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Table of Contents
UNITED STATES
SECURITIES AND EXCHANGE COMMISSION
Washington, D.C. 20549
FORM 10-K
ANNUAL REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934
For the fiscal year ended September 30, 2021
OR
TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934
For the transition period from              to            
Commission file number 1-4221
HP-20210930_G1.JPG
HELMERICH & PAYNE, INC.
(Exact name of registrant as specified in its charter)
Delaware 73-0679879
(State or other jurisdiction of incorporation or organization) (I.R.S. Employer Identification No.)

1437 South Boulder Avenue, Suite 1400, Tulsa, Oklahoma 74119
(Address of principal executive offices) (Zip Code)
(918) 742-5531
(Registrant’s telephone number, including area code)
N/A
(Former name, former address and former fiscal year,
if changed since last report)
Securities registered pursuant to Section 12(b) of the Act:
Title of each class Trading symbol(s) Name of each exchange on which registered
Common Stock ($0.10 par value) HP New York Stock Exchange
Securities registered pursuant to Section 12(g) of the Act: None
Indicate by check mark if the Registrant is a well-known seasoned issuer, as defined in Rule 405 of the Securities Act. Yes ☒  No ☐
Indicate by check mark if the Registrant is not required to file reports pursuant to Section 13 or Section 15(d) of the Act. Yes ☐  No ☒
Indicate by check mark whether the Registrant (1) has filed all reports required to be filed by Section 13 or 15(d) of the Securities Exchange Act of 1934 during the preceding 12 months (or for such shorter period that the Registrant was required to file such reports), and (2) has been subject to such filing requirements for the past 90 days. Yes ☒  No ☐
Indicate by check mark whether the Registrant has submitted electronically every Interactive Data File required to be submitted pursuant to Rule 405 of Regulation S-T (§ 232.405 of this chapter) during the preceding 12 months (or for such shorter period that the registrant was required to submit such files). Yes ☒  No ☐
Indicate by check mark whether the Registrant is a large accelerated filer, an accelerated filer, a non‑accelerated filer, a smaller reporting company, or an emerging growth company. See the definitions of “large accelerated filer,” “accelerated filer,” “smaller reporting company,” and “emerging growth company” in Rule 12b‑2 of the Exchange Act.
Large accelerated filer Accelerated filer  Non‑accelerated filer 
Smaller reporting company Emerging Growth Company 
If an emerging growth company, indicate by check mark if the registrant has elected not to use the extended transition period for complying with any new or revised financial accounting standards provided pursuant to Section 13(a) of the Exchange Act. ☐
Indicate by check mark whether the Registrant has filed a report on and attestation to its management’s assessment of the effectiveness of its internal control over financial reporting under Section 404(b) of the Sarbanes-Oxley Act (15 U.S.C. 7262(b)) by the registered public accounting firm that prepared or issued its audit report. ☒
Indicate by check mark whether the Registrant is a shell company (as defined in Rule 12b‑2 of the Exchange Act). Yes ☐  No ☒
At March 31, 2021, the last business day of the Registrant’s most recently completed second fiscal quarter, the aggregate market value of the Registrant’s common stock held by non‑affiliates was approximately $2.91 billion based on the closing price of such stock on the New York Stock Exchange on such date of $26.96.
Number of shares of common stock outstanding at November 8, 2021: 108,002,263
Portions of the Registrant’s 2022 Proxy Statement for the Annual Meeting of Stockholders to be held in calendar year 2022 are incorporated by reference into Part III of this Form 10‑K. The 2022 Proxy Statement will be filed with the U.S. Securities and Exchange Commission within 120 days after the end of the fiscal year to which this Form 10‑K relates.


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HELMERICH & PAYNE, INC.
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INDEX TO FORM 10‑K
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HP-20210930_G1.JPG 2021 FORM 10-K | 2

Table of Contents
Cautionary Note Regarding Forward-Looking Statements
This Annual Report on Form 10‑K (“Form 10‑K”) contains forward-looking statements within the meaning of Section 27A of the Securities Act of 1933, as amended (the “Securities Act”), and Section 21E of the Securities and Exchange Act of 1934, as amended (the “Exchange Act”). All statements other than statements of historical facts included in this Form 10-K, including without limitation, statements regarding our future financial position, business strategy, budgets, projected costs and plans and objectives of management for future operations, are forward-looking statements. In addition, forward-looking statements generally can be identified by the use of forward-looking terminology such as “may,” “will,” “expect,” “intend,” “estimate,” “anticipate,” “believe,” “predict,” “project,” “target,” “continue,” or the negative thereof or similar terminology. Forward-looking statements are based upon current plans, estimates, and expectations that are subject to risks, uncertainties, and assumptions. Although we believe that the expectations reflected in such forward-looking statements are reasonable, we can give no assurance that such expectations will prove to be correct. Actual results may vary materially from those indicated or anticipated by such forward-looking statements. The inclusion of such statements should not be regarded as a representation that such plans, estimates, or expectations will be achieved.

These forward-looking statements include, among others, such things as:
our business strategy;
estimates of our revenues, income, earnings per share, and market share;
our capital structure and our ability to return cash to stockholders through dividends or share repurchases;
the amount and nature of our future capital expenditures and how we expect to fund our capital expenditures;
the volatility of future oil and natural gas prices;
the effects of actions by, or disputes among or between, members of the Organization of Petroleum Exporting Countries (“OPEC”) and other oil producing nations (together, “OPEC+”) with respect to production levels or other matters related to the prices of oil and natural gas;
changes in future levels of drilling activity and capital expenditures by our customers, whether as a result of global capital markets and liquidity, changes in prices of oil and natural gas or otherwise, which may cause us to idle or stack additional rigs, or increase our capital expenditures and the construction or acquisition of rigs;
the effect, impact, potential duration or other implications of the novel strain of coronavirus ("COVID-19") pandemic, the ongoing recovery from and response to the oil price collapse in 2020, and any expectations we may have with respect thereto;
changes in worldwide rig supply and demand, competition, or technology;
possible cancellation, suspension, renegotiation or termination (with or without cause) of our contracts as a result of general or industry-specific economic conditions, mechanical difficulties, performance or other reasons;
expansion and growth of our business and operations;
our belief that the final outcome of our legal proceedings will not materially affect our financial results;
impact of federal and state legislative and regulatory actions and policies, affecting our costs and increasing operation restrictions or delay and other adverse impacts on our business;
environmental or other liabilities, risks, damages or losses, whether related to storms or hurricanes (including wreckage or debris removal), collisions, grounding, blowouts, fires, explosions, other accidents, terrorism or otherwise, for which insurance coverage and contractual indemnities may be insufficient, unenforceable or otherwise unavailable;
our financial condition and liquidity;
tax matters, including our effective tax rates, tax positions, results of audits, changes in tax laws, treaties and regulations, tax assessments and liabilities for taxes;
potential long-lived asset impairments; and
our sustainability strategy.
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Important factors that could cause actual results to differ materially from our expectations or results discussed in the forward‑looking statements are disclosed in this Form 10‑K under Item 1A— “Risk Factors” and Item 7— “Management’s Discussion and Analysis of Financial Condition and Results of Operations.” All subsequent written and oral forward‑looking statements attributable to us, or persons acting on our behalf, are expressly qualified in their entirety by such cautionary statements. Because of the underlying risks and uncertainties, we caution you against placing undue reliance on these forward-looking statements. We assume no duty to update or revise these forward‑looking statements based on changes in internal estimates, expectations or otherwise, except as required by law.
Risk Factors Summary

This summary briefly lists the principal risks and uncertainties facing our business, which are only a select portion of those risks. A more complete discussion of those risks and uncertainties is set forth in this Form 10‑K under Item 1A— “Risk Factors.” Additional risks not presently known to us or that we currently deem immaterial may also affect us. If any of these risks occur, our business, financial condition or results of operations could be materially and adversely affected. Our business is subject to the following principal risks and uncertainties:

Business and Operating Risks

the impact and effects of public health crises, pandemics and epidemics, such as the COVID-19 pandemic;
the level of activity in the oil and natural gas industry;
the drilling services and solutions business is highly competitive;
new technologies may cause our drilling methods and equipment to become less competitive;
our drilling and technology related operations are subject to a number of operational risks, and we are not fully insured against all of these risks;
cybersecurity risks;
risks associated with our acquisitions, dispositions and investments;
our reliance on management and competition for experienced personnel;
the effect of the loss of one or a number of our large customers;
our current backlog of drilling services and solutions revenue may not be ultimately realized;
risks associated with our contracts with national oil companies;
our dependence on a limited number of vendors;
shortages of drilling equipment and supplies;
unionization efforts and labor regulations in certain countries in which we operate;
the effect of improvements in or new discoveries of alternative technologies;
risks associated with doing business in certain foreign countries;
Financial Risks

covenants in our debt agreements restrict our ability to engage in certain activities;
we may be required to record impairment charges with respect to our drilling rigs and other assets;
the impact of a downgrade in our credit ratings;
our ability to access capital markets could be limited;
our inability to generate cash to service all of our indebtedness;
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Legal and Regulatory Risks

the impact of the regulation of greenhouse gases and climate change;
the impact of new legislation and regulatory initiatives related to hydraulic fracturing or other aspects of the oil and gas industry;
failure to comply with the U.S. Foreign Corrupt Practices Act or foreign anti-bribery legislation;
complex and evolving laws and regulations regarding privacy and data protection;
government policies, mandates and regulations specifically affecting the energy sector and related industries;
the impact of legal claims and litigation;
the effect of additional tax liabilities, limitations on our use of net operating losses and tax credits and/or our significant net deferred tax liability;
failure to comply with or changes to governmental and environmental laws;
Risks Related to Our Common Stock and Corporate Structure

we may reduce or suspend our dividend in the future;
the market price of our common stock may be highly volatile; and
certain provisions of our corporate governing documents could make an acquisition of our company more difficult; and
the effect of public and investor sentiment towards climate change, fossil fuels and other environmental, social and governance ("ESG") matters on the price of our common stock
PART I
ITEM 1. BUSINESS
Overview
Helmerich & Payne, Inc. ("H&P," which, together with its subsidiaries, is identified as the “Company,” “we,” “us” or “our,” except where stated or the context requires otherwise) was incorporated under the laws of the State of Delaware on February 3, 1940 and is successor to a business originally organized in 1920. We provide performance-driven drilling solutions that are intended to make hydrocarbon recovery safer and more economical for oil and gas exploration and production companies. We are an important vendor for a number of oil and gas exploration and production companies, but we focus primarily on the drilling segment of the oil and gas production value chain. Our technology services focus on developing, promoting and commercializing technologies designed to improve the efficiency and accuracy of drilling operations, as well as wellbore quality and placement.
Our global business is composed of three reportable business segments: North America Solutions, Offshore Gulf of Mexico, and International Solutions.  During the fiscal year ended September 30, 2021, our North America Solutions operations were primarily located in Colorado, Louisiana, Montana, Nevada, New Mexico, North Dakota, Ohio, Oklahoma, Pennsylvania, Texas, Utah, West Virginia and Wyoming. Our Offshore Gulf of Mexico operations were conducted in Louisiana and in U.S. federal waters in the Gulf of Mexico. Our International Solutions operations had rigs located in four international locations during fiscal year 2021: Argentina, Bahrain, Colombia and United Arab Emirates (“U.A.E.”).
We also own and operate a limited number of commercial real estate properties located in Tulsa, Oklahoma. Our real estate investments include a shopping center containing approximately 390,000 leasable square feet and approximately 176 acres of undeveloped real estate. Our research and development endeavors include both internal development and external acquisition of developing technologies. Our wholly-owned captive insurance companies (the “Captives”) are used to insure the deductibles for our workers’ compensation, general liability and automobile liability insurance programs. The Company and the Captives maintain excess property and casualty reinsurance programs with third-party insurers in an effort to limit the financial impact of significant events covered under these programs. Our real estate operations, our incubator program for new research and development projects, and our wholly-owned captive insurance companies are included in "Other."
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Drilling Fleet

The following map shows the number of working rigs by basin in our North America Solutions reportable segment as of September 30, 2021:
HP-20210930_G3.JPG
The following table sets forth certain information concerning our North America Solutions drilling rigs as of September 30, 2021:
  HP-20210930_G2.JPG NORTH AMERICA SOLUTIONS FLEET
Location
Super-Spec FlexRig®1
Non Super-Spec FlexRig®2
Total Fleet
Total Available Rigs Contracted Total Available Rigs Contracted Total Available Rigs Contracted
TX 139 66 3 142 66
NM 36 26 36 26
OK 25 10 1 26 10
ND 8 6 8 6
LA 5 5 5 5
OH 4 1 4 1
PA 4 2 4 2
UT 3 3 3 3
CO 1 1 2 2 3 3
WV 2 2 2 2
MT 1 1 1 1
NV 1 1 1 1
WY 1 1 1 1
Totals 230 125 6 2 236 127
(1)AC drive, minimum of 1,500 horsepower drawworks, minimum of 750,000 lbs. hookload rating, 7,500 psi mud circulating system, and multiple-well pad capability.
(2)AC drive, 1,500 horsepower drawworks, 500,000 or 750,000 lbs. hookload rating, 5,000 or 7,500 psi mud circulating system, may or may not have multiple-well pad capability.
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The following table sets forth certain information concerning our Offshore Gulf of Mexico drilling rigs as of September 30, 2021:
HP-20210930_G2.JPG OFFSHORE GULF OF MEXICO FLEET
Location
Shallow Water1
Deep Water1
Total Fleet
Total Available Rigs Contracted Total Available Rigs Contracted Total Available Rigs Contracted
Louisiana2
3 3
Gulf of Mexico 1 1 3 3 4 4
Totals 4 1 3 3 7 4
(1)Deep water rigs operate on floating facilities and shallow water rigs operate on fixed facilities.
(2)Rigs are idle, stacked on land and not in state waters.

The following table sets forth certain information concerning our International Solutions drilling rigs as of September 30, 2021:
HP-20210930_G2.JPG INTERNATIONAL SOLUTIONS FLEET
Location
AC (FlexRig® 3)1
AC (FlexRig® 4)2
Other AC
SCR3
Total Fleet
Total Available Rigs Contracted Total Available Rigs Contracted Total Available Rigs Contracted Total Available Rigs Contracted Total Available Rigs Contracted
Argentina 12 3 4 4 20 3
Colombia 2 2 1 2 7
Bahrain 3 3 3 3
Totals 14 3 9 3 1 6 30 6
(1)Other than four super–spec rigs in Argentina, the FlexRig® 3 is equipped with an AC drive, 1,500 horsepower drawworks, and a 750,000 lb. hookload rating. It can be equipped with an optional skid or walking system, third mud pump, and 7,500 psi high pressure mud system. The other eight rigs in Argentina are equipped with skid systems.
(2)The FlexRig® 4 model has a small footprint and is designed to be highly mobile. The rig is equipped with a 300,000 lb. mast, 400HP top drive and two mud pumps. Range 3 drill pipe is used without setback. The rig is capable of horizontal and vertical drilling, but is primarily used for vertical drilling.
(3)A silicon-controlled-rectifier (“SCR”) system converts alternate current (“AC”) produced by one or more AC generator sets into direct current (“DC”). Of the six SCR rigs, one is equipped with 2,100 horsepower drawworks and the remaining five are equipped with 3,000 horsepower drawworks to drill deep conventional wells.
Drilling Services and Solutions
General
We are the largest provider of super-spec AC drive land rigs in the Western Hemisphere. Operating principally in North and South America, we specialize in shale and unconventional resource plays, drilling challenging and complex wells in oil and gas producing basins in the United States and in international locations. In the United States, we have a diverse mix of customers consisting of large independent, major, mid-sized and small cap oil companies and private independent companies (including private equity-backed companies) that are primarily focused on unconventional shale basins. In South America and the Middle East, our customers primarily include major international and national oil companies.
We did not have any individual customers that represented 10% or more of our total consolidated revenues in fiscal years 2021, 2020, or 2019.
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The following table presents our average active rigs per day (a measure of activity and utilization over the fiscal year) and average utilization for the fiscal years 2021, 2020, and 2019:
Year Ended September 30,
North America Solutions Offshore Gulf of Mexico International Solutions
2021
2020
2019
2021
2020
2019
2021
2020
2019
Average active rigs per day1
107.4    134.3  224.1    4.3    5.3    5.9    5.0    12.6    17.6 
Average utilization2
43  % 47  % 67  % 59  % 66  % 74  % 16  % 40  % 55  %
(1)Includes the impact of downsizing our fleet and/or rigs that have been reclassified to assets held-for-sale. See Note 4—Property, Plant and Equipment to our Consolidated Financial Statements.
(2)A rig is considered to be utilized when it is operating (or otherwise deployed for a customer) or being moved, assembled or dismantled pursuant to a drilling contract, or stacked under contract.
Our Segments
North America Solutions Segment
We believe we operate the largest and most technologically advanced AC drive drilling rig fleet in North America and have a presence in most of the U.S. shale and unconventional basins. We have the leading market share in at least three of the most active oil basins, which include the Permian Basin, Eagle Ford Shale, and Woodford Shale. Nearly all of our active rigs are drilling horizontal or directional wells. As of September 30, 2021, we had approximately 22 percent of the total market share in U.S. land drilling and approximately 32 percent of the super-spec market share in U.S. land drilling. In the United States, we have the industry's largest super-spec fleet with 230 rigs, of which 125 were under contract at September 30, 2021. In total, 127 of our 236 marketed rigs were under contract, 73 were under fixed‑term contracts, and 54 were working well-to-well as of September 30, 2021.
Our drilling technology within this segment enables a solutions-based approach that provides performance-driven drilling services designed to help deliver greater levels of accuracy, consistency, optimization and a reduction of human error to create higher quality wellbores with lower overall risk. This technology is intended to address our customers' unique challenges and should result in less wellbore tortuosity and reduce positional uncertainty in the directional drilling process.
Our North America Solutions segment contributed approximately 84.2 percent ($1.0 billion) of our consolidated operating revenues during fiscal year 2021, compared to approximately 83.1 percent ($1.5 billion) and 86.7 percent ($2.4 billion) of our consolidated operating revenues during fiscal years 2020 and 2019, respectively. In North America, our customers are primarily from the major integrated oil companies, large independent oil companies, small cap oil companies and private independent companies (including private equity-backed companies). Revenue from drilling services performed for our largest North America Solutions drilling customer totaled approximately 11.5 percent ($118.4 million) of the North America Solutions segment revenues during fiscal year 2021.
Offshore Gulf of Mexico Segment
Our Offshore Gulf of Mexico segment has been in operation since 1968 and currently consists of seven platform rigs in the Gulf of Mexico. We supply the rig equipment and crews and the operator, who owns the platform, will typically provide production equipment or other necessary facilities. Our offshore rig fleet operates on conventional fixed leg platforms and floating platforms attached to the sea floor with mooring lines, such as Spars and Tension Leg Platforms. Additionally, we provide management contract services to customer platforms where the customer owns the drilling rig.
As of September 30, 2021, four of the seven offshore rigs were under contract. Our Offshore Gulf of Mexico operations contributed approximately 10.4 percent ($126.4 million) of our consolidated operating revenues during fiscal year 2021, compared to approximately 8.1 percent ($143.1 million) and 5.3 percent ($147.6 million) of our consolidated operating revenues during fiscal years 2020 and 2019, respectively. Revenues from drilling services performed for our largest offshore drilling customer totaled approximately 77.9 percent ($98.4 million) of offshore revenues during fiscal year 2021.
International Solutions Segment
Our International Solutions segment primarily conducts operations in Argentina, Colombia, Bahrain and U.A.E. As of September 30, 2021, we had six land rigs contracted for work in locations outside of the United States. Our International Solutions operations contributed approximately 4.8 percent ($57.9 million) of our consolidated operating revenues during fiscal year 2021, compared to approximately 8.1 percent ($144.2 million) and 7.6 percent ($211.7 million) of our consolidated operating revenues during fiscal years 2020 and 2019, respectively.
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Argentina As of September 30, 2021, we had 20 rigs in Argentina. Revenues generated by Argentine drilling operations contributed approximately 2.3 percent ($27.9 million) of our consolidated operating revenues during fiscal year 2021 compared to approximately 4.8 percent ($84.4 million) and 5.9 percent ($165.7 million) of our consolidated operating revenues during fiscal years 2020 and 2019, respectively. Revenues from drilling services performed for our two largest customers in Argentina totaled approximately 2.2 percent of our consolidated operating revenues and approximately 45.2 percent of our international operating revenues during fiscal year 2021. The Argentine drilling contracts are primarily with large international or national oil companies.
Colombia As of September 30, 2021, we had seven rigs in Colombia. Revenues generated by Colombian drilling operations contributed approximately 0.1 percent ($1.7 million) of our consolidated operating revenues in fiscal year 2021, compared to approximately 0.4 percent ($6.4 million) and 1.1 percent ($29.8 million) of our consolidated operating revenues during fiscal years 2020 and 2019, respectively. Revenues from drilling services performed for our two largest customers in Colombia totaled approximately 0.1 percent of our consolidated operating revenues and approximately 2.9 percent of our international operating revenues during fiscal year 2021. The Colombian drilling contracts are primarily with large international or national oil companies.
Bahrain As of September 30, 2021, we had three rigs in Bahrain.  Revenues generated by Bahrain drilling operations contributed approximately 2.3 percent ($27.4 million) of our consolidated operating revenues in fiscal year 2021, compared to approximately 1.6 percent ($28.7 million) and 0.4 percent ($11.5 million) of our consolidated operating revenues during fiscal years 2020 and 2019, respectively.  All of our revenues in Bahrain are from a partner of the local national oil company.
United Arab Emirates In September 2021, we sold two rigs we had in country as part of a larger rig package sale to ADNOC Drilling Company P.J.S.C. As a result of this transaction, we did not have any rigs located in the U.A.E. as of September 30, 2021. See Item 7— “Management’s Discussion and Analysis of Financial Condition and Results of Operations — Recent Developments” and Note 4—Property, Plant and Equipment to our Consolidated Financial Statements included in this Form 10‑K for additional information. Prior to the sale, revenues generated by our U.A.E. drilling operations contributed approximately 0.1 percent ($1.0 million) of our consolidated operating revenues in fiscal year 2021, compared to approximately 1.4 percent ($24.7 million) and 0.2 percent ($4.7 million) of our consolidated operating revenues during fiscal years 2020 and 2019, respectively. All of our revenues in U.A.E. are from a subsidiary of the national oil company.
Other Operations
Other Operations include additional non-reportable operating segments.  We own and operate a limited number of commercial real estate properties located in Tulsa, Oklahoma. Our real estate investments include a shopping center and undeveloped real estate.
On October 1, 2019, we elected to utilize the Captives to insure the deductibles for our workers’ compensation, general liability and automobile liability insurance programs. Casualty claims occurring prior to October 1, 2019 will remain recorded within each of the operating segments and future adjustments to these claims will continue to be reflected within the operating segments. Reserves for legacy claims occurring prior to October 1, 2019, will remain as liabilities in our operating segments until they have been resolved. Changes in those reserves will be reflected in segment earnings as they occur. We will continue to utilize the Captives to finance the risk of loss to equipment and rig property assets. The Company and the Captives maintain excess property and casualty reinsurance programs with third-party insurers in an effort to limit the financial impact of significant events covered under these programs. Our operating subsidiaries are paying premiums to the Captives, typically on a monthly basis, for the estimated losses based on the external actuarial analysis. These premiums are currently held in a restricted cash account, resulting in a transfer of risk from our operating subsidiaries to the Captives. Starting in the second quarter of fiscal year 2020, the Captives' insurer issued a stop-loss program that will reimburse the Company's health plan for claims that exceed $50,000. The Company did not previously purchase any stop-loss coverage.
During fiscal year 2019, the Company established an incubator program for new research and development projects, the results of which have been included in "Other" within our segment disclosures.
Rigs, Equipment, R&D, and Facilities
During the late 1990’s, we undertook a strategic initiative to develop a new generation drilling rig that would be the safest, fastest-moving and highest performing rig in the land drilling market. Our first FlexRig® drilling rig entered the market in 1998. We continued to innovate and in 2002 introduced our first AC drive rigs, which incorporated new drilling technology and improved safety and environmental design. These rigs found immediate success by delivering higher value wells to the customer and marked the beginning of the AC land rig revolution.
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We also changed our pricing and contracting strategy, and beginning in 2005, predominantly all new FlexRig® drilling rigs were built supported by a firm contract and attractive returns. To date, we have built over 200 FlexRig® rigs that align with this strategy. An important part of our strategy was to design a rig that could support continuous improvement through upgrade capability of the hardware and software on the rigs to take advantage of technology improvements and lengthening the industry rig replacement cycle. These upgrades included, but were not limited to, enhanced drilling control systems and software, skid and walking systems for drilling multiple well pads, 7,500 psi mud systems, set back capacity to accommodate the pipe that the longer laterals demanded, and additional mud system capacity.
In 2011, we introduced a FlexRig® design for long lateral drilling of multiple wells from a single location and for drilling horizontally in unconventional shale reservoirs. The new design preserved the key performance features of earlier designs but added a bi-directional skidding system and equipment capacities suitable for drilling long lateral wells.
In 2016, we saw the further progression of longer lateral wells, which brought additional technical challenges. At that time, we began delivering rigs to the market that were equipped and capable of drilling these longer lateral wells. The industry would later refer to these rigs as super-spec rigs, which have the following specific characteristics: AC drive, minimum 1,500 horsepower drawworks, minimum of 750,000 lbs. hookload rating, 7,500 psi mud circulating system, and multiple-well pad capability. Additionally, our competency in design and construction as well as our financial strength enabled us to efficiently upgrade our other existing rigs to super-spec, resulting in what we believe to be the largest fleet of super-spec rigs in the world. As of September 30, 2021, we had 230 super-spec rigs.
In 2017, we introduced our first walking rig by reconfiguring some of our uni-directional skid designed FlexRig® drilling rigs. Since then, we have reconfigured, converted, and upgraded a total of 49 FlexRig® drilling rigs to super-spec walking rigs.
Years of designing and building our fleet of AC drive FlexRig® drilling rigs has given us many competitive benefits. One key advantage is fleet uniformity. We have overseen the design and assembly of all of our AC FlexRig® drilling rigs, and our different rig classes share many common components.  We co-designed the control systems for our rigs and have the right to make any changes or modifications to those systems that we desire. A uniform fleet creates an adaptive environment to reach maximum efficiency for employees, equipment and technology and is critical to our ability to provide consistent, safe and reliable operations in increasingly complex basins. In addition, our fleet has greater scale than any other competitor, which enables us to upgrade our existing FlexRig® drilling rigs to super-spec in a capital efficient way. High levels of uniformity in crew training and rotation and our ability to control and remove safety exposures across a more standard fleet allow us to deliver higher performance in a safer and more reliable manner for the customer. Further, our fleet is supported by a cost-effective Company-owned supply chain that provides standardized materials directly to the rigs from our regional warehouses.
A long-standing challenge in our industry is providing high quality and consistent results. In addressing this challenge, we utilize process excellence techniques that are developed internally. We provide experienced drilling and maintenance support for our operations, which provides value by reducing nonproductive time in our operations and improving drilling performance through our Rig Systems Monitoring and Support Center (“RSMS”) and Remote Operations Centers ("ROCs"). Our RSMS and ROCs are manned 24 hours a day, seven days a week, with the ability to monitor and detect trends in drilling and drilling services performance onboard our rigs. Our monitoring group within the RSMS provides real-time help and feedback to our wellsite employees, as well as our customers, to fully optimize our operational performance. Additionally, our RSMS and ROCs have staffs of engineers and industry experts that work with our customers to enhance wellbore positioning, drilling program execution and overall drilling performance. The monitoring group and our performance engineers capture our drilling work steps to help provide high quality and reliable results for our customers.
We currently have two facilities that provide vertically integrated solutions for drilling rig manufacturing, upgrades, retrofits and modifications, as well as overhauling, recertification, and repairs as it relates to our rigs and equipment. These facilities utilize lean manufacturing processes to enhance quality and efficiency as well as provide important insights in the maintenance and wear of equipment on our rigs. Our facility located in Galena Park, Texas is primarily utilized for overall rig assembly, overhaul, recommissioning and recertification while our facility near Tulsa, Oklahoma is primarily utilized for modular rig component overhauls and repairs.
During fiscal year 2021, we continued to see adoption and growth with our technologically enabled automation solutions. We designed our automation solutions to address challenges within our customers’ businesses as much of the drilling process is heavily dependent on human decision making to design, execute and optimize crude oil and natural gas extraction. Utilizing these technologies, we are able to deploy a more science-based solution compared to human decisions and execution, thereby reducing variability and the costs around achieving optimal outcomes. These solutions continue to provide differentiated value for our customers through enhanced wellbore quality and placement, improved cost performance and well economics, and better consistency at reduced risk. Our automation focused solutions and applications are enabled by our uniform digital fleet and are designed to provide additional value to our customers' well programs by providing a platform for machine-human collaboration during the drilling process to improve efficiency. Our path to autonomous drilling continues to evolve with several solutions in various stages of commercial testing. All of our technologies play an important role in developing our strategy as we head towards autonomous drilling.
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We have historically offered ancillary services, which are now referred to as FlexServices®. These services include trucking, surface equipment, casing running services and pipe rental. Subsequent to September 30, 2021, we sold the assets associated with two lower margin service offerings, trucking and casing running services, which contributed approximately 2.8 percent to our consolidated revenues during fiscal year 2021, in two separate transactions. The sale of our trucking services was completed on November 3, 2021 while the sale of our casing running services was completed on November 15, 2021 for combined cash consideration less costs to sell of $5.8 million in addition to the possibility of future earnout revenue.
Markets and Competition
Our business largely depends on the level of capital spending by oil and gas companies for exploration and production activities. The level of capital spending is correlated to oil and gas prices. Oil and gas prices can be volatile at times depending upon both near and long-term supply and demand factors. Sustained increases or decreases in the prices of oil and natural gas generally have a material impact on the exploration and production activities of our customers. As such, significant declines in the prices of oil and natural gas may have a material adverse effect on our business, financial condition and results of operations.  As of September 30, 2021, we had 137 rigs under contract, compared to 79 and 218 rigs under contract as of September 30, 2020 and 2019, respectively. For further information concerning risks associated with our business, including volatility surrounding oil and natural gas prices and the impact of low oil prices on our business, see Item 1A— “Risk Factors” and Item 7— “Management’s Discussion and Analysis of Financial Condition and Results of Operations” included in this Form 10‑K.
Our industry is highly competitive, and we strive to differentiate our services based upon the quality of our FlexRig® drilling rigs and our engineering design expertise, operational efficiency, software technologies, and safety and environmental awareness. The number of available rigs generally exceeds demand in many of our markets, resulting in significant price competition. We compete against many drilling companies, some of whom are present in more than one of our operating regions. In the United States, we compete with Nabors Industries Ltd., Patterson-UTI Energy, Inc. and many other competitors with regional operations. Internationally, we compete directly with various contractors at each location where we operate. In the Gulf of Mexico platform rig market, we primarily compete with Nabors Industries Ltd. and Blake International Rigs, LLC.
Drilling Contracts
Our drilling contracts are obtained through competitive bidding or as a result of direct negotiations with customers. Our contracts vary in their terms and rates depending on the nature of the operations to be performed, the duration of the work, the amount and type of equipment and services provided, the geographic areas involved, market conditions and other variables. In many instances, our contracts cover multi‑well or pad and multi‑year projects. Except for a limited number of rigs operated under master agreements, each drilling rig operates under a separate drilling contract.
The duration of our drilling contracts are generally either “well‑to‑well/pad-to-pad” or for a fixed term. “Well‑to‑well” contracts can be terminated at the option of either party upon the completion of drilling of any one well. Fixed-term contracts generally have a minimum term of at least six months up to multiple years. These contracts customarily provide for termination at the election of the customer but may include an “early termination payment” to be paid to us if the contract is terminated prior to the expiration of the fixed term. However, under certain limited circumstances such as destruction of a drilling rig, bankruptcy, sustained unacceptable performance by us or delivery of a rig beyond certain grace and/or liquidated damage periods, no early termination payment would be paid to us.
Contracts generally contain renewal or extension provisions exercisable at the option of the customer at prices mutually agreeable to us and the customer. In most instances, contracts provide for additional payments for mobilization and demobilization of the rig.
Daywork Contracts
Daywork contracts are contracts under which we charge a rate per day, with the price determined by the location, depth and complexity of the well to be drilled, operating conditions, the duration of the contract, and the competitive forces of the market. During fiscal year 2021, a majority of our drilling services were performed on a “daywork” contract basis.
Footage Contracts
Footage contracts are contracts where we charge a fixed rate per foot of hole drilled to a stated depth, with a fixed rate per day for the remainder of the hole. Contracts performed on a "footage" basis generally involve a greater element of risk to the Company compared to contracts performed on a "daywork" basis.
Lump-sum Contracts
Lump-sum contract are contracts under which we charge a fixed sum to deliver a hole to a stated depth and agree to furnish services such as testing, coring and casing the hole which are not normally done on a "footage" basis. "Lump-sum" contracts entail varying degrees of risk greater than the usual "footage" contract.
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Performance-based Contracts
Performance-based contracts are contracts pursuant to which we are compensated based upon our performance against a mutually agreed upon set of predetermined targets. These contract types are relatively new to the industry and typically have a lower base dayrate, but give us the opportunity to receive additional compensation by meeting or exceeding certain performance targets agreed to by our customers. For example, some performance targets are set based upon days to drill a well or the number of lateral feet drilled in zone per day. We often use our automated technology solutions to assist in achieving the performance targets. The risks associated with these contracts relate to the failure to reach the agreed upon performance targets. If we do not meet these targets, we will not receive additional compensation above what we have received utilizing a "daywork" contract. Based on our operational track record throughout fiscal year 2021 and drilling expertise, our performance-based contracts have produced a positive risk-reward outcome. We are seeing a growing adoption of performance contracts by our customers and we expect this trend to continue.
Contract Backlog
As of September 30, 2021 and 2020, our drilling contract backlog was $572.0 million and $658.0 million, respectively. Approximately 22.9 percent of the September 30, 2021 backlog is reasonably expected to be fulfilled in fiscal year 2023 and thereafter. See Item 7—"Management's Discussion and Analysis of Financial Condition and Results of Operations — Contract Backlog" included in this Form 10-K for additional information pertaining to backlog.
Employees
As of September 30, 2021, we had 5,444 employees within the United States and 488 employees in our international operations. The number of employees fluctuates depending on the current and expected demand for our services. We consider our employee relations to be robust. None of our U.S. employees are represented by a union. However, some of our international employees are unionized.
Human Capital Objectives and Programs
We strive to create a culture and work environment that enables us to attract, train, promote, and retain a diverse group of talented employees who together can help us gain a competitive advantage.
Core Values and Culture
"The H&P Way" defines our purpose, core values, and the behaviors that drive our culture. What we endeavor to do is anchored in our purpose, improving lives through efficient and responsible energy. Fostering and maintaining a strong, healthy culture is a key strategic focus. Our core values serve to inform who we are and the way our employees interact with one another, our customers, partners and shareholders. Our core value of Actively C.A.R.E. means that we treat one another with respect. We care about each other, and from a safety perspective, our employees are committed to Controlling and Removing Exposures ("C.A.R.E.") for themselves and others. Our core value of Service Attitude means that we do our part and more for those around us. We consider the needs of others and provide solutions to meet their needs. Our core value of Innovative Spirit means that we constantly work to improve and are willing to try new approaches. We make decisions with the long-term view in mind. Our core value of teamwork means that we listen to one another and work across teams toward a common goal. We collaborate to achieve results and focus on success for our customers and shareholders. Finally, we strive to do the right thing. That means we are honest and transparent. We tackle tough situations, make decisions, and speak up when needed.
Talent Attraction & Retention
Our recruiting practices and decisions on whom we hire are among our most important activities. Our Workforce Staffing team provides full staffing services to ensure consistent staffing levels on our rigs. This team sources, hires, onboards, trains, assigns and reassigns rig-based employees. In downturn years, we maintain relationships with former employees and prioritize recalling our most experienced people for field positions. In fiscal year 2021, we recalled approximately 1,800 employees. In addition, we utilize social media, local job fairs, employee referral bonuses, and educational organizations across the United States to find diverse, motivated and responsible employees.
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Education and Training
We are dedicated to the continual training and development of our employees, especially of those in field operations, to ensure we can develop future managers and leaders from within our organization. Our training starts right at the beginning with on-boarding procedures that focus on safety, responsibility, ethical conduct and inclusive teamwork.
H&P’s strong commitment to our employees’ growth is demonstrated through our formal organizational development team, which oversees talent management, training and development. In addition to career and safety training efforts, the team creates, manages and implements enhancements to development and succession plans, change management initiatives and diversity, equity and inclusion ("DE&I") programs.
H&P offers a variety of training programs ranging from job specific programs to leadership development. Some of the prominent training programs that we offer are:
New Employment Safety Training - onboarding program for new hires in safety sensitive positions. The purpose of the program is to prepare employees to work safely on our rigs and provide necessary certifications to do so; including all Occupational Safety and Health Administration ("OSHA") and IADC training, as well as Company culture education.
Short Service Employee - specialized training program that is a continuation of New Employment Introduction basics and is intended to provide the technical on-the-job training guided by a mentor.
Ethics and Compliance Training – comprised of several specific training programs, including Code of Conduct, Insider Trading, Anti-Discrimination & Harassment, Data Privacy, Trade Compliance, and Anti-Corruption.
Change Champions - teaches employees to solve complex problems using structured processes, tools and data to drive results while emphasizing leadership and public speaking.
Leadership Series - accessible online to all leaders and covers a variety of topics related to leading The H&P Way.
Safety Training and Serious Injury and/or Fatality ("SIF") Reduction Program
We are committed to creating a culture highlighted by an Actively Caring workforce. We strive to Actively C.A.R.E. for:
    
our own safety and health;

the safety and health of others; and

the protection of our environment.
Fundamental to our Actively C.A.R.E. culture is every individual's willingness to provide immediate open feedback to others regarding safe and unsafe work practices and to proactively correct recognized exposures that threaten one's health and safety. Through training and accountability, H&P educates our employees on the negative consequences of taking health and safety risks. Our success will only be determined by demonstrated action and continuous improvement.
Safety Leadership
For more than 20 years, H&P measured safety success the same way other companies in our industry did – the absence of OSHA recordable injuries, declining lost time, restricted duty and medical treatment cases, declining total recordable injury rates ("TRIR") and the number of active rig years worked without an OSHA recordable injury or lost-time injury. We now believe that measuring safety in this manner can be destructive to management’s efforts to build trust with field employees. We have redefined safety success as the Control and Removal of Exposures (C.A.R.E.) for self and others and encourage employees to report near miss incidents with serious, life-altering or fatal injury potential, identifying and reporting serious injury exposures for which employees are personally recognized and rewarding monetarily for exemplifying our Actively C.A.R.E culture. We believe trust is key to organizational health, as well as safety and operational success.
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SIF Strategy
We are committed to controlling and removing SIF exposures on any H&P location or operation. H&P safety data shows that approximately 10 to 15 percent of all OSHA recordable injuries are events in which valuable lessons learned are produced and inform mitigation efforts to reduce potential serious injury in the future. The remaining recordable cases may not provide the necessary learning opportunities to prevent future serious injury. Similarly, the data also indicates that SIF potential incidents, all of which provide information to help prevent future serious injury or fatality, occur approximately 1.5 times more than the traditional TRIR. We continue to track traditional safety metrics like TRIR and lost time injury rates in order to be responsive to client requests and to benchmark against existing industry data but we will have a proportionate response to these antiquated metrics. Our safety success at H&P will be based on key performance indicators related to the controlling and removing of SIF exposure, such as SIF potential and SIF mitigated rates, and our vision for the future of safety at H&P will be guided by these principles.
Diversity, Equity & Inclusion
We believe that creating an environment where our employees feel valued and respected drives engagement, better leverages the unique talents and perspectives of our people to innovate and enhances our ability to attract and retain a diverse workforce. H&P has employed a DE&I specialist, implemented a thriving Women of H&P Employee Resource Group, and established a DE&I Advisory Council with global employee representation. Our commitments are evidenced by formalized policies regarding equal opportunity and a discrimination-free workplace. We are actively tracking diversity data to better understand demographics within the organization.
Employee Benefits, Health and Wellness
H&P values its employees and believes benefit packages are essential to prioritizing the well-being of its staff and offering competitive compensation. Select highlights of our benefits programs include:
Medical, dental and vision insurance for all full-time employees, and all part-time employees working more than 20 hours per week, and their dependents;
A 401(k) plan with Company match incentive for all full-time employees, and all part-time employees working more than 20 hours per week;
Employer paid life insurance benefits, which include a life assistance program, identity theft protection, and travel assistance plan;
The Employee Assistance Plan, which offers wellness support with counseling, legal assistance, financial coaching, and identity theft resolution;
The H&P Way Fund, which provides financial assistance to H&P employees during unavoidable emergencies;
Employee discounts for phone, computer, personal vehicle, car rental, and hotel purchases; and
An Educational Assistance Plan, which offers reimbursement of tuition fees for any employee pursuing an undergraduate degree and, in some cases, post-graduate degrees.
Insurance and Risk Management
Our operations are subject to a number of operational risks, including personal injury and death, environmental, cyber, and weather risks, which could expose us to significant losses and damage claims. We are not fully insured against all of these risks and our contractual indemnity provisions may not fully protect us. Furthermore, if a significant accident or other event occurs and is not fully covered by insurance or an enforceable or recoverable indemnity from a customer, it could have a material adverse effect on our business, financial condition and results of operations.
We have indemnification agreements with many of our customers and we also maintain liability and other forms of insurance. In general, our drilling contracts contain provisions requiring our customers to indemnify us for, among other things, pollution and reservoir damage. However, our contractual rights to indemnification may be unenforceable or limited due to negligent or willful acts by us, or subcontractors and/or suppliers or by reason of state anti-indemnity laws. Our customers and other third parties may also dispute these indemnification provisions, or we may be unable to transfer these risks to our drilling customers or other third parties by contract or indemnification agreements.
We insure working land rigs and related equipment at values that approximate the current replacement costs on the inception date of the policies. However, we self-insure large deductibles under these policies. We also carry insurance with varying deductibles and coverage limits with respect to stacked rigs, offshore platform rigs, and “named wind storm” risk in the Gulf of Mexico.
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We have insurance coverage for comprehensive general liability, automobile liability, workers’ compensation and employer’s liability, and certain other specific risks. Insurance is purchased over deductibles to reduce our exposure to catastrophic events. We retain a significant portion of our expected losses under our workers’ compensation, general liability and automobile liability programs. We self-insure a number of other risks including loss of earnings and business interruption. We are unable to obtain significant amounts of insurance to cover risks of underground reservoir damage.
Our insurance may not in all situations provide sufficient funds to protect us from all liabilities that could result from our operations. Our coverage includes aggregate policy limits. As a result, we retain the risk for any loss in excess of these limits. No assurance can be given that all or a portion of our coverage will not be canceled, that insurance coverage will continue to be available at rates considered reasonable or that our coverage will respond to a specific loss. Further, we may experience difficulties in collecting from our insurers or our insurers may deny all or a portion of our claims for insurance coverage.
Government Regulations

Our operations are affected from time to time and in varying degrees by foreign and domestic political developments and a variety of federal, state, foreign, regional and local laws, rules and regulations, including those relating to:
• drilling of oil and natural gas wells;
• directional drilling services;
• protection of the environment;
• workplace health and safety;
• labor and employment;
• data privacy;
• taxation;
• exportation or importation of equipment, technology and software; and
• currency conversion and repatriation.
Environmental laws and regulations that apply to our operations include the Clean Air Act, the Clean Water Act, the Comprehensive Environmental Response, Compensation, and Liability Act of 1980 (“CERCLA”), the Resource Conservation and Recovery Act (each, as amended) and similar laws that provide for responses to, and liability for, air emissions, water discharges or releases of oil or hazardous substances into the environment, including damages to natural resources. Applicable environmental laws and regulations also include similar foreign, state or local counterparts to the above-mentioned federal laws, which regulate air emissions, water discharges, and management of hazardous substances and waste. Environmental laws can have a material adverse effect on the drilling industry, including our operations, and compliance with such laws may require us to make significant capital expenditures, such as the installation of costly equipment or operational changes, and may affect the resale values or useful lives of our drilling rigs.
The Occupational Safety and Health Act (“OSHA”) and other similar laws and regulations govern the protection of the health and safety of employees. The OSHA hazard communication standard, the Environmental Protection Agency community right-to-know regulations under Title III of CERCLA, the Emergency Planning and Community Right-to-Know Act and similar state statutes and local regulations require that information be maintained about hazardous materials used in our operations and that this information be provided to employees, state and local governments, emergency responders and citizens.
A number of countries actively regulate and control the importation and/or exportation of oil and gas and other aspects of the oil and gas industries in their countries. In addition, government actions and initiatives by OPEC+ may continue to contribute to oil price volatility. In some areas of the world, government activity has adversely affected the amount of exploration and development work done by oil and gas companies and influenced their need for drilling services, and likely will continue to do so.
In addition, we are subject to a variety of other U.S. and foreign laws and regulations, including, but not limited to, the U.S. Foreign Corrupt Practices Act and other anti-bribery and anti-corruption laws. The U.S. Foreign Corrupt Practices Act and similar anti-bribery and anti-corruption laws in other jurisdictions generally prohibit companies and their intermediaries from making improper payments to non-U.S. officials for the purpose of obtaining or retaining business. Failure to comply with applicable laws or regulations or acts of misconduct could subject us to fines, penalties or other sanctions. For more information, see Item 1A— “Risk Factors — Failure to comply with the U.S. Foreign Corrupt Practices Act or foreign anti‑bribery legislation could adversely affect our business.
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We are also subject to the jurisdiction of the U.S. Treasury Department’s Office of Foreign Assets Control, the U.S. Commerce Department’s Bureau of Industry and Security, the U.S. Customs and Border Protection and other U.S. and non-U.S. laws and regulations governing the international trade of goods, services and technology. Such regulations regarding exports and imports of covered goods or dealings with sanctioned countries, persons or entities include licensing, recordkeeping and reporting requirements. Failure to comply with applicable laws and regulations relating to customs, tariffs, sanctions and export controls may subject us to criminal sanctions or civil remedies, including fines, denial of export privileges, injunctions or seizures of assets. For more information, see Item 1A— “Risk Factors — Government policies, mandates, and regulations specifically affecting the energy sector and related industries, regulatory policies or matters that affect a variety of businesses, taxation polices, and political instability could adversely affect our financial condition and results of operations.
We are also subject to regulation by numerous other regulatory agencies, including, but not limited to, the U.S. Department of Labor, which sets employment practice standards for workers. In addition, we are subject to certain requirements to contribute to retirement funds or other benefit plans, and laws in some jurisdictions restrict our ability to dismiss employees.
We monitor our compliance with applicable governmental rules and regulations in each country of operation. We have made and will continue to make the required expenditures to comply with current and future regulatory requirements. We do not anticipate that compliance with currently applicable rules and regulations and required controls will significantly change our competitive position, capital spending or earnings during 2022. We believe we are in material compliance with applicable rules and regulations and, to date, the cost of such compliance has not been material to our business or financial condition. However, future events such as additional laws and regulations, changes in existing laws and regulations or their interpretation or more vigorous enforcement policies of regulatory agencies, may require additional expenditures by us, which may be material. Specifically, the expansion of the scope of laws or regulations protecting the environment has accelerated in recent years, particularly outside the United States, and we expect this trend to continue. Accordingly, there can be no assurance that we will not incur significant compliance costs in the future. See Item 1A— “Risk Factors — Failure to comply with or changes to governmental and environmental laws could adversely affect our business.”
Sustainability

    H&P has helped its customers supply energy for more than a century, and we continue to innovate and improve the ways in which we can provide energy safely, reliably, and efficiently. Through our work and the work of our customers, we have used our unique position and expertise to advance energy production, reliability, and affordability to people across the globe. The Company continues to evolve and refine its comprehensive sustainability strategy rooted in our core value to "do the right thing," as discussed under "— Human Capital Objectives and Programs — Core Values and Culture." Our sustainability strategy uses data to better understand our impacts in areas like emissions, diversity, and safety.

Improving Lives Through Efficient and Responsible Energy
We believe efficient and responsible energy improves lives globally. With a focus on leading-edge technology, we strive to deliver industry-leading efficiency, safety, and value while continuing to reduce our environmental impact.
Society’s general well-being relies on the energy industry to supply the power that sustains and drives our lives. People have relied upon and harnessed energy from resources like fire, water, wind, animals both domesticated and wild, fossil fuels, nuclear, solar, and more, with each having its own unique societal benefits and costs.
Over time, the continued growth of the world’s population highlighted a need to capture more concentrated forms of energy, making a reliance on fossil fuels increasingly central. Over the last several decades, those responsible for producing fossil fuels gained more expertise and became more specialized.  A “service sector” developed to supply the most scientific and technologically specialized needs of the oil and gas sector.  We provide highly specialized services in this narrow segment of the very broad and constantly evolving energy sector. We continue to innovate in an effort to increase efficiency for our customers and provide continued societal benefits with less impact to the environment.
Focused on Safer and More Efficient Drilling
We provide performance-driven drilling solutions that are intended to make oil and gas recovery safer and more economical or our customers. Focused on the drilling segment of the oil and gas production value chain, we provide the expertise, technology and equipment to drill oil and gas wells for our customers - the exploration and production ("E&P") companies. Our E&P customers then determine if and when to extract those resources from the ground, following completion of the well.
H&P and the Fossil Fuel Value Chain

While we do play an important role in helping our customers make overall production as safe and efficient as possible, our most critical responsibility is ensuring the safety of our employees and the employees of our customers. Although many of the environmental and safety risks associated with the oil and gas sector fall outside of our operations, we remain committed to utilizing our expertise and advancing our technologies to aid our customers in minimizing personal and environmental risks and maximizing industry sustainability efforts. Our customers are looking specifically to our expertise and technologies to help them minimize their environmental impact, reduce risks, and achieve their ESG performance targets.
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Below is a description of the roles that H&P plays, in the oil and gas value chain, as a drilling solutions provider in comparison to the roles that participants in other sectors of the oil and gas industry play.
H&P:
makes drilling for oil safer and more efficient;
builds and renovates drilling rigs at two industrial facilities in Texas and Oklahoma;
oversees drilling operations on its rigs on customer sites;
drills predominantly on-shore in the United States (86 percent of available rigs are on onshore);
makes significant and impactful investments in research and development and new technologies;
OTHER SECTORS OF THE OIL AND GAS INDUSTRY:
buy, lease, prepare, manage or restore land or are responsible for the protection of wildlife on or biodiversity of property;
engage in hydraulic fracturing;
pump oil or gas from the ground;
procure, transport or pump water underground, or treat or remove wastewater from the site, or arrange for its disposal;
assume responsibility for the prevention of fugitive releases or emissions associated with the oil and gas production process;
engage in oil and gas transport, refining or storage; and
engage in downstream operations.
Human Capital
For a description of our recruiting practices, education and training for employees, and employee benefits, see "— Human Capital Objectives and Programs" above.
Available Information
Our website is located at www.helmerichpayne.com. Annual reports on Form 10‑K, quarterly reports on Form 10‑Q, current reports on Form 8‑K, and amendments to those reports, earnings releases, and financial statements are made available free of charge on the investor relations section of our website as soon as reasonably practicable after we electronically file such materials with, or furnish such materials to, the Securities and Exchange Commission ("SEC"). The information contained on our website, or accessible from our website, is not incorporated into, and should not be considered part of, this Form 10‑K or any other documents we file with, or furnish to, the SEC. The SEC maintains an Internet site (http://www.sec.gov) that contains reports, proxy and information statements and other information regarding issuers that file electronically with the SEC. Annual reports, quarterly reports, current reports, amendments to those reports, earnings releases, financial statements and our various corporate governance documents are also available free of charge upon written request.
Investors and others should note that we announce material financial information to our investors using our investor relations website (https://ir.helmerichpayne.com/websites/helmerichandpayne/English/0/investor-relations.html), SEC filings, press releases, public conference calls and webcasts. We use these channels as well as social media to communicate with our stockholders and the public about our company, our services and other issues. It is possible that the information we post on social media could be deemed to be material information. Therefore, we encourage investors, the media, and others interested in our company to review the information we post on the social media channels listed on our investor relations website.
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ITEM 1A. RISK FACTORS
An investment in our securities involves a variety of risks. In addition to the other information included and incorporated by reference in this Form 10-K and the risk factors discussed elsewhere in this Form 10-K, the following risk factors should be carefully considered, as they could have a material adverse effect on our business, financial condition and results of operations. There may be other additional risks, uncertainties and matters not presently known to us or that we believe to be immaterial that could nevertheless have a material adverse effect on our business, financial condition and results of operations.
BUSINESS AND OPERATING RISKS
The impact and effects of public health crises, pandemics and epidemics, such as the COVID-19 pandemic, have adversely affected and are expected to continue to adversely affect our business, financial condition and results of operations.
Public health crises, pandemics and epidemics, such as the COVID-19 pandemic, have adversely impacted and are expected to continue to adversely impact our operations, the operations of our customers and the global economy, including the worldwide demand for oil and natural gas and the level of demand for our services. Fear of such events has also altered the level of capital spending by oil and gas companies for exploration and production activities and adversely affected the economies and financial markets of many countries (or globally), resulting in an economic downturn that has affected demand for our services. Actions taken to prevent the spread of COVID-19 by governmental authorities around the world, including imposing mandatory closures of all non-essential business facilities, seeking voluntary closures of such facilities and imposing restrictions on, or advisories with respect to, travel, business operations and public gatherings or interactions, have significantly reduced global economic activity, thereby resulting in lower demand for crude oil. In particular, the travel restrictions in certain countries where we operate, including the closure of their borders to travel into the country, have resulted in an inability to effectively staff or rotate personnel at, and thereby operate, certain of our rigs and could lead to an inability to fulfill our contractual obligations under contracts with customers. Governmental authorities have also implemented multi-step policies with the goal of re-opening various sectors of the economy. However, certain jurisdictions began reopening only to return to restrictions in the face of increases in new COVID-19 cases, while other jurisdictions are continuing to reopen or have completed the reopening process despite increases in COVID-19 cases. Despite the increased availability of vaccines in certain jurisdictions, the COVID-19 pandemic may continue unabated or worsen during the upcoming months, including as a result of the emergence of more infectious strains of the virus, vaccine hesitancy or increased business and social activities, which may cause governmental authorities to reconsider restrictions on business and social activities. In the event governmental authorities increase restrictions, the reopening of the economy may be curtailed. We have experienced, and expect to continue to experience, some disruptions to our business operations, as these restrictions have significantly impacted, and may continue to impact, many sectors of the economy. Depressed economic conditions exacerbated by COVID-19 restrictions in one foreign jurisdiction where we operate have led to an increase in community strikes which have resulted in periodic suspensions of our operations. In addition, the perceived risk of infection and health risk associated with COVID-19, and the illness of many individuals across the globe, has and will continue to alter behaviors of consumers and policies of companies around the world; such altered behaviors and policies have many of the same effects intended by governmental authorities to stop the spread of COVID-19, such as self-imposed or voluntary social distancing, quarantining, and remote work policies. We are complying with local governmental jurisdiction policies and procedures where our operations reside. In some cases, policies and procedures are more stringent in our foreign operations than in our North America operations.
In early March 2020, the increase in crude oil supply resulting from production escalations from OPEC+ combined with a decrease in crude oil demand stemming from the global response and uncertainties surrounding the COVID-19 pandemic resulted in a sharp decline in crude oil prices. Consequently, we saw a significant decrease in customer 2020 capital budgets and a corresponding dramatic decline in the demand for land rigs. Although OPEC+ agreed in April 2020 to cut oil production, OPEC+ has been gradually reducing such cuts and in July 2021, agreed to further reduce such cuts on a monthly basis with a goal of phasing out all production cuts towards the end of 2022. There is no assurance that the most recent OPEC+ agreement will be observed by its parties and OPEC+ may change its agreement depending upon market conditions. Although crude oil prices have recovered since March 2020, oil and natural gas prices are expected to continue to be volatile as a result of near-term production instability, the ongoing COVID-19 pandemic, changes in oil and natural gas inventories, industry demand, global and national economic performance, and the actions of OPEC+.
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These events have had, and could continue to have, an adverse impact on numerous aspects of our business, financial condition and results of operations, including, but not limited to, our growth, costs, loss of workers, labor shortages, supply chain disruptions, or equipment shortages, logistics constraints, customer demand for our services and industry demand generally, capital spending by oil and gas companies, our liquidity, the price of our securities and trading markets with respect thereto, our ability to access capital markets, asset impairments and other accounting changes, certain of our customers experiencing bankruptcy or otherwise becoming unable to pay vendors, including us, and the global economy and financial markets generally. The ultimate extent of the impact of COVID-19 and prolonged excess oil supply on our business, financial condition and results of operations will depend largely on future developments, including the duration and spread of COVID-19 within the United States and the parts of the world in which we operate and the related impact on the oil and gas industry, the impact of governmental actions designed to prevent the spread of COVID-19 and the development, availability, timely distribution and acceptance of effective treatments and vaccines worldwide, all of which are highly uncertain and cannot be predicted with certainty at this time.
Our business depends on the level of activity in the oil and natural gas industry, which is significantly impacted by the volatility of oil and natural gas prices and other factors.
Our business depends on the conditions of the land and offshore oil and natural gas industry. Demand for our services and the rates we are able to charge for such services depend on oil and natural gas industry exploration and production activity and expenditure levels, which are directly affected by trends in oil and natural gas prices and market expectations regarding such prices. The sharp decline in oil prices resulting from the COVID-19 pandemic and the activities of OPEC+ caused a significant decline in both drilling activity and prices for our services in fiscal year 2020. While crude oil prices have stabilized and increased and our rig count has continued to recover, our rig activity has still not reached the level it was at prior to these events and these events therefore continue to have a material adverse effect on our business, financial condition and results of operations.
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Oil and natural gas prices and production levels, as well as market expectations regarding such prices and production levels, have been volatile, which has had, and may in the future have, adverse effects on our business and operations. The volatility in prices and production levels are impacted by many factors beyond our control, including:
the domestic and foreign supply of, and demand for, oil, natural gas and related products;
the cost of exploring for, developing, producing and delivering oil and natural gas;
uncertainty in capital and commodities markets and the ability of oil and natural gas producers to access capital;
the availability of and constraints in storage and transportation capacity, including, for example, takeaway constraints experienced in the Permian Basin over the past several years;
the worldwide economy;
expectations about future oil and natural gas prices and production levels;
local and international political, economic, health and weather conditions, especially in oil and natural gas producing countries, including, for example, the impacts of local and international pandemics and other disasters or events such as the global COVID-19 pandemic;
actions of OPEC, its members and other oil producing nations, such as Russia, relating to oil price and production levels, including announcements of potential changes to such levels;
the levels of production of oil and natural gas of non-OPEC countries;
the continued development of shale plays which may influence worldwide supply and prices;
tax policies of the United States and other countries involved in global energy markets;
political and military conflicts in oil producing regions or other geographical areas or acts of terrorism in the United States or elsewhere;
technological advances that are related to oil and natural gas recovery or that affect the global demand for energy;
the development, exploitation and market acceptance of alternative energy sources as part of a transition to a lower carbon economy;
increased focus by the investment community on sustainability practices in the oil and natural gas industry;
legal and other limitations or restrictions on exportation and/or importation of oil and natural gas;
laws and governmental regulations affecting the use of oil and natural gas; and
the environmental and other laws and governmental regulations affecting exploration and development of oil and natural gas reserves.
The level of land and offshore exploration, development and production activity and the prices of oil and natural gas are volatile and are likely to continue to be volatile in the future. Higher oil and natural gas prices do not necessarily translate into increased activity because demand for our services is typically driven by our customers’ expectations of future commodity prices, as well as our customers' ability to access sources of capital to fund their operating and capital expenditures. However, a sustained decline in worldwide demand for oil and natural gas, as well as excess supply of oil or natural gas coupled with storage and transportation capacity constraints, shutting in of wells or wells being drilled but not completed, prolonged low oil or natural gas prices or a reduction in the ability of our customers to access capital, has resulted in, and may in the future result in, reduced exploration and development of land and offshore areas and a decline in the demand for our services, which has had, and may in the future, have a material adverse effect on our business, financial condition and results of operations.
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Global economic conditions and volatility in oil and gas prices may adversely affect our business.
Concerns over global economic conditions, energy costs, geopolitical issues, supply chain disruptions, inflation, the availability and cost of credit and the worldwide COVID-19 pandemic have contributed to increased economic uncertainty. An economic slowdown or recession in the United States or in any other country that significantly affects the supply of or demand for oil or natural gas could negatively impact our operations and therefore adversely affect our results. Global economic conditions have a significant impact on oil and natural gas prices and any stagnation or deterioration in global economic conditions could result in less demand for our services and could cause our customers to reduce their planned spending on exploration and development drilling. Adverse global economic conditions may cause our customers, vendors and/or suppliers to lose access to the financing necessary to sustain or increase their current level of operations, fulfill their commitments and/or fund future operations and obligations. Furthermore, challenging economic conditions may result in certain of our customers experiencing bankruptcy or otherwise becoming unable to pay vendors, including us. In the past, global economic conditions, and expectations for future global economic conditions, have sometimes experienced significant deterioration in a relatively short period of time and there can be no assurance that global economic conditions or expectations for future global economic conditions will recover in the near term or not quickly deteriorate again due to one or more factors. These conditions could have a material adverse effect on our business, financial condition and results of operations.
The drilling services and solutions business is highly competitive, and a surplus of available drilling rigs may adversely affect our rig utilization and profit margins.
Competition in drilling services and solutions involves such factors as price, efficiency, condition, type and operational capability of equipment, reputation, operating safety, environmental impact, customer relations, rig availability and excess rig capacity in the industry. Competition is primarily on a regional basis and may vary significantly by region at any particular time. Land drilling rigs can be readily moved from one region to another in response to changes in levels of activity, which could result in an oversupply of rigs in any region, leading to increased price competition. In addition, development of new drilling technology by competitors has increased in recent years, which could negatively affect our ability to differentiate our services.
We periodically seek to increase the prices on our services to offset rising costs, earn returns on our capital investment and otherwise generate higher returns for our stockholders. However, we operate in a very competitive industry and we are not always successful in raising or maintaining our existing prices. With the active rig count below the peak reached in 2014 and many rigs, including highly capable AC rigs, still idle, there is considerable pricing pressure in the industry. Even if we are able to increase our prices, we may not be able to do so at a rate that is sufficient to offset rising costs without adversely affecting our activity levels. The inability to maintain our pricing and to increase our pricing as costs increase could have a material adverse effect on our business, financial position, results of operations and cash flows.
Following periods of downturn in our industry, there may be substantially more drilling rigs available than necessary to meet demand even as oil and natural gas prices, and drilling activity, rebound. In the event of a surplus of available and more competitive drilling rigs, we may continue to experience difficulty in replacing fixed‑term contracts, extending expiring contracts or obtaining new contracts in the spot market, and new contracts may contain lower dayrates and substantially less favorable terms, which could have a material adverse effect on our business, financial condition and results of operations. As of September 30, 2021, 136 of our available rigs were not under contract.
Further, as a result of a significant reduction in the demand for oil and natural gas services, certain of our competitors may engage in bankruptcy proceedings, debt refinancing transactions, management changes, or other strategic initiatives in an attempt to reduce operating costs to maintain a position in the market.  This could result in such competitors emerging with stronger or healthier balance sheets and in turn an improved ability to compete with us in the future. We may also see corporate consolidations among our competitors, which could significantly alter industry conditions and competition within the industry, and have a material adverse effect on our business, financial condition and results of operations.
New technologies may cause our drilling methods and equipment to become less competitive and it may become necessary to incur higher levels of capital expenditures in order to keep pace with the disruptive trends in the drilling industry. Growth through the building of new drilling rigs and improvement of existing rigs is not assured.
The market for our services is characterized by continual technological developments that have resulted in, and will likely continue to result in, substantial improvements in the functionality and performance, including environmental performance, of rigs and equipment. Our customers increasingly demand the services of newer, higher specification drilling rigs, as well as new and improved technology, such as drilling automation technology and lower-emissions operations and services. This results in a bifurcation of the drilling fleet and is evidenced by the higher specification drilling rigs (e.g., AC rigs) generally operating at higher overall utilization levels and dayrates than the lower specification drilling rigs (e.g., SCR rigs). In addition, a significant number of lower specification rigs are being stacked and/or removed from service.
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Although we take measures to ensure that we develop and use advanced oil and natural gas drilling technology, changes in technology, improvements by competitors and increasing customer demands for new and improved technology could make our equipment less competitive. There can be no assurance that we will:
have sufficient capital resources to improve existing rigs or build new, technologically advanced drilling rigs;
avoid cost overruns inherent in large fabrication projects resulting from numerous factors such as shortages or unscheduled delays in delivery of equipment or materials, inadequate levels of skilled labor, unanticipated increases in costs of equipment, materials and labor, design and engineering problems, and financial or other difficulties;
successfully deploy idle, stacked, new or upgraded drilling rigs;
effectively manage the increased size or future growth of our organization and drilling fleet;
maintain crews necessary to operate existing or additional drilling rigs; or
successfully improve our financial condition, results of operations, business or prospects as a result of improving existing drilling rigs or building new drilling rigs.
In the event that we are successful in developing new technologies for use in our business, there is no guarantee of future demand for those technologies. Customers may be reluctant or unwilling to adopt our new technologies. We may also have difficulty negotiating satisfactory terms for our technology services or may be unable to secure prices sufficient to obtain expected returns on our investment in the research and development of new technologies.
If we are not successful in upgrading existing rigs and equipment or building new rigs in a timely and cost‑effective manner suitable to customer needs, demand for our services could decline and we could lose market share. One or more technologies that we may implement in the future may not work as we expect and our business, financial condition, results of operations and reputation could be adversely affected as a result. Additionally, new technologies, services or standards could render some of our services, drilling rigs or equipment obsolete, which could reduce our competitiveness and have a material adverse impact on our business, financial condition and results of operations.
Our drilling and technology related operations are subject to a number of operational risks, including environmental and weather risks, which could expose us to significant losses and damage claims. We are not fully insured against all of these risks and our contractual indemnity provisions may not fully protect us.
Our operations are subject to the many hazards inherent in the business, including inclement weather, blowouts, explosions, well fires, loss of well control, equipment failure, pollution, and reservoir damage. These hazards could cause significant environmental and reservoir damage, personal injury and death, suspension of operations, serious damage or destruction of equipment and property and substantial damage to producing formations and surrounding lands and waters. An accident or other event resulting in significant environmental or property damage, or injuries or fatalities involving our employees or other persons could also trigger investigations by federal, state or local authorities. Such an accident or other event and subsequent crisis management efforts could cause us to incur substantial expenses in connection with investigation and remediation as well as cause lasting damage to our reputation, loss of customers and an inability to obtain insurance. 
Our Offshore Gulf of Mexico operations are also subject to potentially significant risks and liabilities attributable to or resulting from adverse environmental conditions, including pollution of offshore waters and related negative impact on wildlife and habitat, adverse sea conditions and platform damage or destruction due to collision with aircraft or marine vessels. Our Offshore Gulf of Mexico operations may also be negatively affected by a blowout or an uncontrolled release of oil or hazardous substances by third parties whose offshore operations are unrelated to our operations. We operate several platform rigs in the Gulf of Mexico. The Gulf of Mexico experiences hurricanes and other extreme weather conditions on a frequent basis, which may increase with any climate change. See below “— The physical effects of climate change and the regulation of greenhouse gases and climate change could have a negative impact on our business.” Damage caused by high winds and turbulent seas could potentially curtail operations on our platform rigs for significant periods of time until the damage can be repaired. Moreover, we may experience disruptions in operations due to damage to customer platforms and other related facilities in the area. We also lease a fabrication facility near the Houston, Texas ship channel, and our principal fabricator and other vendors are also located in the gulf coast region and could be exposed to damage or disruption by hurricanes and other extreme weather conditions, including coastal flooding, which in turn could affect our business, financial condition and results of operations.
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It is customary in our business to have mutual indemnification agreements with customers on a “knock-for-knock” basis, which means that we and our customers assume liability for our respective personnel, subcontractors, and property. In general, our drilling contracts contain provisions requiring our customers to indemnify us for, among other things, pollution and reservoir damage. However, our contractual rights to indemnification may be unenforceable or limited due to negligent or willful acts by us, our subcontractors and/or suppliers. Additionally, certain states, including Texas, New Mexico, Wyoming, and Louisiana, have enacted statutes generally referred to as "oilfield anti-indemnity acts," which expressly limit certain indemnity agreements contained in or related to indemnification in contracts, and could expose the Company to financial loss. Furthermore, other states may enact similar oilfield anti-indemnity acts.
Our customers and other third parties may also dispute, or be unable to meet, their contractual indemnification obligations to us. Accordingly, we may be unable to transfer these risks to our customers and other third parties by contract or indemnification agreements. Incurring a liability for which we are not fully indemnified or insured could have a material adverse effect on our business, financial condition and results of operations.
We insure working land rigs and related equipment at values that approximate the current replacement cost on the inception date of the policies. We also carry insurance with varying deductibles and coverage limits with respect to stacked rigs, offshore platform rigs, and “named wind storm” risk in the Gulf of Mexico. In addition, we have insurance coverage for comprehensive general liability, automobile liability, workers’ compensation and employer’s liability, and certain other specific risks. Insurance is purchased over deductibles to reduce our exposure to catastrophic events. In some cases, we self-insure large deductibles on certain insurance policies. We retain a significant portion of our expected losses under our workers’ compensation, general liability and automobile liability programs. The Company self‑insures a number of other risks, including loss of earnings and business interruption. We are unable to obtain significant amounts of insurance to cover risks of underground reservoir damage. Our insurance will not in all situations provide sufficient funds to protect us from all losses and liabilities that could result from our operations. Our coverage includes aggregate policy limits. As a result, we retain the risk for any loss in excess of these limits. No assurance can be given that insurance coverage will continue to be available at rates considered reasonable or that our coverage will respond to a specific loss. In addition, our insurance may not cover losses associated with pandemics such as the COVID-19 pandemic. Further, we may experience difficulties in collecting from our insurers or our insurers may deny all or a portion of our claims for insurance coverage.
If a significant accident or other event occurs and is not fully covered by insurance or an enforceable or recoverable indemnity from a customer, it could have a material adverse effect on our business, financial condition and results of operations.
Our business is subject to cybersecurity risks.
Our operations depend on effective and secure information technology systems. Threats to information technology systems, including as a result of cyberattacks and cyber incidents, continue to grow. Cybersecurity risks could include, but are not limited to, ransomware attacks, malicious software, attempts to gain unauthorized access to our data and the unauthorized release, corruption or loss of our data and personal information, interruptions in communication, loss of our intellectual property or theft of our FlexRig® and other sensitive or proprietary technology, loss or damage to our data delivery systems, or other cybersecurity and infrastructure systems, including our property and equipment. In response to the COVID-19 pandemic, the Company moved to a "remote work" model for office personnel in March 2020, and in 2021, the Company introduced full-time or part-time remote work as a permanent option for select employees. A significant number of our office employees work remotely. Remote work relies heavily on the use of remote networking and online conferencing services that enable employees to work outside of our corporate infrastructure and, in some cases, use their own personal devices, which exposes the Company to additional cybersecurity risks, including unauthorized access to sensitive information as a result of increased remote access and other cybersecurity related incidents.
These cybersecurity risks could:
disrupt our rig operations including operational technologies as well as our corporate information technology systems,
negatively impact our ability to compete,
enable the theft or misappropriation of funds,
cause the loss, corruption or misappropriation of proprietary or confidential information,
expose us to litigation, and
result in injury to our reputation, downtime, loss of revenue, and increased costs to prevent, respond to or mitigate cybersecurity events.
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It is possible that our business, financial and other systems could be compromised, which could go unnoticed for a prolonged period of time. While various procedures and controls are being utilized to mitigate exposure to such risk, there can be no assurance that the procedures and controls that we implement, or which we cause third party service providers to implement, will be sufficient to protect our systems, information or other property. Additionally, customers as well as other third parties upon whom we rely face similar cybersecurity threats, which could directly or indirectly impact our business and operations. The occurrence of a cyber incident or attack could have a material adverse effect on our business, financial condition and results of operations. Further, as cyber incidents continue to evolve, we may be required to incur additional costs to continue to modify or enhance our protective measures or to investigate or remediate the effects of cyber incidents.
Our acquisitions, dispositions and investments may not result in anticipated benefits and may present risks not originally contemplated, which may have a material adverse effect on our liquidity, consolidated results of operations and consolidated financial condition.
We continually seek opportunities to maximize efficiency and value through various transactions, including purchases or sales of assets, businesses, investments, or joint venture interests. For example, in November 2018 and August 2019, we completed the acquisitions of Angus Jamieson Consulting and DrillScan Energy SAS, respectively. These strategic transactions, among others, are intended to (but may not) result in the realization of savings, the creation of efficiencies, the offering of new products or services, the generation of cash or income, or the reduction of risk. Acquisition transactions may use cash on hand or be financed by additional borrowings or by the issuance of our common stock. These transactions may also affect our liquidity, consolidated results of operations and consolidated financial condition.
These transactions also involve risks, and we cannot ensure that:
any acquisitions we attempt will be completed on the terms announced, or at all;
any acquisitions would result in an increase in income or provide an adequate return of capital or other anticipated benefits;
any acquisitions would be successfully integrated into our operations and internal controls;
the due diligence conducted prior to an acquisition would uncover situations that could result in financial or legal exposure, or that we will appropriately quantify the exposure from known risks;
any disposition would not result in decreased earnings, revenue, or cash flow;
use of cash for acquisitions would not adversely affect our cash available for capital expenditures and other uses; or
any dispositions, investments, or acquisitions, including integration efforts, would not divert management resources.
We have allocated a portion of the purchase price of certain acquisitions to goodwill and other intangible assets. Generally, the amount allocated to goodwill is the excess of the purchase price over the net identifiable assets acquired. At September 30, 2021, we had goodwill of $45.7 million and other intangible assets, net of $73.8 million. If we experience future negative changes in our business climate or our results of operations such that we determine that goodwill or intangible assets are impaired, we will be required to record impairment charges with respect to such assets.
Technology disputes could negatively impact our operations or increase our costs.
Drilling rigs use proprietary technology and equipment which can involve potential infringement of a third party’s rights, or a third party’s infringement of our rights, including patent rights. The majority of the intellectual property rights relating to our drilling rigs and technology services are owned by us or certain of our supplying vendors.  From time to time, we or our customers or supplying vendors become involved in disputes over infringement of intellectual property rights relating to equipment or technology owned or used by us. As a result, we may lose access to important equipment or technology, be required to cease use of some equipment or technology, be forced to modify our drilling rigs or technology, or be required to pay license fees or royalties for the use of equipment or technology. In addition, we may lose a competitive advantage in the event we are unsuccessful in enforcing our rights against third parties, or third parties are successful in enforcing their rights against us. As a result, any technology disputes involving us or our customers or supplying vendors could have a material adverse impact on our business, financial condition and results of operations.
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Unexpected events could disrupt our business and adversely affect our results of operations.
Unexpected or unanticipated events, including, without limitation, computer system disruptions, unplanned power outages, fires or explosions at drilling rigs, natural disasters such as hurricanes and tornadoes, war or terrorist activities, supply disruptions, failure of equipment, changes in laws and/or regulations impacting our businesses, pandemic illness and other unforeseeable circumstances that may arise from our increasingly connected world or otherwise, could adversely affect our business.  It is not possible for us to predict the occurrence or consequence of any such events. However, any such events could create unforeseen liabilities, reduce our ability to provide drilling and related technology services, reduce demand for our services, or make it more difficult or costly to provide services, any of which may ultimately have a material adverse effect on our business, financial condition and results of operations.
Reliance on management and competition for experienced personnel may negatively impact our operations or financial results.
We greatly depend on the efforts of our executive officers and other key employees to manage our operations. Similarly, we utilize highly skilled personnel in operating and supporting our businesses and in developing new technologies. In times of high utilization, it can be difficult to find and retain qualified individuals and, during the recent period of sustained declines in oil and natural gas prices, there have been reductions in the oil field services workforce, both of which could result in higher labor costs. We may also face a loss of workers and labor shortages as a result of vaccine mandates or requirements and enforcement of other COVID-19 regulations in jurisdictions where we operate. The loss of members of management or the inability to attract and retain qualified personnel could have a material adverse effect on our business, financial condition and results of operations. In addition, the unexpected loss of members of management, qualified personnel or a significant number of employees due to disease, including COVID-19, disability, or death, could have a detrimental effect on us.
The loss of one or a number of our large customers could have a material adverse effect on our business, financial condition and results of operations.
In fiscal year 2021, we received approximately 50 percent of our consolidated operating revenues from our ten largest drilling services and solutions customers and approximately 23 percent of our consolidated operating revenues from our three largest customers (including their affiliates). If one or more of our larger customers terminated their contracts, failed to renew existing contracts with us, or refused to award us with new contracts, it could have a material adverse effect on our business, financial condition and results of operations. Further, consolidation among oil and natural gas exploration and production companies may reduce the number of available customers.
Our current backlog of drilling services and solutions revenue may continue to decline and may not be ultimately realized as fixed‑term contracts and may, in certain instances, be terminated without an early termination payment.
Fixed‑term drilling contracts customarily provide for termination at the election of the customer, with an “early termination payment” to be paid to us if a contract is terminated prior to the expiration of the fixed term. However, under certain limited circumstances, such as destruction of a drilling rig, our bankruptcy, sustained unacceptable performance by us or delivery of a rig beyond certain grace and/or liquidated damage periods, no early termination payment would be paid to us. Even if an early termination payment is owed to us, a customer may be unable or may refuse to pay the early termination payment. We also may not be able to perform under these contracts due to events beyond our control, and our customers may seek to cancel or renegotiate our contracts for various reasons, such as depressed market conditions. As of September 30, 2021, our drilling services backlog was approximately $572.0 million for future revenues under firm commitments. Our drilling services backlog may decline over time as existing contract term coverage may not be offset by new term contracts or price modifications for existing contracts, as a result of any number of factors, such as low or declining oil prices and capital spending reductions by our customers. Our inability or the inability of our customers to perform under our or their contractual obligations may have a material adverse impact on our business, financial condition and results of operations.
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Our contracts with national oil companies may expose us to greater risks than we normally assume in contracts with non-governmental customers.
We currently own and operate rigs and have deployed technology under contracts with foreign national oil companies.  In the future, we may expand our international solutions operations and enter into additional, significant contracts with national oil companies.  The terms of these contracts may contain non-negotiable provisions and may expose us to greater commercial, political, operational and other risks than we assume in other contracts.  Foreign contracts may expose us to materially greater environmental liability and other claims for damages (including consequential damages) and personal injury related to our operations, or the risk that the contract may be terminated by our customer without cause on short-term notice, contractually or by governmental action, or under certain conditions that may not provide us with an early termination payment.  We can provide no assurance that increased risk exposure will not have an adverse impact on our future operations or that we will not increase the number of rigs contracted, or the amount of technology deployed, to national oil companies with commensurate additional contractual risks.  Risks that accompany contracts with national oil companies could ultimately have a material adverse impact on our business, financial condition and results of operations.
Our drilling services operating expense includes fixed costs that may not decline in proportion to decreases in rig utilization and dayrates.
Our drilling services operating expense includes all direct and indirect costs associated with the operation, maintenance and support of our drilling equipment, which is often not affected by changes in dayrates and utilization.  During periods of reduced revenue and/or activity, certain of our fixed costs (such as depreciation) may not decline and often we may incur additional costs.  During times of reduced utilization, reductions in costs may not be immediate as we may incur additional costs associated with maintaining and cold stacking a rig, or we may not be able to fully reduce the cost of our support operations in a particular geographic region due to the need to support the remaining drilling rigs in that region. Accordingly, a decline in revenue due to lower dayrates and/or utilization may not be offset by a corresponding decrease in drilling services and solutions expense, which could have a material adverse impact on our business, financial condition and results of operations.
We depend on a limited number of vendors, some of which are thinly capitalized, and the loss of any of which could disrupt our operations.
Certain key rig components, parts and equipment are either purchased from or fabricated by a limited number of vendors, and we have limited long‑term contracts with many of these vendors. Shortages could occur in these essential components due to an interruption of supply, the acquisition of a vendor by a competitor, increased demands in the industry or other reasons beyond our control. Similarly, certain key rig components, parts and equipment are obtained from vendors that are, in some cases, thinly capitalized, independent companies that generate significant portions of their business from us or from a small group of companies in the energy industry. These vendors may be disproportionately affected by any loss of business, downturn in the energy industry, supply chain disruptions, or reduction or unavailability of credit. If we are unable to procure certain of such rig components, parts or equipment, our ability to maintain, improve, upgrade or construct drilling rigs could be impaired, which could have a material adverse effect on our business, financial condition and results of operations.
Shortages of drilling equipment, supplies or other key materials could adversely affect our operations.
The drilling services and solutions business is highly cyclical. During periods of increased demand for drilling services and solutions and periods of supply chain disruption, including as a result of COVID-19, delays in delivery and shortages of drilling equipment and supplies can occur. Suppliers may experience quality control issues as they seek to rapidly increase production of equipment and supplies necessary for our operations. Additionally, suppliers may seek to increase prices for equipment and supplies, which we are unable to pass through to our customers, either due to contractual obligations or market constraints in the drilling services and solutions business. These risks are intensified during periods when the industry experiences significant new drilling rig construction or refurbishment. Additionally, in recent months, there have been a number of disruptions and delays across the global supply chain, which have created a tightening of supplies and shortages in a number of areas, including basic raw materials. Any such delays or shortages could have a material adverse effect on our business, financial condition and results of operations.
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Unionization efforts and labor regulations in certain countries in which we operate could materially increase our costs or limit our flexibility.
Certain of our international employees are unionized, and efforts may be made from time to time to unionize other portions of our workforce.  We may in the future be subject to strikes or work stoppages and other labor disruptions in connection with unionization efforts or renegotiation of existing contracts with unions representing our international employees. For example, worker strikes of short duration are common in Argentina and our operations have experienced such strikes in the past. Additional unionization efforts, if successful, new collective bargaining agreements or work stoppages could materially increase our labor costs, reduce our revenues or limit our operational flexibility.
Improvements in or new discoveries of alternative energy technologies could have a material adverse effect on our financial condition and results of operations.
Since our business depends on the level of activity in the oil and natural gas industry, any improvement in or new discoveries of alternative energy technologies that increase the use of alternative forms of energy and reduce the demand for oil and natural gas could have a material adverse effect on our business, financial condition and results of operations.
Our business and results of operations may be adversely affected by foreign political, economic and social instability risks, foreign currency restrictions and devaluation, and various local laws associated with doing business in certain foreign countries.
We currently have drilling operations in South America (primarily Argentina and Colombia) and the Middle East. In the future, we may further expand the geographic reach of our operations. As a result, we are exposed to certain political, economic and other uncertainties not encountered in U.S. operations, including increased risks of social unrest, strikes, terrorism, war, kidnapping of employees, nationalization, forced negotiation or modification of contracts, difficulty resolving disputes (including technology disputes) and enforcing contract provisions, expropriation of equipment as well as expropriation of oil and gas exploration and drilling rights, taxation policies, foreign exchange restrictions and restrictions on repatriation of income and capital, currency rate fluctuations, increased governmental ownership and regulation of the economy and industry in the markets in which we operate, economic and financial instability of national oil companies, and restrictive governmental regulation, bureaucratic delays and general hazards associated with foreign sovereignty over certain areas in which operations are conducted.
South American countries, in particular, have historically experienced uneven periods of economic growth, as well as recession, periods of high inflation and general economic and political instability.  From time to time, these risks have impacted our business.  For example, in Argentina, while our dayrate is denominated in U.S. dollars, we are paid in Argentine pesos.  The Argentine branch of one of our second-tier subsidiaries then remits U.S. dollars to its U.S. parent by converting the Argentine pesos into U.S. dollars through the Argentine Foreign Exchange Market and repatriating the U.S. dollars. Argentina also has a history of implementing currency controls, which restrict the conversion and repatriation of U.S. dollars, including controls implemented from September 2019 through 2021. As a result of these currency controls, our ability to remit funds from our Argentine subsidiary to its U.S. parent has been limited. Argentina’s economy is currently considered highly inflationary, which is defined as cumulative inflation rates exceeding 100% in the most recent three-year period based on inflation data published by the respective governments.  Nonetheless, all of our foreign operations use the U.S. dollar as the functional currency and local currency monetary assets and liabilities are remeasured into U.S. dollars with gains and losses resulting from foreign currency transactions included in current results of operations. For fiscal year 2021, we experienced aggregate foreign currency losses of $5.4 million in Argentina.  Our aggregate foreign currency losses across all of our operations for fiscal years 2021 and 2020 were $5.3 million and $8.8 million, respectively. However, in the future, we may incur larger currency devaluations, foreign exchange restrictions or other difficulties repatriating U.S. dollars from Argentina or elsewhere, which could have a material adverse impact on our business, financial condition and results of operations.
Additionally, there can be no assurance that there will not be changes in local laws, regulations and administrative requirements or the interpretation thereof, which could have a material adverse effect on the profitability of our operations or on our ability to continue operations in certain areas. Because of the impact of local laws, our future operations in certain areas may be conducted through entities in which local citizens own interests and through entities (including joint ventures) in which we have limited control or hold only a minority interest or pursuant to arrangements under which we conduct operations under contract to local entities. There can be no assurance that we will in all cases be able to structure or restructure our operations to conform to local law (or the administration thereof) on terms we find acceptable.
The future occurrence of one or more international events arising from the types of risks described above could have a material adverse impact on our business, financial condition and results of operations.
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FINANCIAL RISKS
Covenants in our debt agreements restrict our ability to engage in certain activities.
Our current debt agreements pertaining to certain long‑term unsecured debt and our unsecured revolving credit facility contain, and our future financing arrangements likely will contain, various covenants that may in certain instances restrict our ability to, among other things, incur, assume or guarantee additional indebtedness, incur liens, sell or otherwise dispose of all or substantially all of our assets, enter into new lines of business, and merge or consolidate. In addition, our credit facility requires us to maintain a funded leverage ratio (as defined therein) of less than or equal to 50 percent and certain priority debt (as defined therein) may not exceed 17.5 percent of our net worth (as defined therein). Such restrictions may limit our ability to successfully execute our business plans, which may have adverse consequences on our operations.
We may be required to record impairment charges with respect to our drilling rigs and other assets.
We evaluate our drilling rigs and other assets for impairment whenever events or changes in circumstances indicate that the carrying amount of an asset may not be recoverable. Lower utilization and dayrates adversely affect our revenues and profitability. Prolonged periods of low utilization and dayrates may result in the recognition of impairment charges if future cash flow estimates, based upon information available to management at the time, indicate that the carrying value of an asset group may not be recoverable. Drilling rigs in our fleet may become impaired in the future if oil and gas prices decline or remain low for a prolonged period of time or if market conditions deteriorate or if we restructure our drilling fleet. For example, in fiscal years 2021 and 2020, we recognized impairment charges of $70.9 million and $563.2 million, respectively, related to tangible assets and equipment. If we experience future negative changes in our business climate such that we determine that one or more of our asset groups are impaired, we will be required to record additional impairment charges with respect to such asset groups.
Any impairment could have a material adverse effect on our consolidated financial statements. The facts and circumstances included in our impairment assessments are described in Part II, Item 8—"Financial Statements and Supplementary Data."
A downgrade in our credit ratings could negatively impact our cost of and ability to access capital.
Our ability to access capital markets or to otherwise obtain sufficient financing is enhanced by our senior unsecured debt ratings as provided by major U.S. credit rating agencies. Factors that may impact our credit ratings include debt levels, liquidity, asset quality, cost structure, commodity pricing levels, industry conditions and other considerations, including the impact of COVID-19. A ratings downgrade could adversely impact our ability in the future to access debt markets, increase the cost of future debt, and potentially require us to post letters of credit for certain obligations.
Our ability to access capital markets could be limited.
From time to time, we may need to access capital markets to obtain financing. Our ability to access capital markets for financing could be limited by oil and gas prices, our existing capital structure, our credit ratings, the state of the economy, the health or market perceptions of the drilling and overall oil and gas industry, the liquidity of the capital markets and other factors, including the impact of COVID-19. Many of the factors that affect our ability to access capital markets are outside of our control. No assurance can be given that we will be able to access capital markets on terms acceptable to us when required to do so, which could have a material adverse impact on our business, financial condition and results of operations.
Our marketable securities may lose significant value due to credit, market and interest rate risks.
The value of our marketable securities and our investment in ADNOC Drilling Company P.J.S.C are subject to general credit, liquidity, market and interest rate risks, which may be exacerbated by unusual events, such as the COVID-19 pandemic and political instability. A significant loss in value of our investments would negatively impact our debt ratio and financial strength.
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We may not be able to generate cash to service all of our indebtedness and may be forced to take other actions to satisfy our obligations.
Our ability to make future scheduled payments on or to refinance our debt obligations, including any future debt obligations, depends on our financial position, results of operations and cash flows. We may not be able to maintain a level of cash flows from operating activities sufficient to permit us to pay the principal and interest on our indebtedness. If our cash flows and capital resources are insufficient to fund our debt service obligations, we may be forced to reduce or delay investment decisions and capital expenditures, sell assets, seek additional capital or restructure or refinance our indebtedness. Furthermore, these alternative measures may not be successful and may not permit us to meet our scheduled debt service obligations. Our ability to restructure or refinance our debt will depend on the condition of the capital markets and our financial position at such time. Any refinancing of our debt could be at higher interest rates and may require us to comply with more onerous covenants, which could further restrict our business operations. Any failure to make payments of interest and principal on our outstanding indebtedness on a timely basis would be a default (if not waived) and would likely result in a reduction of our credit rating, which could harm our ability to seek additional capital or restructure or refinance our indebtedness.
Changes in the method of determining the London Interbank Offered Rate, or the replacement of the London Interbank Offered Rate with an alternative reference rate, may adversely affect interest expense related to outstanding debt.
Amounts drawn under our current debt agreements, including the 2018 Credit Facility (as defined herein), may bear interest at rates based on the London Interbank Offered Rate (“LIBOR”). On July 27, 2017, the United Kingdom's Financial Conduct Authority (the "FCA"), which regulates LIBOR, announced that it intends to phase out LIBOR as a benchmark by the end of 2021. On November 30, 2020, ICE Benchmark Administration ("IBA"), the administrator of LIBOR, with the support of the United States Federal Reserve and the FCA, announced a plan to consult on ceasing publication of U.S. dollar LIBOR on December 31, 2021 for only the one week and two month U.S. dollar LIBOR tenors, and on June 30, 2023 for all other U.S. dollar LIBOR tenors, which the FCA subsequently confirmed on March 5, 2021. The U.S. Federal Reserve concurrently issued a statement advising banks to stop new U.S. dollar LIBOR issuances by the end of 2021. Such announcements indicate that the continuation of LIBOR on the current basis cannot and will not be guaranteed after 2021. The 2018 Credit Facility provides for a mechanism to amend the facility to reflect the establishment of an alternative rate of interest upon the occurrence of certain events related to the phase-out of U.S. dollar LIBOR. However, we have not yet pursued any technical amendment or other contractual alternative to address this matter and are currently evaluating the impact of the potential replacement of the U.S. dollar LIBOR interest rate. The U.S. Federal Reserve, in conjunction with the Alternative Reference Rates Committee, a steering committee comprised of large U.S. financial institutions (the"ARRC"), has proposed a new index calculated by short term repurchase agreements, backed by Treasury securities called the Secured Overnight Financing Rate ("SOFR") as an alternative to LIBOR for use in contracts that are currently indexed to U.S. dollar LIBOR and has proposed a paced market transition plan to SOFR. On July 29, 2021, the ARRC formally recommended SOFR as its preferred alternative replacement rate for U.S. dollar LIBOR. Although SOFR appears to be the preferred replacement rate for U.S. dollar LIBOR at this time, it is not presently known whether SOFR or any other alternative reference rates that have been proposed will attain market acceptance as replacements of U.S. dollar LIBOR. In addition, the overall financial markets may be disrupted as a result of the phase-out or replacement of U.S. dollar LIBOR. Uncertainty as to the nature of such potential phase-out and alternative reference rates or disruption in the financial market could adversely affect the cost of our borrowings and interest expense related to outstanding floating-rate debt and could have an adverse effect on our financial condition, results of operations and cash flows.
LEGAL AND REGULATORY RISKS
The physical effects of climate change and the regulation of greenhouse gases and climate change could have a negative impact on our business.
The physical and regulatory effects of climate change and a global transition to a low carbon economy could have a negative impact on our operations, our customers’ operations and the overall demand for our customers' products and services. Scientific studies have suggested that emissions of certain gases, commonly referred to as “greenhouse gases” (“GHGs”) and including carbon dioxide and methane, may be contributing to warming of the earth’s atmosphere and other climatic changes. In response to such studies, the issue of climate change and the effect of GHG emissions, in particular emissions from fossil fuels, is attracting increasing attention worldwide and there are a number of political and technological initiatives aimed at reducing the use of hydrocarbons.
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We are aware of the increasing focus of local, state, regional, national and international regulatory bodies on GHG emissions and climate change issues. Legislation to regulate GHG emissions has periodically been introduced in the U.S. Congress and such legislation may be proposed or adopted in the future. In addition, in December 2015, the United States joined the international community at the 21st Conference of the Parties of the United Nations Framework Convention on Climate Change (the “UNFCCC”) in Paris, France in creating an agreement (the “Paris Agreement”) that requires member countries to review and “represent a progression” in their intended nationally determined GHG contributions, which set GHG emission reduction goals every five years beginning in 2020. The agreement entered into full force in November 2016. Effective November 4, 2020, the United States' withdrawal from the Paris Agreement, which had been announced by President Trump in June 2017, took effect. However, in January 2021, President Biden signed an instrument reversing this withdrawal and the United States officially rejoined the Paris Agreement on February 19, 2021.
The aim of the Paris Agreement is to hold the increase in the average global temperature to well below 2ºC (3.6ºF) above pre-industrial levels with efforts to limit the rise to 1.5ºC (2.7ºF) to protect against the more severe consequences of climate change forecasted by scientific studies. These consequences include increased coastal flooding, droughts and associated wildfires, heavy precipitation events, stresses on water supply and agriculture, increased poverty, and negative impacts on health. In connection with the decision to adopt the Paris Agreement, the UNFCCC invited the Intergovernmental Panel on Climate Change (the “IPCC”) to prepare a special report focused on the impacts of an increase in the average global temperature of 1.5ºC above pre-industrial levels and related GHG emission pathways. The 2018 IPCC Report concludes that the measures set forth in the Paris Agreement are insufficient and that more aggressive targets and measures will be needed. The 2018 IPCC Report indicates that GHGs must be reduced from 2010 levels by 45 percent by 2030 and 100 percent by 2050 to prevent global warming of 1.5ºC above pre-industrial levels. The IPCC's 2021 Report focusing on the physical science basis of climate change further concluded that an immediate and large-scale reduction in GHG emissions is necessary to limit global warming to 1.5ºC above pre-industrial levels.
It is not possible at this time to predict the timing and effect of climate change or whether additional GHG legislation, regulations or other measures will be adopted at the federal, state or local levels. However, more aggressive efforts by governments and non-governmental organizations to reduce GHG emissions appear likely based on the findings set forth in the 2018 and 2021 IPCC Reports and any such future laws and regulations could result in increased compliance costs, additional operating restrictions or affect the demand for our customers' products and, accordingly, our services. For example, a coalition of over 20 governors of U.S. states formed the United States Climate Alliance to advance the objectives of the Paris Agreement, and several U.S. cities have committed to advance the objectives of the Paris Agreement at the state or local level as well. To this end, the California governor issued an executive order on September 23, 2020 ordering actions to pursue GHG emissions reductions, including a direction to the California State Air Resources Board to develop and propose regulations to require increasing volumes of new zero-emission passenger vehicles and trucks sold in California over time, with a targeted ban of the sale of new gasoline vehicles by 2035. If we are unable to recover or pass through a significant level of our costs related to complying with climate change regulatory requirements imposed on us, it could have a material adverse impact on our business, financial condition and results of operations. Further, to the extent financial markets view climate change and GHG emissions as a financial risk, this could negatively impact our cost of or access to capital. Climate change and GHG regulation could also negatively impact the drilling programs of our customers and, consequently, delay, limit or reduce the services we provide. An increased focus by the public on the reduction of GHG emissions as well as the results of the physical impacts of climate change could affect the demand for our customers’ products and have a negative effect on our business.
Beyond financial and regulatory impacts, the projected severe effects of climate change have the potential to directly affect our facilities and operations and those of our customers. See above “—Our drilling and technology related operations are subject to a number of operational risks, including environmental and weather risks, which could expose us to significant losses and damage claims. We are not fully insured against all of these risks and our contractual indemnity provisions may not fully protect us.”
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New legislation and regulatory initiatives relating to hydraulic fracturing or other aspects of the oil and gas industry could negatively impact the drilling programs of our customers and, consequently, delay, limit or reduce the services we provide.
Several political and regulatory authorities, governmental bodies, and environmental groups devote resources to campaigns aimed at eradicating hydraulic fracking. We do not engage in any hydraulic fracturing activities. However, it is a common practice in our industry for our customers to recover natural gas and oil from shale and other formations through the use of horizontal drilling combined with hydraulic fracturing. Hydraulic fracturing is the process of creating or expanding cracks, or fractures, in formations using water, sand and other additives pumped under high pressure into the formation. The hydraulic fracturing process is typically regulated by state oil and natural gas commissions. Several states have adopted or are considering adopting regulations that could impose more stringent permitting, public disclosure, waste disposal and/or well construction requirements on oil and gas development, including hydraulic fracturing operations, or otherwise seek to ban fracturing activities altogether. In addition to state laws, some local municipalities have adopted or are considering adopting land use restrictions, such as city ordinances, that may restrict or prohibit the performance of well drilling in general and/or hydraulic fracturing in particular. Members of the U.S. Congress are analyzing, and a number of federal agencies have historically been requested to review, and, under the current administration, may be requested to review again, a variety of environmental issues associated with hydraulic fracturing and the possibility of more stringent regulation. At September 30, 2021, we had approximately 17 rigs placed on federal land and four rigs in federal waters. Any new laws, regulations or permitting requirements regarding hydraulic fracturing could negatively impact the drilling programs of our customers and, consequently, delay, limit or reduce the services we provide. For example, the Environmental Protection Agency has asserted federal regulatory authority pursuant to the federal Safe Drinking Water Act over certain hydraulic fracturing activities involving the use of diesel fuels. Widespread regulation significantly restricting or prohibiting hydraulic fracturing or other drilling activity by our customers could have a material adverse impact on our business, financial condition and results of operations.
Further, we conduct drilling activities in numerous states, including Oklahoma, where seismic activity may occur. In recent years, Oklahoma has experienced an increase in earthquakes. Although the extent of any correlation has been and remains the subject of studies of both federal and state agencies, some parties believe that there is a correlation between hydraulic fracturing related activities and the increased occurrence of seismic activity. As a result, federal and state legislatures and agencies may seek to further regulate, restrict or prohibit hydraulic fracturing activities. Increased regulation and attention given to the hydraulic fracturing process could lead to greater opposition to oil and gas production activities using hydraulic fracturing techniques, operational delays or increased operating and compliance costs in the production of oil and natural gas from shale plays, added difficulty in performing hydraulic fracturing, and potentially a decline in the completion of new oil and gas wells, which could negatively impact the drilling programs of our customers and, consequently, delay, limit or reduce the services we provide.
Failure to comply with the U.S. Foreign Corrupt Practices Act or foreign anti‑bribery legislation could adversely affect our business.
The U.S. Foreign Corrupt Practices Act (“FCPA”) and similar anti‑bribery laws in other jurisdictions, including the United Kingdom Bribery Act 2010, generally prohibit companies and their intermediaries from making improper payments to non-U.S. officials for the purpose of obtaining or retaining business. We operate in many parts of the world that have experienced governmental corruption to some degree and, in certain circumstances, strict compliance with anti‑bribery laws may conflict with local customs and practices and impact our business. Although we have programs in place requiring compliance with anti‑bribery legislation, any failure to comply with the FCPA or other anti‑bribery legislation could subject us to civil and criminal penalties or other sanctions, which could have a material adverse impact on our business, financial condition and results of operation. In addition, investors could negatively view potential violations, inquiries or allegations of misconduct under the FCPA or similar laws, which could adversely affect our reputation and the market for our shares. We could also face fines, sanctions and other penalties from authorities in the relevant foreign jurisdictions, including prohibition of our participating in or curtailment of business operations in those jurisdictions and the seizure of drilling rigs or other assets.
Our business is subject to complex and evolving laws and regulations regarding privacy and data protection.
The regulatory environment surrounding data privacy and protection is constantly evolving and can be subject to significant change. New laws and regulations governing data privacy and the unauthorized disclosure of confidential information pose increasingly complex compliance challenges and potentially elevate our costs. In the normal course of business, we and our third-party partners may collect, process, and store data that is subject to those specific laws and regulations governing personal data.

Complying with varying jurisdictional requirements is becoming increasingly complex and could increase the costs and difficulty of compliance, and violations of applicable data protection laws, including but not limited to the European Union General Data Protection Regulation (“GDPR”) and the California Consumer Privacy Act (“CCPA”), could result in significant penalties.

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The GDPR applies to activities regarding personal data that may be conducted by us, directly or indirectly through vendors and subcontractors, from an establishment in the European Union. As interpretation and enforcement of the GDPR evolves, it creates a range of new compliance obligations, which could cause us to incur costs or require us to change our business practices in a manner adverse to our business. Failure to comply could result in significant penalties of up to a maximum of 4% of our global turnover or up to $20.0 million Euro, which may materially adversely affect our business, reputation, results of operations, and cash flows.

The CCPA, which came into effect on January 1, 2020, gives California residents specific rights in relation to their personal information, requires that companies take certain actions, including notifications for security incidents and may apply to activities regarding personal information that is collected by us, directly or indirectly, from California residents. As interpretation and enforcement of the CCPA evolves, it creates a range of new compliance obligations, which could cause us to change our business practices, with the possibility for significant financial penalties for noncompliance that may materially adversely affect our business, reputation, results of operations, and cash flows.

Non-compliance with these and other data protection laws could expose us to regulatory investigations, which could result in fines and penalties. In addition to imposing fines, regulators may also issue orders to stop processing personal data, which could disrupt operations. We could also be subject to litigation from persons or corporations allegedly affected by data protection violations. In addition, we are also subject to the possibility of cyber incidents or attacks, potentially resulting in a violation of the laws mentioned above. Any violation of these laws or harm to our reputation could have a material adverse effect on our business, financial condition, results of operations and prospects.
Government policies, mandates, and regulations specifically affecting the energy sector and related industries, regulatory policies or matters that affect a variety of businesses, taxation polices, and political instability could adversely affect our financial condition and results of operations.
Energy production and trade flows are subject to government policies, mandates, regulations, and trade agreements. Governmental policies affecting the energy industry, such as taxes, tariffs, duties, price controls, subsidies, incentives, foreign exchange rates, economic sanctions and import and export restrictions, can influence the viability and volume of production of certain commodities, the volume and types of imports and exports, whether unprocessed or processed commodity products are traded, and industry profitability.  For example, the decision of the U.S. government to impose tariffs on certain Chinese imports and the resulting retaliation by the Chinese government imposing a 25 percent tariff on U.S. liquefied natural gas have disrupted aspects of the energy market. Disruptions of this sort can affect the price of oil and natural gas and may cause our customers to change their plans for exploration and production levels, in turn reducing the demand for our services. Moreover, many countries, including the United States, control the import and export of certain goods, services and technology and impose related import and export recordkeeping and reporting obligations.  Governments also may impose economic sanctions against certain countries, persons and other entities that may restrict or prohibit transactions involving such countries, persons and entities.  In particular, U.S. sanctions are targeted against certain countries that are heavily involved in the petroleum and petrochemical industries, which includes drilling activities.
Future government policies may adversely affect the supply of, demand for, and prices of oil and natural gas, restrict our ability to do business in existing and target markets, and adversely affect our business, financial condition and results of operations. The laws and regulations concerning import and export activity, recordkeeping and reporting, including customs, export controls and economic sanctions, are complex and constantly changing.  These laws and regulations may be enacted, amended, enforced or interpreted in a manner materially impacting our operations.  Ongoing economic challenges may increase some governments’ efforts to enact, enforce, amend or interpret laws and regulations as a method to increase revenue.  Shipments can be delayed and denied import or export for a variety of reasons, some of which are outside our control and some of which may result from failure to comply with existing legal and regulatory regimes.  Shipping delays or denials could cause unscheduled operational downtime.  Any failure to comply with applicable legal or regulatory requirements governing international trade could also result in criminal and civil penalties and sanctions, such as fines, imprisonment, debarment from government contracts, seizure of shipments and loss of import and export privileges.
Our business, financial condition and results of operations could be affected by political instability and by changes in other governmental policies, mandates, regulations, and trade agreements, including monetary, fiscal and environmental policies, laws, regulations, acquisition approvals, and other activities of governments, agencies, and similar organizations.  These risks include, but are not limited to, changes in a country’s or region’s economic or political conditions, local labor conditions and regulations, safety and environmental regulations, reduced protection of intellectual property rights, changes in the regulatory or legal environment, restrictions on currency exchange activities, currency exchange fluctuations, burdensome taxes and tariffs, enforceability of legal agreements and judgments, adverse tax, administrative agency or judicial outcomes, and regulation or taxation of greenhouse gases.  International risks and uncertainties, including changing social and economic conditions as well as terrorism, political hostilities, and war, could limit our ability to transact business in these markets and could adversely affect our business, financial condition and results of operations.
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Legal claims and litigation could have a negative impact on our business.
The nature of our business makes us susceptible to legal proceedings and governmental investigations from time to time. We design much of our own equipment and fabricate and upgrade such equipment in facilities that we operate. We also design and develop our own technology. If such equipment or technology fails to perform as expected, or if we fail to maintain or operate the equipment properly, there could be personal injuries, property damage, and environmental contamination, which could result in claims against us. Our ownership and use of proprietary technology and equipment could also result in infringement of intellectual property claims against us. See above “— Technology disputes could negatively impact our operations or increase our costs." The Company also owns and operates a large fleet of motor vehicles, which creates an increased exposure to motor vehicle accidents. Also, we may be subject, and have been subject in the past, to litigation resulting from accidents involving motor vehicles. These lawsuits have resulted, and may result in the future, in the payment of substantial settlements or damages and increases in our insurance costs. In addition, during periods of depressed market conditions we may be subject to an increased risk of our customers, vendors, former employees and others initiating legal proceedings against us. Further, actions or decisions we have taken or may take as a consequence of COVID-19 may result in investigations, litigation or legal claims against us. Lawsuits or claims against us could have a material adverse effect on our business, financial condition and results of operations. Any litigation or claims, even if fully indemnified or insured, could negatively impact our reputation among our customers and the public, and make it more difficult for us to compete effectively or obtain adequate insurance in the future.
Additional tax liabilities, limitations on our use of net operating losses and tax credits and/or our significant net deferred tax liability could affect our financial condition, income tax provision, net income, and cash flows.

We are subject to income taxes in the United States and numerous other jurisdictions. Significant judgment is required in determining our worldwide provision for income taxes and other tax liabilities. In the ordinary course of our business, there are many transactions and calculations where the ultimate tax determination is uncertain. We are regularly audited by tax authorities. Although we believe our tax estimates are reasonable, the final determination of tax audits and any related litigation could be materially different than what is reflected in income tax provisions and accruals. An audit or litigation could materially affect our financial position, income tax provision, net income, or cash flows in the period or periods challenged. Tax rates in the various jurisdictions in which our subsidiaries are organized and conduct their operations may change significantly as a result of political or economic factors beyond our control. It is also possible that future changes to tax laws (including tax treaties in any of the jurisdictions that we operate in) could impact our ability to realize the tax savings recorded to date. Our ability to benefit from our deferred tax assets depends on us having sufficient future taxable income to utilize our net operating loss and tax credit carryforwards before they expire. In addition, Section 382 of the Internal Revenue Code of 1986, as amended (“Section 382”), generally imposes an annual limitation on the amount of net operating losses and other pre-change tax attributes (such as tax credits) that may be used to offset taxable income by a corporation that has undergone an “ownership change” (as determined under Section 382). An ownership change generally occurs if one or more shareholders (or groups of shareholders) that are each deemed to own at least 5 percent of our stock change their ownership by more than 50 percentage points over their lowest ownership percentage during a rolling three-year period. As of September 30, 2021, we have not experienced an ownership change and, therefore, our utilization of our net operating loss carryforwards was not subject to an annual limitation (except for an immaterial portion thereof that we inherited in connection with an acquisition during 2017). However, if we were to experience ownership changes in the future as a result of subsequent shifts in our stock ownership, our ability to use our pre-change net operating loss carryforwards to offset future taxable income might be subject to limitations, which could potentially accelerate or permanently increase our future tax liabilities. Additionally, our future effective tax rates could be adversely affected by changes in tax laws (including tax treaties) or their interpretation, such as the proposals by the Biden administration to increase the U.S. corporate income tax rate and increase the U.S. taxation of international business operations.
Our deferred tax liability associated with property, plant and equipment is significant, which could materially increase the amount of cash income taxes that we pay in the future and, thus, adversely affect our cash flows. Our future capital expenditures, our results of operations and changes in income tax laws could significantly impact the timing of the reversal of our deferred tax liabilities and the timing and amount of our future cash income taxes. While management intends to minimize our income taxes payable in future years to the extent possible, the amount and timing of cash income taxes ultimately paid are based on the aforementioned factors as well as others and are subject to change.
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Failure to comply with or changes to governmental and environmental laws could adversely affect our business.
Many aspects of our operations are subject to various laws and regulations in the jurisdictions where we operate, including those relating to drilling practices and comprehensive and frequently changing laws and regulations relating to the safety and to the protection of human health and the environment. Environmental laws apply to the oil and gas industry including those regulating air emissions, discharges to water, and the transport, storage, use, treatment, disposal and remediation of, and exposure to, solid and hazardous wastes and materials. These laws can have a material adverse effect on the drilling industry, including our operations, and compliance with such laws may require us to make significant capital expenditures, such as the installation of costly equipment or operational changes, and may affect the resale values or useful lives of our drilling rigs. If we fail to comply with these laws and regulations, we could be exposed to substantial administrative, civil and criminal penalties, delays in permitting or performance of projects and, in some cases, injunctive relief. Violations of environmental laws may also result in liabilities for personal injuries, property and natural resource damage and other costs and claims. In addition, environmental laws and regulations in the United States impose a variety of requirements on “responsible parties” related to the prevention of oil spills and liability for damages from such spills. As an owner and operator of drilling rigs, we may be deemed to be a responsible party under these laws and regulations.
Additional legislation or regulation and changes to existing legislation and regulation may reasonably be anticipated, and the effect thereof on our operations cannot be predicted. The expansion of the scope of laws or regulations protecting the environment has accelerated in recent years, particularly outside the United States, and we expect this trend to continue. To the extent new laws are enacted or other governmental actions are taken that prohibit or restrict drilling in areas where we operate or impose additional environmental protection requirements that result in increased costs to the oil and gas industry, in general, or the drilling industry, in particular, our business or prospects could be materially adversely affected.
RISKS RELATED TO OUR COMMON STOCK AND CORPORATE STRUCTURE
We may reduce or suspend our dividend in the future.
We have paid a quarterly dividend for many years. Our most recent quarterly dividend was $0.25 per share. In the future, our Board of Directors may, without advance notice, determine to reduce or suspend our dividend in order to maintain our financial flexibility and best position the Company for long‑term success. The declaration and amount of future dividends is at the discretion of our Board of Directors and will depend on our financial condition, results of operations, cash flows, prospects, industry conditions, capital requirements and other factors and restrictions our Board of Directors deems relevant. The likelihood that dividends will be reduced or suspended is increased during periods of prolonged market weakness or uncertainty, such as the current downturn as a result of the COVID-19 pandemic and the oil price collapse in 2020. In addition, our ability to pay dividends may be limited by agreements governing our indebtedness now or in the future. There can be no assurance that we will not reduce our dividend or that we will continue to pay a dividend in the future.
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The market price of our common stock may be highly volatile, and investors may not be able to resell shares at or above the price paid.
The trading price of our common stock may be volatile. Securities markets worldwide experience significant price and volume fluctuations. This market volatility, as well as other general economic, market or political conditions, could reduce the market price of our common stock in spite of our operating or financial performance. The following factors, in addition to other factors described in this “Risk Factors” section and elsewhere in this Form 10-K, may have a significant impact on the market price of our common stock:
changes in customer needs, expectations or trends and our ability to maintain relationships with key customers;
our ability to implement our business strategy;
changes in our capital structure, including the issuance of additional debt;
public announcements (including the timing of these announcements) regarding our business, financial performance and prospects or new products or services, product enhancements, technological advances or strategic actions, such as acquisitions, restructurings or significant contracts, by our competitors or us;
trading activity in our stock, including portfolio transactions in our stock by us, our executive officers and directors, and significant stockholders or trading activity that results from the ordinary course rebalancing of stock indices in which we may be included;
short-interest in our common stock, which could be significant from time to time;
our inclusion in, or removal from, any stock indices;
investor perception of us and the industry and markets in which we operate;
increased focus by the investment community on sustainability practices at our company and in the oil and natural gas industry generally;
changes in earnings estimates or buy/sell recommendations by securities analysts;
whether or not we meet earnings estimates of securities analysts who follow us;
regulatory or legal developments in the United States and foreign countries where we operate; and
general financial, domestic, international, economic, and market conditions, including overall fluctuations in the U.S. equity markets.
Certain provisions of our corporate governing documents could make an acquisition of our company more difficult.
The following provisions of our charter documents, as currently in effect, and Delaware law could discourage potential proposals to acquire us, delay or prevent a change in control of us or limit the price that investors may be willing to pay in the future for shares of our common stock:
our certificate of incorporation permits our Board of Directors to issue and set the terms of preferred stock and to adopt amendments to our bylaws;
our bylaws contain restrictions regarding the right of stockholders to nominate directors and to submit proposals to be considered at stockholder meetings;
our bylaws restrict the right of stockholders to call a special meeting of stockholders; and 
we are subject to provisions of Delaware law which restrict us from engaging in any of a broad range of business transactions with an “interested stockholder” for a period of three years following the date such stockholder became classified as an interested stockholder.
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Public and investor sentiment towards climate change, fossil fuels and other ESG matters could adversely affect our cost of capital and the price of our common stock.

There have been intensifying efforts within the investment community (including investment advisors, investment fund managers, sovereign wealth funds, public pension funds, universities and individual investors) to promote the divestment of, or limit investment in, the stock of companies in the oil and gas industry. There has also been pressure on lenders and other financial services companies to limit or curtail financing of companies in the oil and gas industry. Because we operate within the oil and gas industry, if these efforts continue or expand, our stock price and our ability to raise capital may be negatively impacted.
Members of the investment community are increasing their focus on ESG practices and disclosures by public companies, including practices and disclosures related to climate change and sustainability, DE&I initiatives, and heightened governance standards. As a result, we may continue to face increasing pressure regarding our ESG disclosures and practices. These pressures have intensified recently in connection with the COVID-19 pandemic, significant societal events and the Biden Administration’s efforts to mitigate climate change. Additionally, members of the investment community may screen companies such as ours for ESG disclosures and performance before investing in our stock. Over the past few years, there has also been an acceleration in investor demand for ESG investing opportunities, and many large institutional investors have committed to increasing the percentage of their portfolios that are allocated towards ESG investments. With respect to any of these investors, our ESG disclosures and efforts may not satisfy the investor requirements or their requirements may not be made known to us. If we or our securities are unable to meet the ESG standards or investment criteria set by these investors and funds, we may lose investors or investors may allocate a portion of their capital away from us, our cost of capital may increase, and our stock price may be negatively impacted.
ITEM 1B. UNRESOLVED STAFF COMMENTS
We have received no written comments regarding our periodic or current reports from the staff of the SEC that were issued 180 days or more preceding the end of fiscal year 2021 and that remain unresolved.
ITEM 2. PROPERTIES
Drilling Services and Solutions Operations
Our property consists primarily of drilling rigs and ancillary equipment.  We own substantially all of the equipment used in our businesses.  For further information on the status of our drilling fleet, see Item 1— “Business — Drilling Fleet.”
Real Property
We own or lease office and yard space to support our ongoing operations, including field and district offices in the United States and internationally. In addition, we have a fabrication and assembly facility in Galena Park, Texas as well as a maintenance and overhaul facility near Tulsa, Oklahoma.
We also own a limited number of commercial real estate properties located in Tulsa, Oklahoma for investment purposes. Our real estate investments include a shopping center and undeveloped real estate.
ITEM 3. LEGAL PROCEEDINGS
See Note 16—Commitments and Contingencies to our Consolidated Financial Statements for information regarding our legal proceedings.
ITEM 4. MINE SAFETY DISCLOSURES
Not applicable.
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PART II
ITEM 5. MARKET FOR REGISTRANT’S COMMON EQUITY, RELATED STOCKHOLDER MATTERS AND ISSUER PURCHASES OF EQUITY SECURITIES
Market Information and Dividends
The principal market on which our common stock is traded is the New York Stock Exchange under the symbol “HP.”  As of November 8, 2021, there were 410 record holders of our common stock as listed by our transfer agent’s records.
We have paid quarterly cash dividends on our common stock during the past two fiscal years. Payment of future dividends will depend on earnings and other factors.
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Performance Graph
The following performance graph reflects the yearly percentage change in our cumulative total stockholder return on common stock as compared with the cumulative total return on the S&P 600 Index. All cumulative returns assume an initial investment of $100, the reinvestment of dividends and are calculated on a fiscal year basis ending on September 30 of each year.
INDEXED RETURNS
Base Period      Years Ending
Company / Index Sep 2016      Sep 2017      Sep 2018      Sep 2019      Sep 2020 Sep 2021
Helmerich & Payne, Inc. 100.00 82.00 111.00 72.00 38.00 58.00
S&P 600 Index 100.00 120.00   144.00   130.00   120.00   189.00
Dow Jones U.S. Select Oil Equipment & Services Index 100.00 93.00   95.00   49.00   24.00   42.00
Philadelphia Stock Exchange Oil Service Sector Index 100.00 88.00   94.00 44.00   22.00   40.00
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The above performance graph and related information shall not be deemed to be “soliciting material” or to be “filed” with the SEC or subject to Regulation 14A or 14C under the Exchange Act or to the liabilities of Section 18 of the Exchange Act, and shall not be deemed to be incorporated by reference into any filing under the Securities Act or the Exchange Act, except to the extent we specifically incorporate it by reference into such a filing.
Stock Portfolio
Information required by this item regarding our marketable securities may be found in, and is incorporated by reference to, Item 7— “Management’s Discussion and Analysis of Financial Condition and Results of Operations — Liquidity and Capital Resources — Investing Activities — Marketable Securities” included in this Form 10‑K.
ITEM 6. (REMOVED AND RESERVED)
Removed and reserved.
ITEM 7. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS
The following discussion should be read in conjunction with Part I of this Form 10‑K as well as the Consolidated Financial Statements and related notes thereto included in Part II, Item 8— “Financial Statements and Supplementary Data” of this Form 10‑K. Our future operating results may be affected by various trends and factors which are beyond our control. Our actual results may differ materially from those anticipated in these forward-looking statements as a result of a variety of risks and uncertainties, including those described in this Form 10-K under “Cautionary Note regarding Forward-Looking Statements” and Item 1A— “Risk Factors.” Accordingly, past results and trends should not be used by investors to anticipate future results or trends.
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Executive Summary
Helmerich & Payne, Inc. (“H&P,” which, together with its subsidiaries, is identified as the “Company,” “we,” “us,” or “our,” except where stated or the context requires otherwise) through its operating subsidiaries provides performance-driven drilling solutions and technologies that are intended to make hydrocarbon recovery safer and more economical for oil and gas exploration and production companies. As of September 30, 2021, our drilling rig fleet included a total of 273 drilling rigs. Our reportable operating business segments consist of the North America Solutions segment with 236 rigs, the Offshore Gulf of Mexico segment with seven offshore platform rigs and the International Solutions segment with 30 rigs as of September 30, 2021. At the close of fiscal year 2021, we had 137 contracted rigs, of which 73 were under a fixed-term contract and 64 were working well-to-well, compared to 79 contracted rigs at September 30, 2020. Our long-term strategy remains focused on innovation, technology, safety, operational excellence and reliability. As we move forward, we believe that our advanced uniform rig fleet, technology offerings, financial strength, contract backlog and strong customer and employee base position us very well to respond to continued cyclical and often times volatile market conditions and take advantage of future opportunities.
Market Outlook
Our revenues are derived from the capital expenditures of companies involved in the exploration, development and production of crude oil and natural gas (“E&Ps”). Generally, the level of capital expenditures is dictated by current and expected future prices of crude oil and natural gas, which are determined by various supply and demand factors. Both commodities have historically been, and we expect them to continue to be, cyclical and highly volatile.
With respect to North America Solutions, the resurgence of oil and natural gas production coming from the United States brought about by unconventional shale drilling for oil has significantly impacted the supply of oil and natural gas and the type of rig utilized in the U.S. land drilling industry. The advent of unconventional drilling for oil in the United States began in early 2009 and continues to evolve as E&Ps drill longer lateral wells with tighter well spacing. During this time, we designed, built and delivered to the market new technology AC drive rigs (FlexRig®), substantially growing our fleet. The pace of progress of unconventional drilling over the years has been cyclical and volatile, dictated by crude oil and natural gas price fluctuations, which at times have proven to be dramatic.
Throughout this time, the length of the lateral section of wells drilled in the United States has continued to grow. The progression of longer lateral wells has required many of the industry’s rigs to be upgraded to certain specifications in order to meet the technical challenges of drilling longer lateral wells. The upgraded rigs meeting those specifications are commonly referred to in the industry as super-spec rigs and have the following specific characteristics: AC drive, minimum of 1,500 horsepower drawworks, minimum of 750,000 lbs. hookload rating, 7,500 psi mud circulating system, and multiple-well pad capability.
The technical requirements of drilling longer lateral wells often necessitate the use of super-spec rigs and even when not required for shorter lateral wells, there is a strong customer preference for super-spec due to the drilling efficiencies gained in utilizing a super-spec rig. As a result, there has been a structural decline in the use of non-super-spec rigs across the industry. However, as a result of having a large super-spec fleet, we gained market share and became the largest provider of super-spec rigs in the industry. As such, we believe we are well positioned to respond to various market conditions.
In early March 2020, the increase in crude oil supply resulting from production escalations from the Organization of the Petroleum Exporting Countries and other oil producing nations ("OPEC+") combined with a decrease in crude oil demand stemming from the global response and uncertainties surrounding the COVID-19 pandemic resulted in a sharp decline in crude oil prices. Specifically, during calendar year 2020, crude oil prices fell from approximately $60 per barrel to the low-to-mid-$20 per barrel range, lower in some cases, which resulted in customers decreasing their 2020 capital budgets nearly 50 percent from calendar year 2019 levels. There was a corresponding dramatic decline in the demand for land rigs, such that the overall rig count for calendar year 2020 averaged roughly 430 rigs, significantly lower than in calendar year 2019, which averaged approximately 940 rigs.
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We experienced much of our rig count decline during the second and third quarters of fiscal year 2020 as our North American Solutions active rig count declined from 195 rigs at December 31, 2019 to a low of 47 rigs in August 2020. However, during the fourth quarter of fiscal year 2020, the market experienced a stabilization of crude oil prices in the $40 per barrel range and subsequently crude oil prices moved toward $50 per barrel as our customers set their capital budgets for calendar year 2021. More recently, crude oil prices have continued to increase, reaching more than $70 per barrel. That said, however, we do not expect rig activity to move in tandem with crude oil prices to the same extent as it has historically. This is primarily due to a large portion of our customers having a more disciplined approach to their operations and capital spending. We expect a majority will maintain their activity levels in accordance with their capital budgets for 2021, which were set during a time when crude oil prices were lower and will not adjust spending levels higher as crude oil prices move higher. Along with stabilization of crude prices during the fourth quarter of fiscal year 2020, our rig activity began to increase, and increased more significantly during the first and second quarters of fiscal year 2021. Our North America Solutions active rig count has more than doubled from 47 rigs in August 2020 to 127 rigs at September 30, 2021. We do anticipate further increases in our rig count for the remainder of calendar year 2021 as customers prepare for 2022 operations based upon the expectation that the level of capital spending will be higher in calendar year 2022 than it was in calendar year 2021.
Utilization for our super-spec FlexRig® fleet peaked in late calendar year 2018 with 216 of 221 super-spec rigs working (98 percent utilization); however, the subsequent decline in the demand for land rigs resulted in customers idling a large portion of our super-spec FlexRig® fleet. At September 30, 2021, we had 105 idle super-spec rigs out of our FlexRig® fleet of 230 super-spec rigs (54 percent utilization).
Collectively, our other business segments, Offshore Gulf of Mexico and International Solutions, are exposed to the same macro commodity price environment affecting our North America Solutions segment; however, activity levels in the International Solutions segment are also subject to other various geopolitical and financial factors specific to the countries of our operations. While we do not expect much change in our Offshore Gulf of Mexico segment, we see opportunities for improvement in our International Solutions segment, but those will likely occur on a more extended timeline compared to what we have experienced in the North America Solutions segment.
H&P recognizes the uncertainties and concerns caused by the COVID-19 pandemic; however, we have managed the Company over time to be in a position of strength both financially and operationally when facing uncertainties of this magnitude. The COVID-19 pandemic has had a significant financial impact on the Company, including increased costs as a result of labor shortages and logistics constraints. The global response to coping with the pandemic resulted in a drop in demand for crude oil, which, when combined with a more than adequate supply of crude oil, resulted in a sharp decline in crude oil prices, causing our customers to have pronounced pullbacks in their operations and planned capital expenditures. The direct impact of COVID-19 on H&P's operations has created some challenges that we believe the Company is adequately addressing to ensure a robust continuation of our operations albeit at a lower activity level.
The health and safety of all H&P stakeholders - our employees, customers, and vendors - remain a top priority at the Company. Accordingly, H&P has implemented additional policies and procedures designed to protect the well-being of our stakeholders and to minimize the impact of COVID-19 on our ongoing operations. We are adhering to Center for Disease Control guidelines for evaluating actual and potential COVID-19 exposures and we are complying with local governmental jurisdiction policies and procedures where our operations reside; in some instances, policies and procedures are more stringent in our foreign operations than in our North America operations and this resulted in a complete suspension, for a certain period of time, of all drilling operations in at least one foreign jurisdiction.
In the United States, the Company is an ‘essential critical infrastructure’ company as defined by the Department of Homeland Security and the Cybersecurity and Infrastructure Security Agency and, as such, continues to operate rigs and technology solutions, providing valuable services to our customers in support of the global energy infrastructure.
Since the COVID-19 outbreak began, no rigs have been fully shut down (other than temporary shutdowns for disinfecting) and such measures to disinfect facilities have not had a significant impact on service. We believe our service levels are unchanged from pre-pandemic levels.

From a financial perspective, we believe the Company is well positioned to continue as a going concern even through a more protracted disruption caused by COVID-19, oil oversupply and low oil prices. We have taken measures to reduce costs and capital expenditures to levels that better reflect a lower activity environment. The actions we took during fiscal year 2020 included a reduction to the annual dividend of approximately $200 million, a reduction of approximately $145 million in the fiscal year 2020 capital spend, a reduction of over $50 million in fixed operational overhead, and a reduction of selling, general and administrative expenses of more than $25 million on an annualized basis. The culmination of these cost-saving initiatives resulted in a $16 million restructuring charge during fiscal year 2020. Further, we took additional steps in fiscal year 2021 to reduce our cost structure. These measures will result in an estimated annualized savings of more than $10 million with the full benefit expected to be realized in calendar year 2022. We anticipate further cost reductions going forward; however, implementation of future cost initiatives will be incremental and are anticipated to be realized over the next few quarters. These cost reduction measures could lead to additional restructuring charges in future periods.
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At September 30, 2021, the Company had cash and cash equivalents and short-term investments of $1.1 billion and availability under the 2018 Credit Facility (as defined herein) of $750 million. On September 27, 2021, the Company delivered a conditional notice of optional full redemption for all of the outstanding 4.65% unsecured senior notes due 2025 (the "2025 Notes") at a redemption price calculated in accordance with the indenture governing the 2025 Notes, plus accrued and unpaid interest on the 2025 Notes to be redeemed. On September 29, 2021, we issued $550.0 million aggregate principal amount of our 2.90% unsecured senior notes due 2031 (the "2031 Notes"). The Company’s obligation to redeem the 2025 Notes was conditioned upon the prior consummation of the issuance of the 2031 Notes, which was satisfied on September 29, 2021. The proceeds from the offering of the 2031 Notes were used to redeem the 2025 Notes. On October 27, 2021, we redeemed all of the outstanding 2025 Notes. The associated make-whole premium and accrued interest of $58.1 million and the write off of the unamortized discount and debt issuance costs of $3.7 million will be recognized during the first fiscal quarter of 2022 contemporaneously with the October 27, 2021 redemption. Subsequent to the redemption, our near-term liquidity was approximately $1.3 billion. We currently do not anticipate the need to draw on the 2018 Credit Facility. See “—Liquidity and Capital Resources—Senior Notes—2.90% Senior Notes due 2031” below and Note 7—Debt to our Consolidated Financial Statements for more information.
    
    As part of the Company's normal operations, we regularly monitor the creditworthiness of our customers and vendors, screening out those that we believe have a high risk of failure to honor their counter-party obligations either through payment or delivery of goods or services. We also perform routine reviews of our accounts receivable and other amounts owed to us to assess and quantify the ultimate collectability of those amounts. At September 30, 2021 and September 30, 2020, the Company had a net allowance against its accounts receivable of $2.1 million and $1.8 million, respectively.

    The nature of the COVID-19 pandemic is inherently uncertain, and as a result, the Company is unable to reasonably estimate the duration and ultimate impacts of the pandemic, including the timing or level of any subsequent recovery. As a result, the Company cannot be certain of the degree of impact on the Company’s business, results of operations and/or financial position for future periods.
Recent Developments
Treasury and Investments
Senior Notes Offering and Redemption of 4.65% Senior Notes due 2025
On September 29, 2021, we completed our offering of $550.0 million aggregate principal amount of the 2031 Notes. We received net proceeds from the offering of the 2031 Notes of approximately $545.1 million, after deducting the initial purchasers’ discounts and commissions and offering expenses. In October 2021, the net proceeds from the offering were principally used to redeem all $487.1 million aggregate principal amount of our outstanding 2025 Notes. See “—Liquidity and Capital Resources—Senior Notes—2.90% Senior Notes due 2031” below and Note 7—Debt to our Consolidated Financial Statements for more information.

On September 27, 2021, the Company delivered a conditional notice of optional full redemption for all of the outstanding 4.65% unsecured senior notes due 2025 (the "2025 Notes") at a redemption price calculated in accordance with the indenture governing the 2025 Notes, plus accrued and unpaid interest on the 2025 Notes to be redeemed. On September 29, 2021, we issued $550.0 million aggregate principal amount of our 2.90% unsecured senior notes due 2031 (the "2031 Notes"). The Company’s obligation to redeem the 2025 Notes was conditioned upon the prior consummation of the issuance of the 2031 Notes, which was satisfied on September 29, 2021. The proceeds from the offering of the 2031 Notes were used to redeem the 2025 Notes. On October 27, 2021, we redeemed all of the outstanding 2025 Notes. The associated make-whole premium and accrued interest of $58.1 million and the write off of the unamortized discount and debt issuance costs of $3.7 million will be recognized during the first fiscal quarter of 2022 contemporaneously with the October 27, 2021 redemption. See “—Liquidity and Capital Resources—Senior Notes—4.65% Senior Notes due 2025” below and Note 7—Debt to our Consolidated Financial Statements for more information.
Credit Facility Maturity Extension
On April 16, 2021, lenders with $680.0 million of commitments under the 2018 Credit Facility exercised their option to extend the maturity of the 2018 Credit Facility from November 13, 2024 to November 12, 2025. No other terms of the 2018 Credit Facility were amended in connection with this extension. The remaining $70.0 million of commitments under the 2018 Credit Facility will expire on November 13, 2024, unless extended by the applicable lender before such date.
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ADNOC and Helmerich & Payne Strategic Alliance
During September 2021, the Abu Dhabi National Oil Company ("ADNOC") and its subsidiary ADNOC Drilling Company P.J.S.C ("ADNOC Drilling") and the Company jointly announced a strategic alliance, through which ADNOC Drilling acquired eight of our FlexRig® land rigs for $86.5 million. Following this transaction, H&P made a $100.0 million cornerstone investment in ADNOC Drilling's initial public offering subject to a three-year lock up period. Our investment is classified within Investments in our Consolidated Balance Sheets as of September 30, 2021. ADNOC Drilling’s IPO completed on October 3, 2021 and our $100.0 million investment represents 159.7 million shares of ADNOC Drilling, equivalent to a one percent ownership stake.
We will account for our investment in ADNOC Drilling prospectively, after the IPO date of October 3, 2021, as a marketable equity security with a readily determinable fair value. Fair value will be measured using a market approach on a recurring basis and is categorized using the fair value hierarchy. Any changes in such values will be reflected in net income. The availability of inputs observable in the market depends on a variety of factors, including the type of instrument, whether the instrument is actively traded and other characteristics particular to the transaction, which includes the effect of the lock-up period.
This alliance is intended to further drive ADNOC Drilling's growth and expansion as well as enhance their rig-based operational performance by providing them access to our world-class FlexRig® fleet and leveraging our expertise and technologies. Additionally, this alliance facilitates our goal of allocating capital international, particularly in the Middle East and North Africa region, by accelerating our access to the attractive and fast-growing Abu Dhabi market as a key platform for further regional expansion.
The eight rigs had an aggregate net book value of $55.6 million and were recorded as assets held-for-sale in our Consolidated Balance Sheets as of September 30, 2021. The rigs' fair value less estimated cost to sell of $29.0 million, including approximately $24.0 million of cash costs to be incurred, approximated their net book values at September 30, 2021. Two of the eight rigs were already located in the U.A.E where ADNOC Drilling is domiciled with the remaining six rigs to be shipped from the United States. As part of the sales agreement, the rigs will be delivered and commissioned in stages over a twelve-month period subject to acceptance upon successful completion of final inspection on customary terms and conditions. No rigs have been delivered to ADNOC Drilling as of September 30, 2021.
Property, Plant and Equipment
Sale of Offshore Rig
During the first quarter of fiscal year 2021, we closed on the sale of an offshore platform rig within our Offshore Gulf of Mexico operating segment for total consideration of $12.0 million with an aggregate net book value of $2.8 million, resulting in a gain of $9.2 million, which is included within (gain) loss on sale of assets on our Consolidated Statements of Operations during the fiscal year ended September 30, 2021.
Assets Held-for-Sale
In March 2021, the Company's leadership continued the execution of the current strategy, which was initially introduced in 2019, focusing on operating various types of highly capable upgraded rigs and phasing out the older, less capable fleet. As a result, the Company has undertaken a plan to sell 71 Domestic non-super-spec rigs, all within our North America Solutions segment, the majority of which were previously decommissioned, written down and/or held as capital spares. The book values of those assets were written down to $13.5 million, which represents the fair value less estimated cost to sell, and were reclassified as held-for-sale in the second and third quarter of fiscal year 2021. As a result, we recognized a non-cash impairment charge of $56.4 million, during the fiscal year ended September 30, 2021, in the Consolidated Statement of Operations. During the year ended September 30, 2021, we completed the sale of a portion of the assets with a net book value of $6.5 million that were originally classified as held-for-sale during the second and third quarter of fiscal year 2021.

During the fiscal year ended September 30, 2021, we formalized a plan to sell assets related to two of our lower margin service offerings, trucking and casing running services, which contributed approximately 2.8 percent to our consolidated revenue during fiscal year 2021, all within our North America Solutions segment. The combined net book values of these assets of $23.2 million were written down to their combined fair value less estimated cost to sell of $8.8 million, and were reclassified as held-for-sale in the Consolidated Balance Sheets as of September 30, 2021. As a result, we recognized a non-cash impairment charge of $14.4 million in the Consolidated Statement of Operations during the year ended September 30, 2021.
Subsequent to September 30, 2021, we closed on the sale of these assets in two separate transactions. The sale of our trucking services was completed on November 3, 2021 while the sale of our casing running services was completed on November 15, 2021 for combined cash consideration less costs to sell of $5.8 million in addition to the possibility of future earnout revenue.
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Restructuring
During the second quarter of fiscal year 2021, we reorganized our IT operations and moved select IT functions to a managed service provider. Costs incurred as of September 30, 2021 in connection with the restructuring are primarily comprised of one-time severance benefits to employees who were involuntarily terminated. The termination date of some of the employees extend beyond September 30, 2021, and such employees are required to render service through their respective termination date in order to receive the one-time severance benefit. During the third quarter of fiscal year 2021, we commenced a voluntary separation program at our local office in Argentina for which we incurred one-time severance charges for employees who were voluntarily terminated. Total costs incurred related to our IT reorganization and our Argentina separation program were $1.5 million for the fiscal year ended September 30, 2021.
Additionally, we continue to take measures to lower our cost structure based on activity levels. During fiscal year 2021, we incurred $4.5 million in one-time moving related expenses primarily due to the downsizing and relocation of our Houston assembly facility and various storage yards used for idle rigs. This together with additional restructuring activities that could result from our in-process cost management review could result in additional restructuring charges throughout the year.
Contract Backlog
Drilling contract backlog is the expected future dayrate revenue from executed contracts. We calculate backlog as the total expected revenue from fixed-term contracts and do not include any anticipated contract renewals or expected performance bonuses as part of its calculation. Additionally, contracts that currently contain month-to-month terms are represented in our backlog as one month of unsatisfied performance obligations. In addition to depicting the total expected revenue from fixed-term contracts, backlog is indicative of expected future cash flow that the Company expects to receive regardless of whether a customer honors the fixed-term contract to expiration of a contract or decides to terminate the contract early and pay an early termination payment. In the event of an early termination payment, the timing of the recognition of backlog and the total amount of revenue may differ; however, the overall associated cash flow is preserved. As such, management finds backlog a useful metric for future planning and budgeting, whereas investors consider it useful in estimating future revenue and cash flows of the Company. As of September 30, 2021 and 2020, our contract drilling backlog was $572.0 million and $658.0 million, respectively. These amounts do not include any anticipated contract renewals or expected performance bonuses. The decrease in backlog at September 30, 2021 from September 30, 2020 is primarily due to prevailing market conditions causing a decline in the number of longer term drilling contracts executed. Approximately 22.9 percent of the September 30, 2021 total backlog is reasonably expected to be fulfilled in fiscal year 2023 and thereafter.
Fixed-term contracts customarily provide for termination at the election of the customer, with an early termination payment to be paid to us if a contract is terminated prior to the expiration of the fixed term. As a result of the depressed market conditions and negative outlook for the near term, beginning in the second quarter of fiscal year 2020, certain of our customers, as well as those of our competitors, opted to renegotiate or early terminate existing drilling contracts. Such renegotiations included requests to lower the contract dayrate in exchange for additional terms, temporary stacking of the rig, and other proposals. We recognized $7.7 million and $73.4 million in early termination revenue associated with term contracts for the fiscal years ended September 30, 2021 and 2020, respectively.

The following table sets forth the total backlog by reportable segment as of September 30, 2021 and 2020, and the percentage of the September 30, 2021 backlog reasonably expected to be fulfilled in fiscal year 2023 and thereafter:
(in millions) September 30, 2021 September 30, 2020
Percentage Reasonably
Expected to be Fulfilled in Fiscal Year 2023
and Thereafter
North America Solutions $ 429.6  $ 542.4  17.4  %
Offshore Gulf of Mexico 17.2  16.7  — 
International Solutions 125.2  98.9  45.1 
  $ 572.0  $ 658.0    

The early termination of a contract may result in a rig being idle for an extended period of time, which could adversely affect our financial condition, results of operations and cash flows. In some limited circumstances, such as sustained unacceptable performance by us, no early termination payment would be paid to us. Early terminations could cause the actual amount of revenue earned to vary from the backlog reported. See Item 1A—"Risk Factors—Our current backlog of drilling services and solutions revenue may continue to decline and may not be ultimately realized as fixed‑term contracts and may, in certain instances, be terminated without an early termination payment” within this Form 10-K regarding fixed term contract risk. Additionally, see Item 1A—"Risk Factors—The impact and effects of public health crises, pandemics and epidemics, such as the COVID-19 pandemic, have adversely affected and are expected to continue to adversely affect our business, financial condition and results of operations" within this Form 10-K.
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Results of Operations for the Fiscal Years Ended September 30, 2021 and 2020
Consolidated Results of Operations
All per share amounts included in the Results of Operations discussion are stated on a diluted basis. Except as specifically discussed, the following results of operations pertain only to our continuing operations.
Net Loss We reported a loss from continuing operations of $337.5 million ($3.14 loss per diluted share) from operating revenues of $1.2 billion for the fiscal year ended September 30, 2021 compared to a loss from continuing operations of $496.4 million ($4.62 loss per diluted share) from operating revenues of $1.8 billion for the fiscal year ended September 30, 2020. Included in the net loss for the fiscal year ended September 30, 2021 is income of $11.3 million ($0.10 per diluted share) from discontinued operations. Including discontinued operations, we recorded a net loss of $326.2 million ($3.04 loss per diluted share) for the fiscal year ended September 30, 2021 compared to a net loss of $494.5 million ($4.60 loss per diluted share) for the fiscal year ended September 30, 2020.
Revenue Consolidated operating revenues were $1.2 billion in fiscal year 2021 and $1.8 billion in fiscal year 2020, including early termination revenue of $7.7 million and $73.4 million in each respective fiscal year. Excluding early termination revenue, operating revenue decreased $0.5 billion in fiscal year 2021 compared to fiscal year 2020. The decrease in fiscal year 2021 from fiscal year 2020 was driven by lower activity, lower early termination revenue, and lower average rig pricing.
Direct Operating Expenses, Excluding Depreciation and Amortization Direct operating expenses in fiscal year 2021 were $1.0 billion, compared with $1.2 billion in fiscal year 2020. The decrease in fiscal year 2021 from fiscal year 2020 was primarily attributable to the previously mentioned lower activity levels, partially offset by fixed overhead costs and higher rig recommissioning expenses, as we reactivated rigs across fiscal year 2021.
Depreciation and Amortization Depreciation and amortization expense was $419.7 million in fiscal year 2021 and $481.9 million in fiscal year 2020. The decrease in depreciation and amortization during fiscal year ended September 30, 2021 compared to fiscal year ended September 30, 2020 was primarily attributable to the lower carrying cost of our impaired assets as well as ongoing low levels of capital expenditures. Depreciation and amortization includes amortization of intangible assets of $7.2 million in fiscal years 2021 and 2020, and abandonments of equipment of $2.0 million and $4.0 million in fiscal years 2021 and 2020, respectively.
Research and Development For the fiscal years ended September 30, 2021 and 2020, we incurred $21.7 million and $21.6 million, respectively, of research and development expenses.
Selling, General and Administrative Expense Selling, general and administrative expenses increased to $172.2 million in the fiscal year ended September 30, 2021 compared to $167.5 million in the fiscal year ended September 30, 2020. The $4.7 million increase in fiscal year 2021 compared to fiscal year 2020 is primarily due to higher accrued variable compensation expense and professional service fees.
Asset Impairment During the fiscal year ended September 30, 2021, we undertook a plan to sell 71 Domestic non-super-spec rigs, all within our North America Solutions segment, the majority of which were previously decommissioned, written down and/or held as capital spares. This resulted in an impairment charge of $56.4 million ($43.3 million, net of tax, or $0.40 per diluted share. During the fiscal year ended September 30, 2021, we formalized a plan to sell assets related to two of our lower margin service offerings, trucking and casing running services, all within our North America Solutions segment. The combined book values of these assets were written down to $8.8 million, which represents their combined fair value less cost to sell, and were reclassified as held-for-sale in the Consolidated Balance Sheets as of September 30, 2021. As a result, we recognized a non-cash impairment charge of $14.4 million ($10.9 million, net of tax, or $0.10 per diluted share). Comparatively, during the fiscal year ended September 30, 2020, we recorded an asset impairment charge of $563.2 million ($437.5 million, net of tax, or $5.21 per diluted share) resulting from impairment of several assets including rotational inventory, property, plant and equipment, and goodwill.
Restructuring Charges During the fiscal years ended September 30, 2021 and 2020, we incurred $5.9 million and $16.0 million, respectively, in restructuring charges. The charges incurred during the fiscal year ended September 30, 2021 included $1.5 million in one-time severance benefits paid to employees who were voluntarily or involuntarily terminated primarily as a result of the reorganization of our IT operations coupled with charges of $4.5 million primarily related to the relocation of our Houston assembly facility and the downsizing of our storage yards used for idle rigs. The charges incurred during the fiscal year ended September 30, 2020 were primarily comprised of $19.5 million in one-time severance benefits to employees who were voluntarily or involuntarily terminated, offset by a benefit of $3.5 million related to forfeitures and modifications of stock-based compensation awards.
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Interest and Dividend Income Interest and dividend income was $10.3 million and $7.3 million in fiscal years 2021 and 2020, respectively. The increase in interest and dividend income in fiscal year 2021 was primarily due to $3.2 million of interest income received from the U.S. Department of the Treasury related to a tax refund, partially offset by lower interest rates.
Interest Expense Interest expense totaled $24.0 million in fiscal year 2021 and $24.5 million in fiscal year 2020. Interest expense is primarily attributable to fixedrate debt outstanding.
Income Taxes We had an income tax benefit of $103.7 million in fiscal year 2021 compared to an income tax benefit of $140.1 million in fiscal year 2020. The effective income tax rate was 23.5 percent in fiscal year 2021 compared to 22.0 percent in fiscal year 2020. The effective rates differ from the U.S. federal statutory rate (21.0 percent for fiscal years 2021 and 2020) due to non-deductible permanent items, state and foreign income taxes, and adjustments to the deferred state income tax rate.
Deferred income taxes are provided for temporary differences between the financial reporting basis and the tax basis of our assets and liabilities. Recoverability of any tax assets are evaluated, and necessary allowances are provided. The carrying values of the net deferred tax assets are based on management’s judgments using certain estimates and assumptions that we will be able to generate sufficient future taxable income in certain tax jurisdictions to realize the benefits of such assets. If these estimates and related assumptions change in the future, additional valuation allowances may be recorded against the deferred tax assets resulting in additional income tax expense in the future. See Note 8—Income Taxes to our Consolidated Financial Statements for additional income tax disclosures.
Discontinued Operations Expenses incurred within the country of Venezuela are reported as discontinued operations. Our wholly-owned subsidiaries, Helmerich & Payne International Drilling Co. ("HPIDC") and Helmerich & Payne de Venezuela, C.A., filed a lawsuit in the United States District Court for the District of Columbia on September 23, 2011 against the Bolivarian Republic of Venezuela, Petroleos de Venezuela, S.A. and PDVSA Petroleo, S.A. We are seeking damages for the taking of our Venezuelan drilling business in violation of international law and for breach of contract. While there exists the possibility of realizing a recovery, we are currently unable to determine the timing or amounts we may receive, if any, or the likelihood of recovery. In March 2016, the Venezuelan government implemented the previously announced plans for a new foreign currency exchange system. Activity within discontinued operations for both fiscal years 2021 and 2020 is primarily a result of the impact of exchange rate fluctuations due to the remeasurement of an uncertain tax liability.
North America Solutions

The following table presents certain information with respect to our North America Solutions reportable segment:
(in thousands, except operating statistics) 2021      2020 % Change
Operating revenues $ 1,026,364  $ 1,474,380  (30.4) %
Direct operating expenses 773,507  942,277  (17.9)
Segment gross margin 252,857  532,103  (52.5)
Depreciation and amortization 392,415  438,039  (10.4)
Research and development 21,811  20,699  5.4 
Selling, general and administrative expense 51,089  53,714  (4.9)
Asset impairment charge 70,850  406,548  (82.6)
Restructuring charges 3,868  7,005  (44.8)
Segment operating loss $ (287,176) $ (393,902) (27.1)
Operating Statistics1:
        
Average active rigs 107  134  (20.1)
Number of active rigs at the end of period 127  69  84.1 
Number of available rigs at the end of period 236  262  (9.9)
Reimbursements of "out-of-pocket" expenses $ 113,897  $ 171,455  (33.6)
(1)These operating metrics allow investors to analyze the various components of segment financial results in terms of activity, utilization and other key results.  Management uses these metrics to analyze historical segment financial results and as the key inputs for forecasting and budgeting segment financial results.  Beginning in the first quarter of fiscal year 2021, these operating metrics replaced previously used per day metrics. As a result, prior year comparative information is also provided above.
Segment Gross Margin The North America Solutions segment gross margin was $252.9 million for the fiscal year ended September 30, 2021 compared to $532.1 million for the fiscal year ended September 30, 2020. The decrease was primarily driven by lower activity levels, lower early termination revenue, lower average rig pricing, and higher rig recommissioning expenses. Revenues were $1.0 billion and $1.5 billion in fiscal year 2021 and 2020, respectively. The decrease in operating revenue is primarily due to the factors mentioned above. Included in revenues for fiscal year 2021 is early termination revenue of $5.8 million
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compared to $68.8 million during fiscal year 2020. Fixed‑term contracts customarily provide for termination at the election of the customer, with an early termination payment to be paid to us if a contract is terminated prior to the expiration of the fixed term (except in limited circumstances including sustained unacceptable performance by us). Direct operating expenses decreased to $773.5 million during the fiscal year ended September 30, 2021 as compared to $942.3 million during the fiscal year ended September 30, 2020 primarily due to the factors mentioned above.
Depreciation Depreciation expense decreased to $392.4 million during the fiscal year ended September 30, 2021 as compared to $438.0 million during the fiscal year ended September 30, 2020. The decrease is primarily attributable to the absence of depreciation on the 71 rigs that were reclassified as held-for-sale during the second and third quarters of fiscal year 2021 and rig impairments during fiscal year 2020, in addition to ongoing low levels of capital expenditures.
Asset Impairment Charge During the fiscal year ended September 30, 2021, we undertook a plan to sell 71 Domestic non-super-spec rigs, all within our North America Solutions segment, the majority of which were previously decommissioned, written down and/or held as capital spares. This resulted in an impairment charge of $56.4 million ($43.3 million, net of tax, or $0.40 per diluted share. During the fiscal year ended September 30, 2021, we formalized a plan to sell assets related to two of our lower margin service offerings, trucking and casing running services, all within our North America Solutions segment. The combined net book values of these assets were written down to $8.8 million, which represents their combined fair value less cost to sell, and were reclassified as held-for-sale in the Consolidated Balance Sheets as of September 30, 2021. As a result, we recognized a non-cash impairment charge of $14.4 million ($10.9 million, net of tax, or $0.10 per diluted share). Comparatively, during the fiscal year ended September 30, 2020, we recorded an impairment charge of $406.5 million ($313.7 million, net of tax, or $3.76 per diluted share) resulting from our impairment of our Domestic Conventional, FlexRig3, and FlexRig4 asset groups, in addition to our in-progress drilling equipment, rotational inventory and goodwill.
Restructuring Charges For the fiscal years ended September 30, 2021 and 2020, we incurred $3.9 million and $7.0 million, respectively, in restructuring charges. The charges incurred during the fiscal year ended September 30, 2021 primarily included charges of $3.8 million related to the relocation of the Houston assembly facility and the downsizing of storage yards used for idle rigs. The charges incurred during the fiscal year ended September 30, 2020 were primarily comprised of $10.0 million in one-time severance benefits to employees who were voluntarily or involuntarily terminated, offset by a benefit of $3.0 million related to forfeitures and modifications of stock-based compensation awards.
Offshore Gulf of Mexico

The following table presents certain information with respect to our Offshore Gulf of Mexico reportable segment:
(in thousands, except operating statistics) 2021      2020      % Change
Operating revenues $ 126,399  $ 143,149    (11.7) %
Direct operating expenses 97,249  119,371    (18.5)
Segment gross margin 29,150  23,778  22.6 
Depreciation 10,557  11,681    (9.6)
Selling, general and administrative expense 2,624  3,365    (22.0)
Restructuring charges —  1,254  (100.0)
Segment operating income $ 15,969  $ 7,478    113.5 
Operating Statistics1:
 
Average active rigs   (20.0)
Number of active rigs at the end of period   (20.0)
Number of available rigs at the end of period   (12.5)
Reimbursements of "out-of-pocket" expenses $ 27,388  $ 30,436    (10.0)
(1)These operating metrics allow investors to analyze the various components of segment financial results in terms of activity, utilization and other key results.  Management uses these metrics to analyze historical segment financial results and as the key inputs for forecasting and budgeting segment financial results.  Beginning in the first quarter of fiscal year 2021, these operating metrics replaced previously used per day metrics. As a result, prior year comparative information is also provided above.
Segment Gross Margin During the fiscal year ended September 30, 2021, the Offshore Gulf of Mexico segment gross margin was $29.2 million compared to a gross margin of $23.8 million for the fiscal year ended September 30, 2020. This increase was driven by the absence of $4.2 million of bad debt expense that was incurred during the fiscal year ended September 30, 2020. We had an 11.7 percent decrease in operating revenue during the fiscal year ended September 30, 2021 compared to the fiscal year ended September 30, 2020. The decrease in operating revenue is primarily due to lower activity levels partially offset by the mix of rigs working as compared to being on standby or mobilization rates. Direct operating expenses decreased to $97.2 million during the fiscal year ended September 30, 2021 as compared to $119.4 million during the fiscal year ended September 30, 2020. The decrease was primarily driven by the factors described above.
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Restructuring Charges We did not incur any restructuring charges during the fiscal year ended September 30, 2021. During the fiscal year ended September 30, 2020, we incurred $1.3 million in restructuring charges. Charges incurred during the fiscal year ended September 30, 2020 primarily consisted of employee termination benefits that resulted from our reduction in staffing levels.
International Solutions

The following table presents certain information with respect to our International Solutions reportable segment:
(in thousands, except operating statistics) 2021      2020      % Change
Operating revenues $ 57,917  $ 144,185    (59.8) %
Direct operating expenses 68,672  124,791    (45.0)
Segment gross margin (10,755) 19,394  (155.5)
Depreciation 2,013  17,531    (88.5)
Selling, general and administrative expense 8,028  4,565    75.9 
Asset impairment charge —  156,686  (100.0)
Restructuring charges 207  2,980  (93.1)
Segment operating loss $ (21,003) $ (162,368)   (87.1)
    
Operating Statistics1:
Average active rigs 13    (61.5)
Number of active rigs at the end of period   20.0 
Number of available rigs at the end of period 30  32    (6.3)
Reimbursements of "out-of-pocket" expenses $ 6,693  $ 10,099  (33.7)
(1)These operating metrics allow investors to analyze the various components of segment financial results in terms of activity, utilization and other key results.  Management uses these metrics to analyze historical segment financial results and as the key inputs for forecasting and budgeting segment financial results.  Beginning in the first quarter of fiscal year 2021, these operating metrics replaced previously used per day metrics. As a result, prior year comparative information is also provided above.
Segment Gross Margin The International Solutions segment gross margin was $(10.8) million for the fiscal year ended September 30, 2021 compared to a gross margin of $19.4 million for the fiscal year ended September 30, 2020. The change was primarily driven by lower activity levels coupled with fixed minimum levels of country overhead during the fiscal year ended September 30, 2021. We had a 59.8 percent decrease in operating revenue during the fiscal year ended September 30, 2021 compared to the fiscal year ended September 30, 2020. The decrease in operating revenue is primarily due to lower activity levels. Direct operating expenses decreased to $68.7 million during the fiscal year ended September 30, 2021 as compared to $124.8 million during the fiscal year ended September 30, 2020 and was driven by the factors described above.
Asset Impairment Charge During the fiscal year ended September 30, 2021, we recorded no impairment charges. Comparatively, during the fiscal year ended September 30, 2020, we recorded an impairment charge of $156.7 million ($123.8 million, net of tax, or $1.45 per diluted share) resulting from our impairment of our International Conventional, FlexRig®3, and FlexRig®4 asset groups, in addition to rotational inventory.
Restructuring Charges For the fiscal years ended September 30, 2021 and 2020, we incurred $0.2 million and $3.0 million in restructuring charges, respectively. During the fiscal year ended September 30, 2021, we commenced a voluntary separation program at our local office in Argentina for which we incurred one-time severance charges for employees who were voluntarily terminated. Charges incurred during the fiscal year ended September 30, 2020 primarily consisted of employee termination benefits that resulted from our reduction in staffing levels.
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Other Operations

Results of our other operations, excluding corporate selling, general and administrative costs, corporate restructuring, and corporate depreciation, are as follows:
(in thousands) 2021      2020      % Change
Operating revenues $ 43,304  $ 49,114    (11.8) %
Direct operating expenses 50,064  41,027  22.0 
Gross margin (6,760) 8,087  (183.6)
Depreciation 1,426     1,241    14.9 
Research and development 127  946  (86.6)
Selling, general and administrative expense 1,205  1,237  (2.6)
Restructuring charges 186  260  (28.5)
Operating income (loss) $ (9,704) $ 4,403    (320.4)
Gross Margin On October 1, 2019, we elected to capitalize a new Captive insurance company to insure the deductibles for our domestic workers’ compensation, general liability and automobile liability claims programs, and to continue the practice of insuring deductibles from the Company's international casualty and rig property programs. Direct operating expenses consisted primarily of adjustments to accruals for estimated losses of $12.6 million and $16.4 million allocated to the Captive and rig and casualty insurance premiums of $21.9 million and $6.7 million during the fiscal years ended September 30, 2021 and 2020, respectively. The decrease in estimated losses is primarily due to actuarial valuation adjustments by our third-party actuary as well as lower activity levels. Intercompany premium revenues recorded by the Captive during the fiscal years ended September 30, 2021 and 2020 amounted to $35.4 million and $36.9 million, respectively, which were eliminated upon consolidation. 
Results of Operations for the Fiscal Years Ended September 30, 2020 and 2019
A discussion of our results of operations for the fiscal year ended September 30, 2020 compared to the fiscal year ended September 30, 2019 is included in Part II, Item 7— "Management's Discussion and Analysis of Financial Condition and Results of Operations" of our Annual Report on Form 10-K for the fiscal year ended September 30, 2020, filed with the Securities and Exchange Commission ("SEC") on November 20, 2020, and is incorporated by reference into this Form 10-K.
Liquidity and Capital Resources
Sources of Liquidity
Our sources of available liquidity include existing cash balances on hand, cash flows from operations, and availability under the 2018 Credit Facility. Our liquidity requirements include meeting ongoing working capital needs, funding our capital expenditure projects, paying dividends declared, and repaying our outstanding indebtedness. Historically, we have financed operations primarily through internally generated cash flows. During periods when internally generated cash flows are not sufficient to meet liquidity needs, we may utilize cash on hand, borrow from available credit sources, access capital markets or sell our investments.  Likewise, if we are generating excess cash flows or have cash balances on hand beyond our near-term needs, we may invest in highly rated short‑term money market and debt securities. These investments can include U.S. Treasury securities, U.S. Agency issued debt securities, corporate bonds and commercial paper, certificates of deposit and money market funds.
We may seek to access the debt and equity capital markets from time to time to raise additional capital, increase liquidity as necessary, fund our additional purchases, exchange or redeem senior notes, or repay any amounts under the 2018 Credit Facility. Our ability to access the debt and equity capital markets depends on a number of factors, including our credit rating, market and industry conditions and market perceptions of our industry, general economic conditions, our revenue backlog and our capital expenditure commitments.
The effects of the COVID-19 pandemic and the oil price collapse in 2020 have had significant adverse consequences for general economic, financial and business conditions, as well as for our business and financial position and the business and financial position of our customers, suppliers and vendors and may, among other things, impact our ability to generate cash flows from operations, access the capital markets on acceptable terms or at all and affect our future need or ability to borrow under the 2018 Credit Facility. In addition to our potential sources of funding, the effects of such global events may impact our liquidity or need to alter our allocation or sources of capital, implement additional cost reduction measures and further change our financial strategy. Although the COVID-19 pandemic and the oil price collapse could have a broad range of effects on our sources and uses of liquidity, the ultimate effect thereon, if any, will depend on future developments, which cannot be predicted at this time.
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Cash Flows
Our cash flows fluctuate depending on a number of factors, including, among others, the number of our drilling rigs under contract, the revenue we receive under those contracts, the efficiency with which we operate our drilling units, the timing of collections on outstanding accounts receivable, the timing of payments to our vendors for operating costs, and capital expenditures, all of which was impacted by the COVID-19 pandemic and the oil price collapse in 2020. As our revenues increase, operating net working capital is typically a use of capital, while conversely, as our revenues decrease, operating net working capital is typically a source of capital. To date, general inflationary trends have not had a material effect on our operating margins.
As of September 30, 2021, we had $917.5 million of cash and cash equivalents on hand and $198.7 million of short-term investments. Our cash flows for the fiscal years ended September 30, 2021, 2020 and 2019 are presented below:
Year Ended September 30,
(in thousands) 2021      2020 2019
Net cash provided by (used in):
Operating activities $ 136,440  $ 538,881  $ 855,751 
Investing activities (161,994) (87,885) (422,636)
Financing activities 425,523  (297,220) (376,329)
Net increase in cash and cash equivalents and restricted cash $ 399,969  $ 153,776  $ 56,786 
Operating Activities
For the purpose of understanding the impact on our cash flows from operating activities, operating net working capital is calculated as current assets, excluding cash and cash equivalents, short-term investments, and assets held-for-sale, less current liabilities, excluding dividends payable and the current portion of long-term debt. Operating net working capital was $43.4 million, $194.2 million and $381.7 million as of September 30, 2021, 2020 and 2019, respectively. The sequential decrease in net working capital was primarily driven by the receipt of the $86.5 million in cash consideration from ADNOC Drilling in advance of delivering the eight purchased rigs. The total cash proceeds were recorded within Accrued Liabilities within our Consolidated Balance Sheets as of September 30, 2021. This was partially offset by activity-driven increases in other components of our operating net working capital. Included in accounts receivable as of September 30, 2021 was $24.5 million of income tax receivables. Cash flows provided by operating activities were $136.4 million, $538.9 million and $855.8 million in fiscal years 2021, 2020 and 2019, respectively. The decrease in cash provided by operating activities is primarily driven by lower operating activity and lower pricing.
Investing Activities
Capital Expenditures Our capital expenditures were $82.1 million, $140.8 million and $458.4 million in fiscal years 2021, 2020 and 2019, respectively. The year-over-year decrease in capital expenditures is driven by lower maintenance capital expenditures as a result of lower activity. Our fiscal year 2022 capital spending is currently estimated to be between $250 million and $270 million. This estimate includes normal capital maintenance requirements, information technology spending and skidding to walking conversions for a limited number of rigs.
Purchase of Investments Our net (purchases) sales of investments were $(209.9) million, $(40.0) million and $1.1 million in fiscal years 2021, 2020 and 2019, respectively. The increase in purchases is attributable to our strategy to optimize our returns on investment, including our purchase of our cornerstone investment of $100.0 million in ADNOC Drilling.
Acquisition of Business We paid $16.2 million, net of cash acquired, during fiscal year 2019, for the acquisition of drilling technology companies.
Sale of Assets Our proceeds from asset sales totaled $43.5 million, $78.4 million and $50.8 million in fiscal year 2021, 2020 and 2019, respectively. During the fiscal year ended September 30, 2020, we closed on the sale of a portion of our real estate investment portfolio, including six industrial sites, for total consideration, net of selling related expenses, of $40.7 million.
Sale of Subsidiary In December 2019, we closed on the sale of a wholly-owned subsidiary of HPIDC, TerraVici Drilling Solutions, Inc. ("TerraVici"). As a result of the sale, 100% of TerraVici's outstanding capital stock was transferred to the purchaser in exchange for approximately $15.1 million, resulting in a total gain on the sale of TerraVici of approximately $15.0 million.
Equity Securities As of September 30, 2021, our equity securities primarily consist of common shares in Schlumberger, Ltd. that, at the close of fiscal year 2021, had a fair value of $13.9 million. The value of our securities is subject to fluctuation in the market and may vary considerably over time. This investment is recorded at fair value on our Consolidated Balance Sheets. Refer to Note 13—Fair Value Measurement of Financial Instruments to our Consolidated Financial Statements. In September 2019, we sold our remaining 1.6 million shares in Valaris, previously known as Ensco Rowan plc, for total proceeds of approximately $12.0 million.
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Advance payment for sale of property, plant and equipment During September 2021, the Company agreed to sell eight FlexRig land rigs with an aggregate net book value of $55.6 million to ADNOC Drilling for $86.5 million. Two of the eight rigs were already located in the U.A.E where ADNOC Drilling is domiciled with the remaining six rigs to be shipped from the United States. We received the $86.5 million in cash consideration in advance of delivering the rigs. As part of the sales agreement, the rigs will be delivered and commissioned in stages over a twelve-month period subject to acceptance upon successful completion of final inspection on customary terms and conditions. No rigs have been delivered to ADNOC Drilling as of September 30, 2021 and, therefore, the total cash proceeds of $86.5 million is recorded in Accrued Liabilities within our Consolidated Balance Sheets as of September 30, 2021.
Financing Activities
Repurchase of Shares We have an evergreen authorization from the Board of Directors (the "Board") for the repurchase of up to four million common shares in any calendar year. The repurchases may be made using our cash and cash equivalents or other available sources. We repurchased 1.5 million shares for $28.5 million during fiscal year 2020 and one million shares for $42.8 million during fiscal year 2019. There were no purchases of common shares in fiscal year 2021.
Dividends We paid dividends of $1.00, $2.38, and $2.84 per share during fiscal years 2021, 2020 and 2019, respectively. Total dividends paid were $109.1 million, $260.3 million and $313.4 million in fiscal years 2021, 2020 and 2019, respectively. A cash dividend of $0.25 per share was declared on September 1, 2021 for shareholders of record on November 23, 2021, payable on December 1, 2021. The declaration and amount of future dividends is at the discretion of the Board and subject to our financial condition, results of operations, cash flows, and other factors the Board deems relevant.
Debt Issuance Proceeds and Costs On September 29, 2021, we issued $548.7 million aggregate principal amount of the 2031 Notes in an offering to persons reasonably believed to be qualified institutional buyers in the United States pursuant to Rule 144A under the Securities Act (“Rule 144A”) and to certain non-U.S. persons in transactions outside the United States pursuant to Regulation S under the Securities Act (“Regulation S”). Debt issuance fees paid as of September 30, 2021 were $3.9 million. On October 27, 2021, we redeemed all of the outstanding 2025 Notes. The Company financed the redemption of the 2025 Notes with the net proceeds from the offering of the 2031 Notes, together with cash on hand. Additional details are fully discussed in Note 7—Debt.
Credit Facilities
On November 13, 2018, we entered into a credit agreement by and among the Company, as borrower, Wells Fargo Bank, National Association, as administrative agent, and the lenders party thereto, which was amended on November 13, 2019, providing for an unsecured revolving credit facility (as amended, the “2018 Credit Facility”), that was set to mature on November 13, 2024. On April 16, 2021, lenders with $680.0 million of commitments under the 2018 Credit Facility exercised their option to extend the maturity of the 2018 Credit Facility from November 13, 2024 to November 12, 2025. No other terms of the 2018 Credit Facility were amended in connection with this extension. The remaining $70.0 million of commitments under the 2018 Credit Facility will expire on November 13, 2024, unless extended by the applicable lender before such date.
The 2018 Credit Facility has $750.0 million in aggregate availability with a maximum of $75.0 million available for use as letters of credit. The 2018 Credit Facility also permits aggregate commitments under the facility to be increased by $300.0 million, subject to the satisfaction of certain conditions and the procurement of additional commitments from new or existing lenders. The borrowings under the 2018 Credit Facility accrue interest at a spread over either the London Interbank Offered Rate ("LIBOR") or an adjusted base rate (as defined in the credit agreement). We also pay a commitment fee on the unused balance of the facility. Borrowing spreads as well as commitment fees are determined based on the debt rating for senior unsecured debt of the Company, as determined by Moody’s and Standard & Poor's. The spread over LIBOR ranges from 0.875 percent to 1.500 percent per annum and commitment fees range from 0.075 percent to 0.200 percent per annum. Based on the unsecured debt rating of the Company on September 30, 2021, the spread over LIBOR would have been 1.125 percent had borrowings been outstanding under the 2018 Credit Facility and commitment fees are 0.125 percent. There is a financial covenant in the 2018 Credit Facility that requires us to maintain a total funded debt to total capitalization ratio of less than or equal to 50 percent. The 2018 Credit Facility contains additional terms, conditions, restrictions and covenants that we believe are usual and customary in unsecured debt arrangements for companies of similar size and credit quality, including a limitation that priority debt (as defined in the credit agreement) may not exceed 17.5 percent of the net worth of the Company. As of September 30, 2021, there were no borrowings or letters of credit outstanding, leaving $750.0 million available to borrow under the 2018 Credit Facility.
As of September 30, 2021, we had 3 separate outstanding letters of credit with banks, in the amounts of $24.8 million, $3.0 million and $2.1 million, respectively.
As of September 30, 2021, we also had a $20.0 million unsecured standalone line of credit facility, for the purpose of obtaining the issuance of international letters of credit, bank guarantees, and performance bonds. Of the $20.0 million, $7.6 million of financial guarantees were outstanding as of September 30, 2021.
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The applicable agreements for all unsecured debt contain additional terms, conditions and restrictions that we believe are usual and customary in unsecured debt arrangements for companies that are similar in size and credit quality. At September 30, 2021, we were in compliance with all debt covenants, and we anticipate that we will continue to be in compliance during the next quarter of fiscal year 2022.
Senior Notes

2.90% Senior Notes due 2031 On September 29, 2021, we issued $550.0 million aggregate principal amount of the 2.90 percent 2031 Notes in an offering to persons reasonably believed to be qualified institutional buyers in the United States pursuant to Rule 144A under the Securities Act (“Rule 144A”) and to certain non-U.S. persons in transactions outside the United States pursuant to Regulation S under the Securities Act (“Regulation S”). Interest on the 2031 Notes is payable semi-annually on March 29 and September 29 of each year, commencing on March 29, 2022. The 2031 Notes will mature on September 29, 2031 and bear interest at a rate of 2.90 percent annum.

Prior to June 29, 2031, the Company may redeem the 2031 Notes at its option, in whole or in part, at any time or from time to time at a redemption price equal to the greater of: (i) 100% of the principal amount of the 2031 Notes to be redeemed or (ii) the sum of the present values, as calculated by the Independent Investment Banker (as defined in the 2031 Notes Indenture (as defined herein)), of the remaining scheduled payments of principal and interest thereon (exclusive of the interest accrued to the redemption date) computed by discounting such payments to the redemption date on a semi-annual basis, assuming a 360-day year consisting of twelve 30-day months, at a rate equal to the sum of the Treasury Rate (as defined in the 2031 Notes Indenture) for such 2031 Notes plus 25 basis points, plus, in either case, accrued and unpaid interest, if any, to, but excluding, the redemption date (subject to the right of holders of record on the relevant record date to receive interest due on the relevant interest payment date).

On or after June 29, 2031, the Company may redeem the 2031 Notes at its option, in whole or in part, at any time or from time to time at a redemption price equal to 100% of the principal amount of the 2031 Notes to be redeemed, plus accrued and unpaid interest thereon to, but excluding, the redemption date (subject to the right of holders of record on the relevant record date to receive interest due on the relevant interest payment date).

The 2031 Notes were issued pursuant to an Indenture, dated as of December 20, 2018 (the “Base Indenture”), as supplemented by the Second Supplemental Indenture thereto, dated as of September 29, 2021 (together with the Base Indenture, the “2031 Notes Indenture”), in each case by and between the Company and Wells Fargo Bank, National Association, as trustee.
The 2031 Notes Indenture contains certain covenants that, among other things and subject to certain exceptions, limit the ability of the Company and its subsidiaries to incur certain liens; engage in sale and lease-back transactions; and consolidate, merge or transfer all or substantially all of the assets of the Company. The 2031 Notes Indenture also contains customary events of default with respect to the 2031 Notes.
4.65% Senior Notes due 2025 On December 20, 2018, we issued approximately $487.1 million in aggregate principal amount of the 2025 Notes. Interest on the 2025 Notes is payable semi-annually on March 15 and September 15 of each year, commencing on March 15, 2019. The debt issuance costs are being amortized straight-line over the stated life of the obligation, which approximated the effective interest method.

On September 27, 2021, the Company delivered a conditional notice of optional full redemption for all of the outstanding 2025 Notes at a redemption price calculated in accordance with the indenture governing the 2025 Notes, plus accrued and unpaid interest on the 2025 Notes to be redeemed. The Company financed the redemption of the 2025 Notes with the net proceeds from the offering of the 2031 Notes, together with cash on hand. The Company’s obligation to redeem the 2025 Notes was conditioned upon the prior consummation of the issuance of the 2031 Notes, which was satisfied on September 29, 2021.

On October 27, 2021, we redeemed all of the outstanding 2025 Notes. The associated make-whole premium and accrued interest of $58.1 million and the write off of the unamortized discount and debt issuance costs of $3.7 million will be recognized during the first fiscal quarter of 2022 contemporaneously with the October 27, 2021 redemption.
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Future Cash Requirements
Our operating cash requirements, scheduled debt repayments, interest payments, any declared dividends, and estimated capital expenditures for fiscal year 2022 are expected to be funded through current cash and cash to be provided from operating activities. However, there can be no assurance that we will continue to generate cash flows at current levels. If needed, we may decide to obtain additional funding from our $750.0 million 2018 Credit Facility. We currently do not anticipate the need to draw on the 2018 Credit Facility. Our indebtedness under our long-term unsecured senior notes totaled $550.0 million at September 30, 2021 and matures on September 29, 2031. 
As of September 30, 2021, we had a $563.4 million deferred tax liability on our Consolidated Balance Sheets, primarily related to temporary differences between the financial and income tax basis of property, plant and equipment. Our capital expenditures over the last several years have been subject to accelerated depreciation methods (including bonus depreciation) available under the Internal Revenue Code of 1986, as amended, enabling us to defer a portion of cash tax payments to future years. Future levels of capital expenditures and results of operations will determine the timing and amount of future cash tax payments. We expect to be able to meet any such obligations utilizing cash and investments on hand, as well as cash generated from ongoing operations.
At September 30, 2021, we had $4.6 million recorded for uncertain tax positions and related interest and penalties. However, the timing of such payments to the respective taxing authorities cannot be estimated at this time.
The long‑term debt to total capitalization ratio was 15.9 percent at September 30, 2021 compared to 12.8 percent at September 30, 2020. For additional information regarding debt agreements, refer to Note 7—Debt to our Consolidated Financial Statements.
Material Commitments
Our contractual obligations as of September 30, 2021 are summarized in the table below:
Payments due by year
(in thousands) Total 2022 2023 2024 2025 2026 Thereafter
Debt1
1,037,148  487,148  —  —  —  —  550,000 
Interest2
162,915  16,239  16,289  16,159  16,251  16,253  81,724 
Make-whole premium and accrued interest3
59,064  59,064  —  —  —  —  — 
Operating leases4
39,863  10,596  8,660  7,391  4,332  1,876  7,008 
Purchase obligations5
48,100  48,100  —  —  —  —  — 
Total contractual obligations $ 1,347,090  $ 621,147  $ 24,949  $ 23,550  $ 20,583  $ 18,129  $ 638,732 
(1)On October 27, 2021, we redeemed the $487.1 million outstanding 2025 Notes. See Note 7—Debt to our Consolidated Financial Statements.
(2)Interest on fixed-rate 2031 Notes was estimated based on principal maturities. See Note 7—Debt to our Consolidated Financial Statements.
(3)On October 27, 2021, we redeemed all of the outstanding 2025 Notes, which resulted in the payment of a make-whole premium and accrued interest on the 2025 Notes. See Note 7—Debt to our Consolidated Financial Statements.
(4)See Note 5—Leases to our Consolidated Financial Statements.
(5)See Note 16—Commitments and Contingencies to our Consolidated Financial Statements.
Critical Accounting Policies and Estimates

Accounting policies that we consider significant are summarized in Note 2—Summary of Significant Accounting Policies, Risks and Uncertainties to our Consolidated Financial Statements included in Part II, Item 8—"Financial Statements and Supplementary Data" of this Form 10-K. The preparation of our financial statements in conformity with U.S. GAAP requires management to make certain estimates and assumptions. These estimates and assumptions affect the reported amounts of assets, liabilities, revenues and expenses and related disclosures of contingent assets and liabilities. Estimates are based on historical experience and on various other assumptions that we believe to be reasonable under the circumstances, the results of which form the basis for making judgments about the carrying values of assets and liabilities that are not readily apparent from other sources. These estimates and assumptions are evaluated on an ongoing basis. Actual results may differ from these estimates under different assumptions or conditions. The following is a discussion of the critical accounting policies and estimates used in our financial statements.
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Property, Plant and Equipment
Property, plant and equipment, including renewals and betterments, are capitalized at cost, while maintenance and repairs are expensed as incurred. The interest expense applicable to the construction of qualifying assets is capitalized as a component of the cost of such assets. We account for the depreciation of property, plant and equipment using the straight‑line method over the estimated useful lives of the assets considering the estimated salvage value of the property, plant and equipment. Both the estimated useful lives and salvage values require the use of management estimates. Assets held-for-sale are reported at the lower of the carrying amount or fair value less estimated costs to sell. Our estimate of fair value represents our best estimate based on industry trends and reference to market transactions and is subject to variability. Certain events, such as unforeseen changes in operations, technology or market conditions, could materially affect our estimates and assumptions related to depreciation or result in abandonments. For the fiscal years presented in this Form 10-K, no significant changes were made to the determinations of useful lives or salvage values. Upon retirement or other disposal of fixed assets, the cost and related accumulated depreciation are removed from the respective accounts and any gains or losses are recorded in the results of operations.
Impairment of Long‑lived Assets, Goodwill and Other Intangible Assets
Management assesses the potential impairment of our long‑lived assets and finite-lived intangibles whenever events or changes in circumstances indicate that the carrying value may not be recoverable. Changes that could prompt such an assessment may include equipment obsolescence, changes in the market demand, periods of relatively low rig utilization, declining revenue per day, declining cash margin per day, completion of specific contracts, change in technology and/or overall changes in general market conditions. If a review of the long‑lived assets and finite-lived intangibles indicates that the carrying value of certain of these assets or asset groups is more than the estimated undiscounted future cash flows, an impairment charge is made, as required, to adjust the carrying value to the estimated fair value. Cash flows are estimated by management considering factors such as prospective market demand, recent changes in rig technology and its effect on each rig’s marketability, any cash investment required to make a rig marketable, suitability of rig size and makeup to existing platforms, and competitive dynamics including utilization. The fair value of drilling rigs is determined based upon either an income approach using estimated discounted future cash flows, a market approach considering factors such as recent market sales of rigs of other companies and our own sales of rigs, appraisals and other factors, a cost approach utilizing reproduction costs new as adjusted for the asset age and condition, and/or a combination of multiple approaches. The use of different assumptions could increase or decrease the estimated fair value of assets and could therefore affect any impairment measurement.
We review goodwill for impairment annually in the fourth fiscal quarter or more frequently if events or changes in circumstances indicate it is more likely than not that the carrying amount of the reporting unit holding such goodwill may exceed its fair value. We initially assess goodwill for impairment based on qualitative factors to determine whether the existence of events or circumstances leads to a determination that it is more likely than not that the fair value of one of our reporting units is greater than its carrying amount.
If further testing is necessary or a quantitative test is elected, we quantitatively compare the fair value of a reporting unit with its carrying amount, including goodwill. If the carrying amount exceeds the fair value, an impairment charge will be recognized in an amount equal to the excess; however, the loss recognized would not exceed the total amount of goodwill allocated to that reporting unit.
Self‑Insurance Accruals
We insure working land rigs and related equipment at values that approximate the current replacement costs on the inception date of the policies. However, we self-insure large deductibles under these policies. We also carry insurance with varying deductibles and coverage limits with respect to stacked rigs, offshore platform rigs, and “named wind storm” risk in the Gulf of Mexico. We self‑insure a number of other risks, including loss of earnings and business interruption.
We self‑insure a significant portion of expected losses relating to workers’ compensation, general liability, employer’s liability and automobile liability. Generally, deductibles range from $1 million to $10 million per occurrence depending on the coverage and whether a claim occurs outside or inside of the United States. Insurance is purchased over deductibles to reduce our exposure to catastrophic events but there can be no assurance that such coverage will apply or be adequate in all circumstances. Estimates are recorded for incurred outstanding liabilities for workers’ compensation and other casualty claims. Retained losses are estimated and accrued based upon our estimates of the aggregate liability for claims incurred. Estimates for liabilities and retained losses are based on adjusters’ estimates, our historical loss experience and statistical methods commonly used within the insurance industry that we believe are reliable.
We also engage a third-party actuary to perform a periodic review of our casualty losses. Nonetheless, insurance estimates include certain assumptions and management judgments regarding the frequency and severity of claims, claim development and settlement practices. Unanticipated changes in these factors may produce materially different amounts of expense that would be reported under these programs. Our wholly‑owned captive insurance companies finance a significant portion of the physical damage risk on company‑owned drilling rigs as well as casualty deductibles. An actuary reviews the loss reserves retained by the Company and the captives on an annual basis.
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Revenue Recognition
Drilling services and solutions revenues are comprised of daywork drilling contracts for which the related revenues and expenses are recognized as services are performed and collection is reasonably assured. For certain contracts, we receive payments contractually designated for the mobilization of rigs and other drilling equipment. Mobilization payments received, and direct costs incurred for the mobilization, are deferred and recognized on a straight-line basis as the drilling service is provided. Costs incurred to relocate rigs and other drilling equipment to areas in which a contract has not been secured are expensed as incurred. Reimbursements received for out‑of‑pocket expenses are recorded as revenue. For contracts that are terminated prior to the specified term, early termination payments received by us are recognized as revenues when all contractual requirements are met.
Income Taxes
    Deferred income taxes are accounted for under the liability method, which takes into account the differences between the basis of the assets and liabilities for financial reporting purposes and amounts recognized for income tax purposes. Our net deferred tax liability balance at year-end reflects the application of our income tax accounting policies and is based on management’s estimates, judgments and assumptions. Included in our net deferred tax liability balance are deferred tax assets that are assessed for realizability. If it is more likely than not that a portion of the deferred tax assets will not be realized in a future period, the deferred tax assets will be reduced by a valuation allowance based on management’s estimates.
    In addition, we operate in several countries throughout the world and our tax returns filed in those jurisdictions are subject to review and examination by tax authorities within those jurisdictions. We recognize uncertain tax positions we believe have a greater than 50 percent likelihood of being sustained. We cannot predict or provide assurance as to the ultimate outcome of any existing or future assessments.
New Accounting Standards
See Note 2—Summary of Significant Accounting Policies, Risks and Uncertainties to our Consolidated Financial Statements for recently adopted accounting standards and new accounting standards not yet adopted.
ITEM 7A. QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK
Our financial position is exposed to a variety of risks, including foreign currency exchange risk, commodity price risk, credit and capital market risk, interest rate risk and equity price risk. We have seen an increase in these risks and related uncertainties with increased volatility in oil and gas prices and the financial markets as a result of the COVID-19 pandemic.
Foreign Currency Exchange Rate Risk
Our drilling contracts in foreign countries generally provide for payment in U.S. dollars. Historically, in Argentina, while the contracts were denominated in the U.S. dollar, we were paid in Argentine pesos. We are currently receiving some customer payments in U.S. dollars, but we will likely receive future payments in Argentine pesos as we have in the past. The Argentine branch of one of our second‑tier subsidiaries remits U.S. dollars to its U.S. parent by converting the Argentine pesos into U.S. dollars through the Argentine Foreign Exchange Market and repatriating the U.S. dollars. In the future, other contracts or applicable law may require payments to be made in foreign currencies. As such, there can be no assurance that we will not experience in Argentina or elsewhere a devaluation of foreign currency, foreign exchange restrictions or other difficulties repatriating U.S. dollars even if we are able to negotiate the contract provisions designed to mitigate such risks. At September 30, 2021, a hypothetical decrease in value of 10 percent would result in a decrease in value of our monetary assets and liabilities denominated in Argentine pesos by approximately $2.5 million.
Argentina’s economy is currently considered highly inflationary, which is defined as cumulative inflation rates exceeding 100 percent in the most recent three‑year period based on inflation data published by the respective governments. Nonetheless, all of our foreign operations use the U.S. dollar as the functional currency and local currency monetary assets and liabilities are remeasured into U.S. dollars with gains and losses resulting from foreign currency transactions included in current results of operations.
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Commodity Price Risk
The demand for drilling services and solutions is derived from exploration and production companies spending money to explore and develop drilling prospects in search of crude oil and natural gas. Their spending is driven by their cash flow and financial strength, which is affected by trends in crude oil and natural gas commodity prices. Crude oil prices are determined by a number of factors including global supply and demand, the establishment of and compliance with production quotas by oil exporting countries, worldwide economic conditions and geopolitical factors. Crude oil and natural gas prices have historically been volatile and very difficult to predict with any degree of certainty. While current energy prices are important contributors to positive cash flow for customers, expectations about future prices and price volatility are generally more important for determining future spending levels. This volatility can lead many exploration and production companies to base their capital spending on much more conservative estimates of commodity prices. As a result, demand for drilling services and solutions is not always purely a function of the movement of commodity prices.
Credit and Capital Market Risk
Customers may finance their exploration activities through cash flow from operations, the incurrence of debt or the issuance of equity. Any deterioration in the credit and capital markets, as experienced in the past, can make it difficult for customers to obtain funding for their capital needs. A reduction of cash flow resulting from declines in commodity prices or a reduction of available financing may result in customer credit defaults or reduced demand for our services, which could have a material adverse effect on our business, financial condition and results of operations. Similarly, we may need to access capital markets to obtain financing. Our ability to access capital markets for financing could be limited by, among other things, oil and gas prices, our existing capital structure, our credit ratings, the state of the economy, the health of the drilling and overall oil and gas industry, and the liquidity of the capital markets. Many of the factors that affect our ability to access capital markets are outside of our control. No assurance can be given that we will be able to access capital markets on terms acceptable to us when required to do so, which could have a material adverse impact on our business, financial condition and results of operations.
Further, we attempt to secure favorable prices through advanced ordering and purchasing for drilling rig components. While these materials have generally been available at acceptable prices, there is no assurance the prices will not vary significantly in the future. Any fluctuations in market conditions causing increased prices in materials and supplies could have a material adverse effect on future operating costs.
Interest Rate Risk
Our interest rate risk exposure results primarily from short‑term rates, mainly LIBOR‑based, on any borrowings from our revolving credit facility. There were no outstanding borrowings under this facility at September 30, 2021, and our outstanding debt consisted of $1.0 billion (face amount) in senior unsecured notes, of which $487.1 million is classified as current. In September 2021, we issued $550.0 million principal amount of senior unsecured notes, which have a fixed rate of 2.90 percent, and delivered a conditional notice, satisfied on September 29, 2021, of optional full redemption for all of the outstanding 4.65 percent senior unsecured notes, which have a carrying value of $487.1 million. The fair value of the 4.65 percent senior unsecured notes was estimated to be $541.6 million and $534.5 million for fiscal years 2021 and 2020, respectively, and the fair value of the 2.90 percent senior unsecured notes was estimated to be $554.3 million at September 30, 2021.
Equity Price Risk
On September 30, 2021, we had equity securities with a total fair value of $13.9 million compared to $7.3 million at September 30, 2020. A hypothetical 10 percent decrease in the market price for our marketable equity securities as of September 30, 2021 would decrease the fair value by $1.4 million. We make no specific plans to sell securities, but rather sell securities based on market conditions and other circumstances. These securities are subject to a wide variety and number of market‑related risks that could substantially reduce or increase the fair value of our holdings.
At November 8, 2021, the total fair value of our equity securities increased to approximately $16.0 million. We continually monitor the fair value of the investments but are unable to predict future market volatility and any potential impact to the Consolidated Financial Statements.
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ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA

INDEX TO CONSOLIDATED FINANCIAL STATEMENTS
HP-20210930_G6.JPG
PAGE
57
58
Consolidated Financial Statements:
Consolidated Balance Sheets at September 30, 2021 and 2020
61
61
63
64
65
66

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Management’s Report on Internal Control over Financial Reporting
Management of Helmerich & Payne, Inc. is responsible for establishing and maintaining adequate internal control over financial reporting as defined in Rule 13a‑15(f) or 15d‑15(f) under the Securities Exchange Act of 1934. Our internal control over financial reporting was designed under the supervision of the Chief Executive Officer and Chief Financial Officer to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with accounting principles generally accepted in the United States of America, and includes those policies and procedures that:
(i)pertain to the maintenance of records that, in reasonable detail, accurately and fairly reflect the transactions and dispositions of our assets;
(ii)provide reasonable assurance that transactions are recorded as necessary to permit preparation of financial statements in accordance with generally accepted accounting principles, and that our receipts and expenditures are being made only in accordance with authorizations of our management and the Board of Directors; and
(iii)provide reasonable assurance regarding prevention or timely detection of unauthorized acquisition, use or disposition of our assets that could have a material effect on the financial statements.
Because of its inherent limitations, internal control over financial reporting may not prevent or detect misstatements. Also, projections of any evaluation of effectiveness to future periods are subject to the risk that controls may become inadequate because of changes in conditions or that the degree of compliance with the policies or procedures may deteriorate.
Management assessed the effectiveness of the Company’s internal control over financial reporting as of September 30, 2021. In making this assessment, management used the criteria established in the Internal Control—Integrated Framework (2013) issued by the Committee of Sponsoring Organizations of the Treadway Commission. Based on our evaluation under the criteria in Internal Control-Integrated Framework (2013), management has concluded that the Company maintained effective internal control over financial reporting as of September 30, 2021.
Ernst & Young LLP, an independent registered public accounting firm, has issued an attestation report on the effectiveness of the Company’s internal control over financial reporting as of September 30, 2021, as stated in their report which appears herein.
Helmerich & Payne, Inc.
by
/s/ John W. Lindsay /s/ Mark W. Smith
John W. Lindsay
Director, President and Chief Executive Officer
Mark W. Smith
Senior Vice President and Chief Financial Officer
November 18, 2021 November 18, 2021

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Report of Independent Registered Public Accounting Firm

The Board of Directors and Shareholders of
Helmerich & Payne, Inc.

Opinion on the Financial Statements
We have audited the accompanying consolidated balance sheets of Helmerich & Payne, Inc. (the Company) as of September 30, 2021 and 2020, the related consolidated statements of operations, comprehensive loss, shareholders' equity and cash flows for each of the three years in the period ended September 30, 2021, and the related notes (collectively referred to as the “consolidated financial statements”).  In our opinion, the consolidated financial statements present fairly, in all material respects, the financial position of the Company at September 30, 2021 and 2020, and the results of its operations and its cash flows for each of the three years in the period ended September 30, 2021, in conformity with U.S. generally accepted accounting principles.
We also have audited, in accordance with the standards of the Public Company Accounting Oversight Board (United States) (PCAOB), the Company’s internal control over financial reporting as of September 30, 2021, based on criteria established in Internal Control-Integrated Framework issued by the Committee of Sponsoring Organizations of the Treadway Commission (2013 framework) and our report dated November 18, 2021 expressed an unqualified opinion thereon.
Basis for Opinion
These financial statements are the responsibility of the Company’s management. Our responsibility is to express an opinion on the Company’s financial statements based on our audits. We are a public accounting firm registered with the PCAOB and are required to be independent with respect to the Company in accordance with the U.S. federal securities laws and the applicable rules and regulations of the Securities and Exchange Commission and the PCAOB.
We conducted our audits in accordance with the standards of the PCAOB. Those standards require that we plan and perform the audit to obtain reasonable assurance about whether the financial statements are free of material misstatement, whether due to error or fraud. Our audits included performing procedures to assess the risks of material misstatement of the financial statements, whether due to error or fraud, and performing procedures that respond to those risks. Such procedures included examining, on a test basis, evidence regarding the amounts and disclosures in the financial statements. Our audits also included evaluating the accounting principles used and significant estimates made by management, as well as evaluating the overall presentation of the financial statements. We believe that our audits provide a reasonable basis for our opinion.
Critical Audit Matters
The critical audit matters communicated below are matters arising from the current period audit of the financial statements that were communicated or required to be communicated to the audit committee and that: (1) relate to accounts or disclosures that are material to the financial statements and (2) involved our especially challenging, subjective or complex judgments. The communication of critical audit matters does not alter in any way our opinion on the consolidated financial statements, taken as a whole, and we are not, by communicating the critical audit matters below, providing separate opinions on the critical audit matters or on the accounts or disclosures to which they relate.

   
Self-Insurance Accruals
Description of the Matter 
The Company's self-insurance liability for workers’ compensation and other casualty claims was $81.0 million at September 30, 2021. As described in Note 2—Summary of Significant Accounting Policies, Risks and Uncertainties to the consolidated financial statements, this liability is based on a third-party actuarial analysis, which includes an estimate for incurred but not reported claims. The actuarial analysis considers a variety of factors, including third-party adjusters’ estimates, historic experience, and statistical methods commonly used within the insurance industry. 

Auditing the Company's reserve for self-insured risks for worker’s compensation and other casualty claims is complex and required us to use our actuarial specialists due to the significant measurement uncertainty associated with the estimate, management’s application of significant judgment, and the use of various actuarial methods.
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How We Addressed the Matter in Our Audit 
  We evaluated the design and tested the operating effectiveness of the Company’s controls over the workers’ compensation and other casualty claims accrual process, including management's review controls over the significant assumptions used in the calculation and the completeness and accuracy of the data underlying the reserve.  

To test the self-insurance liability for worker’s compensation and other casualty claims, we performed audit procedures that included, among others, testing the completeness and accuracy of the underlying claims data provided to management’s actuary and obtaining legal confirmation letters to evaluate the reserves recorded on significant litigated matters. Additionally, we involved our actuarial specialists to assist in our evaluation of the methodologies applied by management’s actuary in establishing the actuarially determined reserve. We compared the Company’s assumptions to ranges of assumptions independently developed by our actuarial specialists.
    Valuation of Assets Held-for-Sale
Description of the Matter 
 
As more fully described in Note 4—Property, Plant and Equipment to the consolidated financial statements, during 2021 the Company committed to a plan to sell 71 non-super spec rigs. This action resulted in classification of the assets as held-for-sale. The Company measured these assets at fair value less cost to sell, resulting in a $56.4 million impairment charge.

Auditing the Company's valuation of the assets-held-for-sale was complex and required subjective judgment and involvement of a valuation specialist in evaluating management’s assumptions used in determining the fair value less costs to sell. Significant assumptions used in the Company’s estimate included management’s use of market quotes.
How We Addressed the Matter in Our Audit 
 
We evaluated the design and tested the operating effectiveness of controls over the Company's process to estimate fair value less costs to sell. For example, we tested management's review controls over the significant assumptions underlying the fair value analysis.

Our testing of the Company’s held-for-sale analysis included, among other procedures, evaluating management’s selection of valuation methodologies, evaluating the significant assumptions used and testing the completeness and accuracy of the underlying data. For example, we compared the market quotes used in the analysis to external documentation. We also performed sensitivity analyses of the assumptions to evaluate the change in the fair value resulting from changes in assumptions. We involved our valuation specialists to assist in our procedures.

/s/ Ernst & Young LLP
We have served as the Company’s auditor since 1994.
Tulsa, Oklahoma
November 18, 2021

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Report of Independent Registered Public Accounting Firm

The Board of Directors and Shareholders of
Helmerich & Payne, Inc.
Opinion on Internal Control over Financial Reporting
We have audited Helmerich & Payne, Inc.’s internal control over financial reporting as of September 30, 2021, based on criteria established in Internal Control—Integrated Framework issued by the Committee of Sponsoring Organizations of the Treadway Commission (2013 framework) (the COSO criteria). In our opinion, Helmerich & Payne, Inc. (the Company) maintained, in all material respects, effective internal control over financial reporting as of September 30, 2021, based on the COSO criteria.
We also have audited, in accordance with the standards of the Public Company Accounting Oversight Board (United States) (PCAOB), the consolidated balance sheets of the Company as of September 30, 2021 and 2020, the related consolidated statements of operations, comprehensive loss, shareholders’ equity and cash flows for each of the three years in the period ended September 30, 2021, and the related notes and our report dated November 18, 2021 expressed an unqualified opinion thereon.
Basis for Opinion
The Company’s management is responsible for maintaining effective internal control over financial reporting, and for its assessment of the effectiveness of internal control over financial reporting included in the accompanying Management’s Report on Internal Control over Financial Reporting. Our responsibility is to express an opinion on the Company’s internal control over financial reporting based on our audit. We are a public accounting firm registered with the PCAOB and are required to be independent with respect to the Company in accordance with the U.S. federal securities laws and the applicable rules and regulations of the Securities and Exchange Commission and the PCAOB.
We conducted our audit in accordance with the standards of the PCAOB. Those standards require that we plan and perform the audit to obtain reasonable assurance about whether effective internal control over financial reporting was maintained in all material respects.
Our audit included obtaining an understanding of internal control over financial reporting, assessing the risk that a material weakness exists, testing and evaluating the design and operating effectiveness of internal control based on the assessed risk, and performing such other procedures as we considered necessary in the circumstances. We believe that our audit provides a reasonable basis for our opinion.
Definition and Limitations of Internal Control Over Financial Reporting
A company’s internal control over financial reporting is a process designed to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles. A company’s internal control over financial reporting includes those policies and procedures that (1) pertain to the maintenance of records that, in reasonable detail, accurately and fairly reflect the transactions and dispositions of the assets of the company; (2) provide reasonable assurance that transactions are recorded as necessary to permit preparation of financial statements in accordance with generally accepted accounting principles, and that receipts and expenditures of the company are being made only in accordance with authorizations of management and directors of the company; and (3) provide reasonable assurance regarding prevention or timely detection of unauthorized acquisition, use or disposition of the company’s assets that could have a material effect on the financial statements.
Because of its inherent limitations, internal control over financial reporting may not prevent or detect misstatements. Also, projections of any evaluation of effectiveness to future periods are subject to the risk that controls may become inadequate because of changes in conditions, or that the degree of compliance with the policies or procedures may deteriorate.
/s/ Ernst & Young LLP
Tulsa, Oklahoma
November 18, 2021

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HELMERICH & PAYNE, INC.
CONSOLIDATED BALANCE SHEETS
September 30,
(in thousands except share data and per share amounts) 2021 2020
ASSETS
Current Assets:
Cash and cash equivalents $ 917,534  $ 487,884 
Short-term investments 198,700  89,335 
Accounts receivable, net of allowance of $2,068 and $1,820, respectively
228,894  192,623 
Inventories of materials and supplies, net 84,057  104,180 
Prepaid expenses and other, net 85,928  89,305 
Assets held-for-sale 71,453  — 
Total current assets 1,586,566  963,327 
Investments 135,444  31,585 
Property, plant and equipment, net 3,127,287  3,646,341 
Other Noncurrent Assets:
Goodwill 45,653  45,653 
Intangible assets, net 73,838  81,027 
Operating lease right-of-use asset 49,187  44,583 
Other assets, net 16,153  17,105 
Total other noncurrent assets 184,831  188,368 
Total assets $ 5,034,128  $ 4,829,621 
LIABILITIES & SHAREHOLDERS' EQUITY
Current Liabilities:
Accounts payable $ 71,996  $ 36,468 
Dividends payable 27,332  27,226 
Current portion of long-term debt 483,486  — 
Accrued liabilities 283,492  155,442 
Total current liabilities 866,306  219,136 
Noncurrent Liabilities:
Long-term debt, net 541,997  480,727 
Deferred income taxes 563,437  650,675 
Other 147,757  147,180 
Noncurrent liabilities - discontinued operations 2,013  13,389 
Total noncurrent liabilities 1,255,204  1,291,971 
Commitments and Contingencies (Note 16)
Shareholders' Equity:
Common stock, $0.10 par value, 160,000,000 shares authorized, 112,222,865 and 112,151,563 shares issued as of September 30, 2021 and 2020, respectively, and 107,898,859 and 107,488,242 shares outstanding as of September 30, 2021 and 2020, respectively
11,222  11,215 
Preferred stock, no par value, 1,000,000 shares authorized, no shares issued
—  — 
Additional paid-in capital 529,903  521,628 
Retained earnings 2,573,375  3,010,012 
Accumulated other comprehensive loss (20,244) (26,188)
Treasury stock, at cost, 4,324,006 shares and 4,663,321 shares as of September 30, 2021 and 2020, respectively
(181,638) (198,153)
Total shareholders’ equity 2,912,618  3,318,514 
Total liabilities and shareholders' equity $ 5,034,128  $ 4,829,621 
The accompanying notes are an integral part of these consolidated financial statements.

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HELMERICH & PAYNE, INC.
CONSOLIDATED STATEMENTS OF OPERATIONS
Year Ended September 30,
(in thousands, except per share amounts) 2021 2020 2019
OPERATING REVENUES
Drilling services $ 1,210,800  $ 1,761,714  $ 2,785,557 
Other 7,768  12,213  12,933 
1,218,568  1,773,927  2,798,490 
OPERATING COSTS AND EXPENSES
Drilling services operating expenses, excluding depreciation and amortization 952,600  1,184,788  1,803,204 
Other operating expenses 5,138  5,777  5,382 
Depreciation and amortization 419,726  481,885  562,803 
Research and development 21,724  21,645  27,467 
Selling, general and administrative 172,195  167,513  194,416 
Asset impairment charge 70,850  563,234  224,327 
Restructuring charges 5,926  16,047  — 
Gain on sale of assets (1,042) (46,775) (39,691)
1,647,117  2,394,114  2,777,908 
OPERATING INCOME (LOSS) FROM CONTINUING OPERATIONS (428,549) (620,187) 20,582 
Other income (expense)
Interest and dividend income 10,254  7,304