National Bank and Trust Company of Oklahoma City Stock Transfer Department P.O. Box 25848 Oklahoma City, Oklahoma 73125-0848 Telephone: (405) 231-6325 FORM 10-K The Company’s Annual Report on Form 10-K, which has been submitted to the Securities and Exchange Commission, is available free of charge upon written request. DIRECT INQUIRIES TO: President Helmerich & Payne, Inc. Utica at Twenty- First Tulsa, Oklahoma 74114 Telephone: (918) 742-5531 31 Eleven-Year Financial Review HELMERICH & PAYNE, INC. Years Ended September 30, 1995 1994 1993 REVENUES AND INCOME* Contract Drilling Revenues............................................................... Crude Oil Sales ................................................................................ Natural Gas Sales ............................................................................ Gas Marketing Revenues** .............................................................. Chemical Sales ................................................................................ Real Estate Revenues...................................................................... Dividend Income .............................................................................. Other Revenues ............................................................................... Total Revenues................................................................................. Net Cash Provided by Operating Activities†† .................................. Net Income†..................................................................................... 203,325 13,227 33,851 34,729 18,986 7,560 3,389 10,709 325,776 88,572 9,751 182,781 13,161 45,261 51,874 18,746 7,396 3,621 6,161 329,001 79,909 24,971 149,661 15,392 52,446 63,786 14,286 7,620 3,535 8,371 315,097 74,619 24,550 PER SHARE DATA Net Income†..................................................................................... Cash Dividends ................................................................................ Shares Outstanding* ........................................................................ .40 .50 24,765 1.02 .485 24,710 1.01 .48 24,637 FINANCIAL POSITION Net Working Capital* ........................................................................ Ratio of Current Assets to Current Liabilities ................................... Investments*..................................................................................... Total Assets* .................................................................................... Long-Term Debt* .............................................................................. Shareholders’ Equity*....................................................................... 45,383 1.65 156,908 710,165 76,238 2.63 87,414 624,827 562,435 524,334 CAPITAL EXPENDITURES* Contract Drilling Equipment ............................................................. Wells and Equipment ....................................................................... Chemical Plant and Equipment........................................................ Real Estate....................................................................................... Other Assets (includes undeveloped leases) ................................... Total Capital Outlays ........................................................................ 80,943 19,384 793 873 9,783 111,776 PROPERTY, PLANT AND EQUIPMENT AT COST* 501,682 Contract Drilling Equipment ............................................................. 384,755 Producing Properties ....................................................................... 8,051 Undeveloped Leases........................................................................ 13,210 Chemical Plant and Equipment........................................................ 46,642 Real Estate....................................................................................... 56,382 Other ................................................................................................ Total Property, Plant and Equipment................................................ 1,010,722 53,752 40,916 572 902 9,741 105,883 444,432 377,371 11,729 12,417 47,827 49,326 943,102 104,085 3.24 84,945 610,935 3,600 508,927 24,101 23,142 540 436 5,990 54,209 418,004 340,176 10,010 11,845 47,502 45,785 873,322 * 000’s omitted ** Gas Marketing activities began in 1990 †† Funds generated by operations for 1985 † Includes $13.6 million (.55 per share) effect of impairment charge for adoption of SFAS No. 121 in 1995 and cumulative effect of change in accounting for income taxes of $4,000,000 ($.16 per share) in 1994 32 1992 1991 1990 1989 1988 1987 1986 1985 112,833 16,369 38,370 40,410 13,411 7,541 4,050 6,716 239,700 63,331 10,849 105,364 17,374 35,628 10,055 12,674 7,542 5,285 20,024 213,946 52,110 21,241 90,974 16,058 37,697 10,566 12,067 7,636 7,402 56,144 238,544 55,422 47,562 78,315 14,821 33,013 __ 10,754 7,778 9,127 17,361 171,169 67,099 22,700 75,985 14,001 26,154 __ 11,265 7,878 10,069 15,213 160,565 57,967 20,150 64,718 15,223 17,251 __ 9,603 7,561 9,757 34,766 158,879 38,337 22,016 68,220 20,020 21,308 __ 8,471 6,839 11,033 29,244 165,135 54,756 7,025 90,647 32,447 28,335 __ 8,778 5,658 10,878 18,054 194,797 72,552 18,498 .45 .465 24,576 .88 .46 24,488 1.97 .44 24,485 .94 .42 24,173 .83 .40 24,166 .91 .38 24,187 .28 .36 24,187 .74 .35 25,146 82,800 3.31 87,780 585,504 8,339 493,286 43,049 21,617 104 690 17,038 82,498 404,155 329,264 12,973 11,305 47,286 43,810 848,793 108,212 4.19 96,471 575,168 5,693 491,133 56,297 34,741 2,478 2,104 6,909 102,529 370,494 312,438 5,552 11,202 46,671 37,059 783,416 146,741 3.72 99,574 582,927 5,648 479,485 18,303 16,489 1,089 1,467 5,512 42,860 324,293 287,248 5,507 8,723 44,928 32,682 703,381 114,357 3.12 130,443 591,229 49,087 443,396 17,901 30,673 745 878 6,787 56,984 323,313 279,768 5,441 7,635 48,016 30,237 694,410 135,275 6.10 133,726 576,473 70,715 430,804 19,110 25,936 688 3,095 2,623 51,452 313,289 251,445 3,305 6,889 47,165 28,279 650,372 135,139 6.68 140,431 571,348 74,732 420,833 13,993 27,402 307 6,128 2,041 49,871 309,865 228,214 4,197 6,201 44,070 28,675 621,222 108,331 5.61 158,311 563,236 79,340 408,185 23,673 11,767 232 1,409 2,075 39,156 307,199 215,488 7,294 5,894 38,131 28,846 602,852 118,340 4.58 163,045 616,034 85,532 427,860 27,777 9,527 175 9,782 5,397 52,658 287,641 218,102 10,403 5,662 36,538 28,345 586,691 33 Eleven-Year Operating Review HELMERICH & PAYNE, INC. Years Ended September 30, 1995 1994 1993 CONTRACT DRILLING Drilling Rigs, United States ................................................................ Drilling Rigs, International.................................................................. Contract Wells Drilled, United States................................................. Total Footage Drilled, United States* ................................................. Average Depth per Well, United States ............................................. Percentage Rig Utilization, United States .......................................... Percentage Rig Utilization, International............................................ 41 35 212 1,933 9,119 71 84 47 29 162 1,842 11,367 69 88 42 29 128 1,504 11,746 53 68 PETROLEUM EXPLORATION AND DEVELOPMENT Gross Wells Completed ..................................................................... Net Wells Completed ......................................................................... Net Dry Holes .................................................................................... 59 27.4 5.9 44 15 1.7 42 15.9 4.3 PETROLEUM PRODUCTION Net Crude Oil and Natural Gas Liquids Produced (barrels daily)................................................................ Net Oil Wells Owned — Primary Recovery........................................ Net Oil Wells Owned — Secondary Recovery................................... Secondary Oil Recovery Projects ...................................................... Net Natural Gas Produced (thousands of cubic feet daily) ...................................................... Net Gas Wells Owned........................................................................ 2,214 186 64 12 72,387 354 2,431 202 71 14 72,953 341 2,399 202 71 14 78,023 307 NATURAL GAS ODORANTS AND OTHER CHEMICALS Chemicals Sold (pounds)* ................................................................. 7,670 8,071 7,930 REAL ESTATE MANAGEMENT Gross Leasable Area (square feet)* .................................................. Percentage Occupancy...................................................................... 1,652 87 1,652 83 1,656 86 TOTAL NUMBER OF EMPLOYEES Helmerich & Payne, Inc. and Subsidiaries† ....................................... 3,245 2,787 2,389 * 000’s omitted. † 1985-1989 include U.S. employees only 34 1992 1991 1990 1989 1988 1987 1986 1985 39 30 100 1,085 10,853 42 69 46 25 106 1,301 12,274 47 69 49 20 119 1,316 11,059 50 46 49 20 108 1,350 12,500 44 46 48 18 115 1,284 11,165 45 30 50 19 110 1,182 10,745 39 16 48 19 110 1,384 12,582 44 30 47 19 111 1,477 13,306 65 47 54 17.8 4.3 45 20.3 4.3 36 15.3 3.4 45 15.2 2.8 45 14.6 1.6 18 5.2 .5 27 10.3 3.6 42 19.5 9.7 2,334 220 74 14 75,470 289 2,152 227 55 12 66,617 278 2,265 223 46 12 65,147 194 2,486 201 214 17 57,490 205 2,463 202 222 21 45,480 197 2,578 199 237 20 31,752 180 3,077 234 235 18 32,392 180 3,388 234 259 19 35,288 174 8,452 8,155 8,255 7,702 8,507 8,165 7,554 9,123 1,656 87 1,664 86 1,664 85 1,669 90 1,670 90 1,595 94 1,433 95 1,333 93 1,928 1,758 1,864 1,100 1,156 1,026 844 1,126 35 Directors Officers W. H. Helmerich, III Chairman of the Board Hans Helmerich President and Chief Executive Officer Allen S. Braumiller Vice President, Exploration George S. Dotson Vice President, President of Helmerich & Payne International Drilling Co. Douglas E. Fears Vice President, Finance Steven R. Mackey Vice President, Secretary, and General Counsel James L. Payne Vice President, Real Estate Steven R. Shaw Vice President, Production W. H. Helmerich, III Chairman of the Board, Tulsa, Oklahoma Hans Helmerich President and Chief Executive Officer, Tulsa, Oklahoma William L. Armstrong Chairman, Ambassador Media Corporation, Denver, Colorado Glenn A. Cox* President and Chief Operating Officer, Retired, Phillips Petroleum Co., Bartlesville, Oklahoma George S. Dotson Vice President, President of Helmerich & Payne International Drilling Co., Tulsa, Oklahoma C. W. Flint, Jr.* Chairman, Flint Industries, Inc., Tulsa, Oklahoma George A. Schaefer Chairman and Chief Executive Officer, Retired, Caterpillar Inc., Peoria, Illinois Harry W. Todd Chairman, CEO, and President, Retired, Rohr Industries, Inc., Chula Vista, California John D. Zeglis Senior Vice President and General Counsel, American Telephone & Telegraph Co., Basking Ridge, New Jersey *Member, Audit Committee 36 Five-Year Production Review Years Ended September 30, 1993 1992 1991 Barrels 1990 1989 OIL AND LIQUIDS Annual Production ................................ 007,854,124 007,074,405 008,826,843 008,907,289 006,299,410 2,463 $15.54 6,299,410 Per Day Production ........................... Average Price per Barrel ...................... Year-end Proved Reserves .................. 2,486 $16.34 8,618,850 2,265 $19.42 8,102,761 2,334 $19.16 7,507,586 2,152 $22.12 7,074,405 NATURAL GAS Annual Production ................................ 16,600,054 Per Day Production ........................... 45,480 Average Price per Mcf ......................... $1.44 Year-end Proved Reserves .................. 294,596,000 296,229,000 279,923,000 291,630,000 279,562,000 20,983,983 57,490 $1.48 24,310,155 66,617 $1.35 27,622,018 75,470 $1.39 23,778,690 65,147 $1.48 Thousand Cubic Feet (mcf) Financial Highlights Years Ended September 30, 1993 (in thousands) Gross Revenues ............................................................... Pre-Tax Income ................................................................ Depreciation Expense....................................................... Capital Expenditures ......................................................... Year-end Book Value ........................................................ Average Occupancy ......................................................... $ 7,550 4,074 1,685 697 28,234 87% 1992 $ 7,558 3,722 1,633 2,190 29,194 86% Financial Highlights Years Ended September 30, 1993 1992 (in thousands) 1991 Gross Revenues ................................................................................. Pre-Tax Income .................................................................................. Non-Cash Charges......................................................................... Capital Expenditures .......................................................................... Pounds of Product Sold .................................................................. $ 7,550 4,074 1,685 697 28,234 $ 7,558 3,722 1,633 2,190 29,194 Summary of Property Owned Property Name Utica Square Shopping Center Utica Square Offices and Medical Center Plaza Office Building Space Center Space Center East Tandem Business Park Tulsa Business Park Maxim Center Maxim Place Southpark/100 East Industrial Park Description Square Feet Upscale Retail Professional Offices Corporate Offices Industrial Warehouses Industrial Warehouses Office/Warehouse Complex Office/Warehouse Complex Office/Warehouse Complex Office/Warehouse Complex Undeveloped 260 Acres Total Square Feet 406,260 94,969 90,156 495,000 202,500 88,084 204,600 40,800 33,750 1,656,119 37 Stock Portfolio Held by the Company September 30, 1993 Number of Shares Carrying Amount on Balance Sheet Market Value at End of Fiscal Year (in thousands,except share amounts) Schlumberger, Ltd.................................................... Atwood Oceanics, Inc...................................................... Sun Company, Inc. .......................................................... Phillips Petroleum Company. ........................................... Liberty Bancorp............................................................... Oryx Energy Company .................................................... Oneok............................................................................. Other .............................................................................. Total.................................................................... 740,000 1,600,000 907,164 300,000 500,000 700,000 225,000 $ 23,511 19,285 10,637 7,470 7,270 6,683 2,751 7,338 $ 84,945 $ 49,303 17,200 25,854 10,125 17,000 17,150 5,006 10,737 $152,375 On November 11, 1993 approximately 1,000 plaintiffs filed a lawsuit one of the Company’s subsidiaries, alleging person- al injury and property damage arising out of the operation of the subsidiary’s facility. The plaintiffs allege that the sub- sidiary released dangerous chemicals and waste into the air and ground water and are seeking actual damages of $500 million and punitive damages of $500 billion. This lawsuit is one of three lawsuits filed simultaneously. A similar lawsuit has been filed against another company and a class action lawsuit was filed against virtually every chemical plant and oil refinery in the area. Management believes that the lawsuit is without merit and that the ultimate monetary exposure is not material to the financial statements because they believe that the Company has complied in all material respects with applicable laws and regulations. The Company is also a defendant in other litigation arising out of operations in the normal course of business. In the opinion of management, after taking into account existing legal reserves, none of the various other pending lawsuits and proceedings should have a material adverse effect upon the consolidated financial position or results of opera- tions of the Company. 38 

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