EDGAR 10-K Filing

Company CIK: 46765
Filing Year: 2022
Filename: 46765_10-K_2022_0000046765-22-000070.json

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ITEM 1. BUSINESS
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 and technologies that are intended to make hydrocarbon recovery safer and more economical for oil and gas exploration and production companies. We are an important partner 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 drilling services operations are organized into the following reportable operating business segments: North America Solutions, Offshore Gulf of Mexico and International Solutions. Our North America Solutions operations are primarily located in Texas, but traditionally also operate in other states, depending on demand. Such states include: Colorado, Louisiana, New Mexico, North Dakota, Ohio, Oklahoma, Pennsylvania, Utah, West Virginia and Wyoming. Additionally, Offshore Gulf of Mexico operations are conducted in Louisiana and in U.S. federal waters in the Gulf of Mexico and our International Solutions operations have rigs and/or services primarily located in four international locations: Argentina, Bahrain, Colombia and United Arab Emirates.
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 366,000 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 primarily used to insure the deductibles for our workers’ compensation, general liability, automobile liability, rig property and a medical stop-loss program. 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."
2022 FORM 10-K | 6
Drilling Fleet
The following map shows the number of available rigs by basin in our North America Solutions reportable segment as of September 30, 2022:
The following table sets forth certain information concerning our North America Solutions drilling rigs as of September 30, 2022:
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 132 96 3 - 135 96
NM 40 34 - - 40 34
OK 21 13 1 - 22 13
LA 11 9 - - 11 9
ND 11 10 - - 11 10
PA 5 4 - - 5 4
CO 1 1 2 2 3 3
WV 3 3 - - 3 3
UT 3 3 - - 3 3
OH 2 - - - 2 -
WY 1 1 - - 1 1
Totals 230 174 6 2 236 176
(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.
2022 FORM 10-K | 7
The following table sets forth certain information concerning our Offshore Gulf of Mexico drilling rigs as of September 30, 2022:
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, 2022:
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 8 4 - - - 4 - 20 8
Colombia 2 - - - 1 1 2 2 5 3
Bahrain - - 3 1 - - - - 3 1
Totals 14 8 7 1 1 1 6 2 28 12
(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.
(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 2022, 2021, or 2020.
2022 FORM 10-K | 8
The following table presents operating statistics for the fiscal years 2022, 2021, and 2020:
Year Ended September 30,
North America Solutions Offshore Gulf of Mexico International Solutions
Revenue days1
59,672 39,199 49,003 1,460 1,552 1,922 3,036 1,815 4,605
Average active rigs2
163 107 134 4 4 5 8 5 13
Number of active rigs at the end of period3
176 127 69 4 4 5 12 6 5
Number of available rigs at the end of period 236 236 262 7 7 8 28 30 32
(1)Defined as the number of contractual days we recognized revenue during the period.
(2)Active rigs generate revenue for the Company; accordingly 'average active rigs' represents the average number of rigs generating revenue during the applicable period. This metric is calculated by dividing revenue days by total days in the applicable period (i.e. 365 days). This 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.
(3)Defined as the number of rigs generating revenue at the applicable end date of the time period.
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 capable of drilling horizontal or directional wells. As of September 30, 2022, we had approximately 22 percent of the total market share in U.S. land drilling and approximately 34 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 174 were under contract at September 30, 2022. In total, 176 of our 236 marketed rigs were active under contract, 119 were under fixed-term contracts, and 57 were working well-to-well as of September 30, 2022.
Our drilling technology within this segment enables a solutions-based approach that provides performance-driven drilling services designed to help deliver greater levels of drilling efficiency, 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 based upon their goals and desired outcomes which will often vary from well to well, basin to basin.
Our North America Solutions segment contributed approximately 86.8 percent ($1.8 billion) of our consolidated operating revenues during fiscal year 2022, compared to approximately 84.2 percent ($1.0 billion) and 83.1 percent ($1.5 billion) of our consolidated operating revenues during fiscal years 2021 and 2020, 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 7.9 percent ($141.0 million) of the North America Solutions segment revenues during fiscal year 2022.
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, 2022, four of the seven offshore rigs were under contract. Our Offshore Gulf of Mexico operations contributed approximately 6.1 percent ($125.5 million) of our consolidated operating revenues during fiscal year 2022, compared to approximately 10.4 percent ($126.4 million) and 8.1 percent ($143.1 million) of our consolidated operating revenues during fiscal years 2021 and 2020, respectively. Revenues from drilling services performed for our largest offshore drilling customer totaled approximately 76.6 percent ($96.1 million) of offshore revenues during fiscal year 2022.
2022 FORM 10-K | 9
International Solutions Segment
Our International Solutions segment primarily conducts operations in Argentina, Colombia, Bahrain and U.A.E. As of September 30, 2022, we had twelve land rigs contracted for work in locations outside of the United States. Our International Solutions operations contributed approximately 6.6 percent ($136.1 million) of our consolidated operating revenues during fiscal year 2022, compared to approximately 4.8 percent ($57.9 million) and 8.1 percent ($144.2 million) of our consolidated operating revenues during fiscal years 2021 and 2020, respectively.
Argentina As of September 30, 2022, we had 20 available rigs in Argentina. Revenues generated by Argentine drilling operations contributed approximately 4.4 percent ($91.4 million) of our consolidated operating revenues during fiscal year 2022 compared to approximately 2.3 percent ($27.9 million) and 4.8 percent ($84.4 million) of our consolidated operating revenues during fiscal years 2021 and 2020, respectively. Revenues from drilling services performed for our two largest customers in Argentina totaled approximately 3.5 percent of our consolidated operating revenues and approximately 53.3 percent of our international operating revenues during fiscal year 2022. The Argentine drilling contracts are primarily with large international or national oil companies.
Colombia As of September 30, 2022, we had five available rigs in Colombia. Revenues generated by Colombian drilling operations contributed approximately 1.1 percent ($22.0 million) of our consolidated operating revenues in fiscal year 2022, compared to approximately 0.1 percent ($1.7 million) and 0.4 percent ($6.4 million) of our consolidated operating revenues during fiscal years 2021 and 2020, respectively. Revenues from drilling services performed for our two largest customers in Colombia totaled approximately 1.1 percent of our consolidated operating revenues and approximately 16.2 percent of our international operating revenues during fiscal year 2022. The Colombian drilling contracts are primarily with large international or national oil companies.
Bahrain As of September 30, 2022, we had three available rigs in Bahrain. Revenues generated by Bahrain drilling operations contributed approximately 0.8 percent ($17.0 million) of our consolidated operating revenues in fiscal year 2022, compared to approximately 2.3 percent ($27.4 million) and 1.6 percent ($28.7 million) of our consolidated operating revenues during fiscal years 2021 and 2020, respectively. All of our revenues in Bahrain are from a partner of the local national oil company.
United Arab Emirates During the year ended September 30, 2022, our operations in U.A.E. consisted of services provided to ADNOC Drilling Company P.J.S.C. ("ADNOC Drilling"), primarily in the form of secondment labor, as part of the strategic alliance that was announced in September 2021. H&P's alliance with ADNOC Drilling includes several accretive projects, in addition to general consulting services, that leverage H&P's expertise and technologies to help deliver more competitive well completion times, greater drilling efficiencies, and improved well economics. Currently, H&P does not own any drilling rigs within U.A.E.
Other Operations
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. The Company self-insures employee health plan exposures in excess of employee deductibles. 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. This program is reviewed at the end of each policy year by an outside actuary.
The Company's incubator program includes the activity related to new research and development projects.
Our real estate operations, our incubator program for new research and development projects, and our wholly-owned captive insurance companies are included in "Other" within our segment disclosures.
2022 FORM 10-K | 10
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.
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 generated 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 a result of these investments, today the vast majority of our current domestic fleet is comprised of super spec rigs. As of September 30, 2022, we had a total of 234 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 59 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.
2022 FORM 10-K | 11
We continue 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 data driven solution compared to human decisions and execution, thereby reducing variability and the costs around achieving optimal outcomes. These solutions are designed to continue to help 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.
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. During the first quarter of fiscal year 2022, 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 assets was completed on November 3, 2021 while the sale of our casing running services assets was completed on November 15, 2021, for total consideration less costs to sell of $6.0 million, in addition to the possibility of future earnout proceeds, resulting in a loss of $3.4 million. During the year ended September 30, 2022 we recognized $1.1 million in earnout proceeds associated with the sale of our trucking services assets within Other (Gain) Loss on Sale of Assets on the Consolidated Statements of Operations.
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 has traditionally been 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, 2022, we had 192 active rigs under contract, compared to 137 and 79 rigs under contract as of September 30, 2021 and 2020, 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., Precision Drilling Corporation, 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. 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.
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.
Each drilling rig operates under a separate drilling contract and, in some instances, these contracts are part of an over-arching term agreement known as a FlexPool. These agreements are with a limited number of customers that operate multiple rigs, often times across multiple basins in the U.S. Under the FlexPool agreements, customers enter into a fixed term contract covering a minimum amount of drilling days, utilizing a minimum number of drilling rigs and have the flexibility to employ more or fewer rigs as long as the minimum number of rigs (outlined in the agreement) is maintained. If any provisions are violated, as in a customer operating below the minimum number of rigs, early termination payments may apply.
2022 FORM 10-K | 12
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 2022, a majority of our drilling services were performed on a “daywork” contract basis.
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 2022 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, 2022 and 2021, our drilling contract backlog was $1.2 billion and $0.6 billion, respectively. Approximately 30.8 percent of the September 30, 2022 backlog is reasonably expected to be fulfilled in fiscal year 2024 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, 2022, we had approximately 7,000 employees within the United States and approximately 1,000 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 enable 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 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.
2022 FORM 10-K | 13
Education and Training
We are committed to the continual training and development of our employees, especially of those in field operations, to help ensure we can develop future managers and leaders from within our organization. Our training starts 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. The three training programs include:
•Introduction to Diversity, Equity, and Inclusion and Traits of Inclusive Teams;
•Unconscious Bias and Microaggressions; and
•Allyship and Privilege.
These three courses take employees through an exploratory and educational journey to discover how unique perspectives and curiosity can create an environment to understand, welcome, respect, and value one another.
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 Training - 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 Training - teaches employees to solve complex problems using structured processes, tools and data to drive results while emphasizing leadership and public speaking.
•Leadership Series Training - 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.
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 and declining total recordable injury rates ("TRIR"). 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 rewarded 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.
2022 FORM 10-K | 14
SIF Strategy
We are committed to controlling and removing SIF exposures at any H&P rig or facility. We continue to track traditional safety metrics, such as TRIR, to be responsive to customer requests and industry benchmarking, but do not use these metrics as the foundation for our safety culture. H&P data shows that only a small portion of OSHA recordable incidents provide value in preventing potential serious injuries. Incidents that do not result in an injury, but have the potential for a serious injury or fatality provide many more learning opportunities for preventing future serious injuries or fatalities. Based on this data we have a proportionate response approach to incident investigations and corrective actions. Priority is given to those incidents that have the potential to cause a serious injury or fatality. Our safety success at H&P will be based on key performance indicators related to the removal of SIF exposures, such as SIF Potential and SIF Mitigated rates. 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, well control events 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;
• currency conversion and repatriation;
•global anti-corruption laws; and
•government sanctions and embargo listing.
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 Health and Safety Act (“OSHSA”) and other similar laws and regulations govern the protection of the health and safety of employees. The OHSA 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.
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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.”
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 may require payment of statutorily calculated amounts to employees upon termination of employment.
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 fiscal year 2023. We believe we are materially compliant 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. The Company continues to evolve and refine its comprehensive sustainability strategy rooted in our core value to "do the right thing," as discussed above. Our sustainability strategy uses data to better understand our impacts in areas like emissions, diversity, and safety. Additional information on our sustainability strategy and programs can be obtained by reviewing our Sustainability Reports and related information, located on our website.
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, including our Sustainability Reports and related information, 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 a website (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
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
Our business depends on the level of activity in the oil and natural gas industry, which is significantly impacted by the current and expected price of oil and natural gas as well as the volatility in those 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. Oil prices are particularly sensitive to actual and perceived threats to geopolitical stability and to changes in production from OPEC+ member states. For example, the ongoing conflict, and the continuation of, or any increase in the severity of, the conflict between Russia and Ukraine, has led and may continue to lead to an increase in the volatility of global oil and gas prices, which could have a corresponding negative impact on the capital expenditure of oil and gas companies as a result of the higher perceived risk.
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;
•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, hostilities or perceived hostilities 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;
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•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.
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 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 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. From time to time we are able to increase our prices, but we may not be able to do so at a rate that is sufficient to offset rising costs. The inability to maintain our pricing and to increase our pricing as costs increase to offset rising costs and capital expenditures could adversely affect our rig utilization and profit margins.
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, 2022, 79 of our available rigs were not under contract.
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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.
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.
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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 in frequency and severity as a result of 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 result in increased operating costs or decreases in revenues and adversely affect our business, financial condition and results of operations.
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, well control events 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, denial-of-service attacks, malicious software, attempts to gain unauthorized access to our data and the unauthorized release, corruption or loss of our data and personal information, employee or insider error, 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 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. Furthermore, geopolitical tensions or conflicts, such as Russia's invasion of Ukraine, may further heighten the risk of cybersecurity attacks.
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Cybersecurity incidents involving our own systems or those of our third-party vendors, 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, regulatory action, and potential liability, and
•result in injury to our reputation, downtime, loss of revenue, and increased costs to prevent, respond to or mitigate cybersecurity events.
It is possible that our business, financial and other systems, as well as those of our third-party vendors, 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 on 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, including those related to financial reporting, disclosure and cyber and information security;
•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. The amount allocated to goodwill is the excess of the purchase price over the net identifiable assets acquired. At September 30, 2022, we had goodwill of $45.7 million and other intangible assets, net of $67.2 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.
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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.
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 (occurrences of which may increase in frequency and severity as a result of climate change), 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 have resulted and may in the future result in higher labor costs. We may also face a loss of workers and labor shortages as a result of 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, 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 2022, we received approximately 45.5 percent of our consolidated operating revenues from our ten largest drilling services and solutions customers and approximately 19.0 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 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, 2022, our drilling services backlog was approximately $1.2 billion 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.
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, delays in delivery and shortages of drilling equipment and supplies can occur and it may take longer for our vendors to service drilling components. Additionally, suppliers may seek to increase prices for equipment, supplies, and services, 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. Further, certain key rig components, parts and equipment are also either purchased from, fabricated or serviced by a limited number of vendors, which, in some cases, may be thinly capitalized and disproportionately affected by any loss of business, downturn in the energy industry, supply chain disruptions, or reduction or availability of credit. A number of disruptions and delays across the global supply chain have occurred in recent years, which have created delays in servicing key components, and a tightening of supplies and shortages in a number of areas, ranging from basic raw materials to semiconductors, and increasing costs, and we expect such disruptions and delays could continue in the near term and possibly beyond. To date, as an industry leader, we have effectively managed these delays, disruptions, and shortages by engaging in near and long-term demand planning with multiple vendors who provide and service key rig components, parts and equipment. However, if we are not able to effectively manage these disruptions and delays in the future, they could have a material adverse effect on our business, financial condition and results of operations.
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.
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The impact and effects of public health crises, pandemics and epidemics, such as the COVID-19 pandemic, could have a material adverse effect on our business, financial condition and results of operations.
Public health crises, pandemics and epidemics, such as the COVID-19 pandemic, and fear of such events have adversely impacted and may 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. Other effects of the pandemic include and may continue to include, significant volatility and disruption of the global financial markets; continued volatility of crude oil prices and related uncertainties around OPEC+ production; disruption of our operations, including suspension of drilling activities; impact to 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 employee impacts from illness, travel restrictions, including border closures and other community response measures. Such public health crises, pandemics and epidemics are continuously evolving and the extent to which our business operations and financial results continue to be affected depends on various factors beyond our control, such as the duration, severity and sustained geographic resurgence of the COVID-19 virus; the emergence, severity and spread of new variants of the virus; the impact and effectiveness of governmental actions to contain and treat such outbreaks, including government policies and restrictions; vaccine hesitancy, vaccine mandates, and voluntary or mandatory quarantines; and the global response surrounding such uncertainties.
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 2022. 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 2022, we recognized aggregate foreign currency losses of $5.4 million in Argentina. Our aggregate foreign currency losses across all of our operations for fiscal years 2022 and 2021 were $5.9 million and $5.3 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.
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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.
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 2022 and 2021, we recognized impairment charges of $4.4 million and $70.9 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. 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. 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 are subject to general credit, liquidity, market and interest rate risks, which may be exacerbated by unusual events, such as global health crises 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.
The replacement of LIBOR with an alternative reference rate, may adversely affect interest expense related to outstanding debt.
In 2017, the United Kingdom's Financial Conduct Authority (the "FCA"), which regulates the London Interbank Offered Rate ("LIBOR"), announced that it intends to phase out LIBOR as a benchmark. The FCA ceased publication of U.S. dollar LIBOR on December 31, 2021 in the case of one week and two month U.S. dollar LIBOR tenors and intends to phase out LIBOR for all other U.S. dollar tenors immediately after June 30, 2023. The U.S. Federal Reserve (the "Federal Reserve") advised banks to cease entering into new contracts that use U.S. dollar LIBOR as a reference rate. The Alternative Reference Rate Committee ("ARRC"), a committee convened by the Federal Reserve recommended the use of the Secured Overnight Financing Rate ("SOFR"), a new index, calculated by short-term repurchase agreements, backed by U.S. Treasury securities, as its preferred alternative rate for LIBOR in the U.S. On March 8, 2022, we entered into the second amendment to the 2018 Credit Facility, which, among other things, replaced provisions in respect of interest rate determinations that were based on LIBOR with provisions based on SOFR.
Given the inherent differences between LIBOR and SOFR, or any other alternative benchmark rate that may be established, there are many uncertainties regarding a transition from LIBOR. Using SOFR could make borrowing more expensive because it lacks a credit component, which could cause lenders to increase spreads to price for this uncertainty. Additionally, in a crisis, borrowers may hold excess liquidity if SOFR does not spike to reflect conditions, which may create issues for bank liquidity, adversely impacting borrowers. The market transition away from LIBOR to an alternative reference rate is complex and overall financial markets may be disrupted as a result of the phase-out. The availability and cost of our borrowings and interest expense related to outstanding floating-rate debt due to the adoption of SOFR or other alternative benchmark rates or a broader market disruption caused by the phase-out of LIBOR 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.
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, the United States is currently a member of 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.
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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 Intergovernmental Panel on Climate Change (the “IPCC”) prepared 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. In addition, increasing attention to the risks of climate change has resulted in an increased possibility of litigation or investigations brought by public and private entities against oil and gas companies in connection with their GHG emissions. As a result, we or our customers may become subject to court orders compelling a reduction of GHG emissions or requiring mitigation of the effects of climate change. 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. If we are unable to recover or pass through a significant level of our costs or are required to change our practices 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.
The federal government and certain state governments have enacted, and are expected to continue to enact, laws and regulations that mandate or provide economic incentives for the development of technologies and sources of energy other than oil and gas, such as wind and solar. Such legislation incentivizes the development, use and investment in these technologies and alternative energy sources and could accelerate the shift away from traditional oil and gas. For example, the Inflation Reduction Act ("IRA") of 2022 contains tax inducements and other provisions that incentivize investment, development, and deployment of alternative energy sources and technologies. Also, in 2022, California mandated that all new passenger cars and light trucks sold in the state be electric vehicles or other emissions-free models by 2035. If these future laws and regulations result in customers reducing their production of oil and gas, they could ultimately have an adverse effect on our business and prospects.
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, which could result in more frequent and severe disruptions to our business and those of our customers, increased costs to repair damaged facilities or maintain or resume operations, and increased insurance costs. 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, 2022, we had approximately 35 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.
Our aspirations, goals and initiatives related to sustainability and emissions reduction, and our public statements and disclosures regarding them, expose us to numerous risks.
We have developed, and will continue to develop and set, goals, targets, or other objectives related to sustainability matters. Statements related to these goals, targets and objectives reflect our current plans and do not constitute a guarantee that they will be achieved. Our efforts to research, establish, accomplish, and accurately report on these goals, targets, and objectives expose us to numerous operational, reputational, financial, legal, and other risks. Our ability to achieve any stated goal, target, or objective, including with respect to emissions reduction, is subject to numerous factors and conditions, some of which are outside of our control. Examples of such factors include: (1) the extent our customers' decisions directly impact, relate to, or influence the use of our equipment that creates the emissions we report, (2) the availability and cost of low- or non-carbon-based energy sources and technologies, (3) evolving regulatory requirements affecting sustainability standards or disclosures, (4) the availability of suppliers that can meet our sustainability and other standards. In addition, standards for tracking and reporting on sustainability matters, including climate-related matters, have not been harmonized and continue to evolve. Our processes and controls for reporting sustainability matters may not always comply with evolving and disparate standards for identifying, measuring, and reporting such metrics, including sustainability-related disclosures that may be required of public companies by the SEC, and such standards may change over time, which could result in significant revisions to our current goals, reported progress in achieving such goals, or ability to achieve such goals in the future. Our business may also face increased scrutiny from investors and other stakeholders related to our sustainability activities, including the goals, targets, and objectives that we announce, and our methodologies and timelines for pursuing them. If our sustainability practices do not meet investor or other stakeholder expectations and standards, which continue to evolve, our reputation, our ability to attract or retain employees, and our attractiveness as an investment or business partner could be negatively affected. Similarly, our failure or perceived failure to pursue or fulfill our sustainability-focused goals, targets, and objectives, to comply with ethical, environmental, or other standards, regulations, or expectations, or to satisfy various reporting standards with respect to these matters, within the timelines we announce, or at all, could adversely affect our business or reputation, as well as expose us to government enforcement actions and private litigation.
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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”) and California Privacy Rights Act ("CPRA"), which will amend the CCPA in January 2023 to provide for additional privacy protections, as well as similar laws enacted by other states, could result in significant penalties.
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 four percent 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, and, effective January 2023, will be amended by the CPRA, 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 and CPRA 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. Similar legislation has been adopted in Virginia, Colorado, Utah and Connecticut, all of which will go into effect in 2023.
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.
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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.
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.
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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, 2022, we have not experienced an ownership change and, therefore, utilization of our applicable tax attributes were 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 certain pre-change tax attributes 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. For example, the IRA, passed on August 16, 2022, includes a new 15 percent corporate minimum tax as well as a one percent excise tax on corporate stock repurchases applicable to repurchases after December 31, 2022. We are in the process of evaluating the potential impacts of the IRA. While we do not currently expect the IRA to have a material impact on our effective tax rate, our analysis is ongoing and incomplete, and it is possible that the IRA could have a material adverse effect on our tax liability.
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.
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.
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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 base dividend declared was $0.25 per share. Subsequent to September 30, 2022, we also declared a supplemental dividend of $0.235 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 recent 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.
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.
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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.
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. See above "-Our aspirations, goals and initiatives related to sustainability and emissions reduction, and our public statements and disclosures regarding them, expose us to numerous risks." These pressures have intensified recently in connection with the COVID-19 pandemic, significant societal events and government 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.

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ITEM 1B. UNRESOLVED STAFF COMMENTS
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 2022 and that remain unresolved.

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ITEM 2. PROPERTIES
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 lease 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.
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ITEM 3. LEGAL PROCEEDINGS
ITEM 3. LEGAL PROCEEDINGS
See Note 16-Commitments and Contingencies to our Consolidated Financial Statements for information regarding our legal proceedings.

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ITEM 4. MINE SAFETY DISCLOSURE
ITEM 4. MINE SAFETY DISCLOSURES
Not applicable.
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PART II

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ITEM 5. MARKET FOR REGISTRANT'S COMMON EQUITY
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 9, 2022, there were 369 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 and is subject to Board approval.
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, Dow Jones U.S. Select Oil Equipment & Services Index, and Philadelphia Stock Exchange Oil Service Sector 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 2017 Sep 2018 Sep 2019 Sep 2020 Sep 2021 Sep 2022
Helmerich & Payne, Inc. $ 100.00 $ 137.00 $ 88.00 $ 43.00 $ 70.00 $ 90.00
S&P 600 Index 100.00 120.00 108.00 100.00 157.00 127.00
Dow Jones U.S. Select Oil Equipment & Services Index 100.00 102.00 52.00 22.00 42.00 45.00
Philadelphia Stock Exchange Oil Service Sector Index 100.00 107.00 48.00 21.00 43.00 46.00
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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.

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ITEM 6. SELECTED FINANCIAL DATA
ITEM 6. (RESERVED)
Reserved.

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ITEM 7. MANAGEMENT'S DISCUSSION AND ANALYSIS
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.
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, 2022, our drilling rig fleet included a total of 271 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 28 rigs as of September 30, 2022. At the close of fiscal year 2022, we had 192 active contracted rigs, of which 125 were under a fixed-term contract and 67 were working well-to-well, compared to 137 contracted rigs at September 30, 2021. 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 to take advantage of future opportunities.
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Market Outlook
Our revenues are primarily 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.
Our drilling services operations are organized into the following reportable operating segments: North America Solutions, Offshore Gulf of Mexico, and International Solutions. 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 technical requirements of drilling longer lateral unconventional shale wells often necessitate the use of rigs that 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.
There is a strong customer preference for super-spec rigs not only due to the higher rig specifications that enable more technical drilling, but also 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. We are the largest provider of super-spec rigs in the industry and, accordingly, we believe we are well positioned to respond to various market conditions.
Historically there has been a strong correlation between crude oil and natural gas prices and the demand for drilling rigs with the rig count increasing and decreasing with the up and down movements in the commodity prices. However, beginning in 2021, rig activity has not moved in tandem with crude oil prices to the same extent it had historically as a large portion of our customers instituted a more disciplined approach to their operations and capital spending in order to enhance their own financial returns. Those customers established capital budgets based upon commodity price assumptions for the upcoming year and adhered to them, not adjusting activity plans as commodity prices moved.
The capital budgets for calendar year 2023 have not yet been established by many of our customers; however, based upon the crude oil and natural gas pricing environment and many of our customers' desire to at least maintain their current production levels, we expect the level of capital spending and activity in calendar year 2023 to be similar to modestly higher than that experienced in calendar year 2022. In recent years the U.S. demand for super-spec rigs has strengthened. Despite this increased demand for super-spec rigs there is still idle super-spec rig capacity in the market; however, much of that idle capacity represents rigs that have not been active during the preceding two years and in some cases even longer. Consequently, there have been additional costs incurred to bring those long-idled rigs back into working condition, which contributed to upward pricing for super-spec rigs. This supply-demand dynamic combined with the value proposition we provide our customers through our drilling expertise, high-quality FlexRig® fleet, and automation technology resulted in an improvement in our underlying contract economics.
Our North America Solutions active rig count has more than tripled from COVID pandemic lows of 47 rigs in August 2020 to 176 rigs at September 30, 2022. Given the current market dynamics, our disciplined approach to deploying capital, and our fiscal year 2023 capital budget of $425 to $475 million, we project that our active rig count could reach 192 rigs during the first half of calendar 2023. While H&P stands ready to respond to the future demand for its super-spec rigs, we will do so by applying the same disciplined approach, focusing on financial returns. That said, the market for our rigs and others like them in the industry will likely remain tight as supply-chain challenges and labor constraints experienced across the energy industry may inhibit the industry’s ability overall to supply a significant quantity of super-specs rigs. As the largest provider of super-spec rigs in the U.S., H&P is not immune from supply-chain challenges or potential labor constraints, or inflationary pressures that can arise as a result of these matters. However, we believe we are well positioned to address these challenges and do not believe they are a limiting factor relative to our activity plans for fiscal 2023 nor believe they will have a significant adverse impact on our financial results. As a result of increased customer demand and limited supply additions given high required rig reactivation expenditures and supply chain constraints, we expect the momentum of the upward pressure on pricing to continue into fiscal 2023.
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 activity change in our Offshore Gulf of Mexico segment, we do expect margin improvements based on recent rate increases. Regarding our International Solutions segment, we see opportunities for improvement in activity and the related corresponding margin improvement, but those will likely occur on a more extended timeline compared to what we have experienced in the North America Solutions segment.
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Recent Developments
Investment in Tamboran
In October 2022, we purchased a $14.1 million equity investment, representing approximately 106 million shares, in Tamboran Resources Limited ("Tamboran"). Tamboran's shares are listed and publicly traded on the Australian Securities Exchange. Additionally, during September 2022, we entered into a fixed-term drilling services agreement with Tamboran. The expected $30.3 million of revenue to be earned over the term of the contract is included within our contract backlog as of September 30, 2022, as mobilization is expected to commence in fiscal year 2023.
Investments in Geothermal Energy
During the fiscal year ended September 30, 2022, we purchased an additional $18.2 million in geothermal energy investments consisting of both debt and equity securities. Investments were made in five separate companies that are pursuing technological concepts to make unconventional geothermal energy a viable economic renewable energy source. These companies are developing enhanced geothermal system ("EGS") and closed loop concepts. The EGS concepts use one or more of the following: horizontal drilling, induced permeability, and fiber optic sensing. The closed loop concepts use multilateral wellbores, proprietary working fluid, or coaxial pipe configurations. All of these concepts are designed to harvest geothermal heat to create carbon-free, 24/7 geothermal energy. The aggregate balance of our investments in geothermal energy companies was $23.7 million and $2.7 million at September 30, 2022 and 2021, respectively. At this time, we expect the quantity and pace of our geothermal investments to be reduced relative to fiscal year 2022.
Investment in ADNOC Drilling
During September 2021, the Company made a $100.0 million cornerstone investment in ADNOC Drilling in advance of its announced IPO, representing 159.7 million shares of ADNOC Drilling, equivalent to a one percent ownership stake and subject to a three-year lockup period. ADNOC Drilling’s IPO was completed on October 3, 2021, and its shares are listed and traded on the Abu Dhabi Securities Exchange. Our investment is classified as a long-term equity investment within Investments in our Consolidated Balance Sheets. During the fiscal year ended September 30, 2022, we recognized a gain of $47.4 million on our Consolidated Statements of Operations, as a result of the change in fair value of the investment during the period. As of September 30, 2022, this investment is classified as a Level 1 investment based on the quoted stock price on the Abu Dhabi Securities Exchange. During the fiscal year ended September 30, 2022, we also received dividends in the amount of $6.6 million as a result of this investment.
Investment in Galileo Technologies
During the fiscal year ended September 30, 2022, the Company made a $33.0 million cornerstone investment in Galileo Holdco 2 Limited Technologies ("Galileo Holdco 2"), part of the group of companies known as Galileo Technologies (“Galileo”) in the form of a convertible note. Galileo specializes in liquification, natural gas compression and re-gasification modular systems and technologies to make the production, transportation, and consumption of natural gas, biomethane, and hydrogen more economically viable. The convertible note bears interest at 5% per annum with a maturity date of the earlier of April 2027 or an exit event (as defined in the agreement as either an initial public offering or a sale of Galileo). If the conversion option is exercised, the note would convert into common shares of the parent of Galileo Holdco 2 ("Galileo Parent"). We do not intend to sell this investment prior to its maturity date or an exit event. Two of our Directors are independent directors of Galileo Parent. Neither Director has a direct or indirect material interest in the transaction.
Pension Plan Lump-sum Distribution
During March 2022, the Company's domestic noncontributory defined benefit pension plan was amended to include a limited lump sum distribution option and a special eligibility window to be available to certain participants. During the period beginning on May 2, 2022 and ending on June 30, 2022, these participants could elect the limited lump sum distribution. This one-time lump sum was subsequently paid in August 2022 and resulted in a pension settlement charge of $7.8 million during the year ended September 30, 2022.
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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 gross margin 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, 2022 and 2021, our contract drilling backlog was $1.2 billion and $0.6 billion, respectively. The increase in backlog at September 30, 2022 from September 30, 2021 is primarily due to an increase in the number of fixed term drilling contracts executed. Approximately 30.8 percent of the September 30, 2022 total backlog is reasonably expected to be fulfilled in fiscal year 2024 and thereafter.
The following table sets forth the total backlog by reportable segment as of September 30, 2022 and 2021, and the percentage of the September 30, 2022 backlog reasonably expected to be fulfilled in fiscal year 2024 and thereafter:
(in millions) September 30, 2022 September 30, 2021 Percentage Reasonably
Expected to be Fulfilled in Fiscal Year 2024
and Thereafter
North America Solutions $ 863.6 $ 429.6 26.0 %
Offshore Gulf of Mexico 7.6 17.2 -
International Solutions 301.2 125.2 45.3
$ 1,172.4 $ 572.0
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 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, could have a material adverse effect on our business, financial condition and results of operations" within this Form 10-K.
Results of Operations for the Fiscal Years Ended September 30, 2022 and 2021
Consolidated Results of Operations
Net Income (Loss) We reported income from continuing operations of $6.6 million ($0.05 per diluted share) from operating revenues of $2.1 billion for the fiscal year ended September 30, 2022 compared to 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. Included in net income for the fiscal year ended September 30, 2022 is income of $0.4 million (with no impact on a per diluted share basis) from discontinued operations. Including discontinued operations, we recorded net income of $7.0 million ($0.05 per diluted share) for the fiscal year ended September 30, 2022 compared to a net loss of $326.2 million ($3.04 loss per diluted share) for the fiscal year ended September 30, 2021.
Operating Revenue Consolidated operating revenues were $2.1 billion in fiscal year 2022 and $1.2 billion in fiscal year 2021, including early termination revenue of $0.7 million and $7.7 million in each respective fiscal year. Excluding early termination revenue, operating revenue increased $0.8 billion in fiscal year 2022 compared to fiscal year 2021. The increase in fiscal year 2022 from fiscal year 2021 was primarily driven by an increase in average rig pricing and activity levels in our North America Solutions segment and increased activity levels in our International Solutions segment. Refer to segment results below for further details.
Direct Operating Expenses, Excluding Depreciation and Amortization Direct operating expenses in fiscal year 2022 were $1.4 billion, compared with $1.0 billion in fiscal year 2021. The increase in fiscal year 2022 from fiscal year 2021 was primarily attributable to the previously mentioned higher activity levels.
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Depreciation and Amortization Depreciation and amortization expense was $403.2 million in fiscal year 2022 and $419.7 million in fiscal year 2021. The decrease in depreciation and amortization during the fiscal year ended September 30, 2022 compared to the fiscal year ended September 30, 2021 was primarily attributable to the termination of depreciation on eight rigs that were included in the ADNOC sale during the fourth quarter of fiscal year 2021 coupled with ongoing relatively low levels of capital expenditures. Depreciation and amortization includes amortization of intangible assets of $7.2 million in fiscal years 2022 and 2021, and abandonments of equipment of $6.6 million and $2.0 million in fiscal years 2022 and 2021, respectively.
Selling, General and Administrative Expense Selling, general and administrative expenses increased to $182.4 million in the fiscal year ended September 30, 2022 compared to $172.2 million in the fiscal year ended September 30, 2021. The $10.2 million increase in fiscal year 2022 compared to fiscal year 2021 is primarily due to a $6.0 million increase in IT infrastructure spending, and a $5.6 million increase in labor and travel expense.
Asset Impairment Charges During the fiscal year ended September 30, 2022, we identified various assets that met the asset held-for-sale criteria and were reclassified as assets held-for-sale on our Consolidated Balance Sheets. The combined net book value of these assets was $5.4 million and were written down to their estimated fair value less cost to sell of $1.0 million, resulting in a non-cash impairment charge of $4.4 million, within our North America Solutions and International Solutions segments. The impairment charge was recorded in the Consolidated Statement of Operations for the fiscal year ended September 30, 2022. Comparatively, during the fiscal year ended September 30, 2021, the Company developed 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, which resulted in an impairment charge of $56.4 million. Also, 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, which resulted in a non-cash impairment charge of $14.4 million.
Gain on Investment Securities During the fiscal year ended September 30, 2022, we recognized an aggregate gain of $57.9 million on investment securities. This gain was primarily comprised of a $47.4 million gain on our equity investment in ADNOC Drilling caused by an increase in the fair market value of the stock. In September 2021, the Company made a cornerstone equity investment consisting of 159.7 million shares for $100.0 million as part of ADNOC Drilling's initial public offering. This investment is subject to a three-year lock-up period. Additionally, during the fiscal year ended September 30, 2022, we sold our remaining equity securities of approximately 467.5 thousand shares in Schlumberger, Ltd. and received proceeds of approximately $22.0 million. We recognized an aggregate gain of $8.2 million related to this investment, which included a $0.5 million gain recognized upon the sale and a $7.7 million gain as a result of the change in the fair value of the investment during the fiscal year ended September 30, 2022.
Restructuring Charges During the fiscal years ended September 30, 2022 and 2021, we incurred $0.8 million and $5.9 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.
Interest and Dividend Income Interest and dividend income was $18.1 million and $10.3 million in fiscal years 2022 and 2021, respectively. The increase in interest and dividend income in fiscal year 2022 was primarily due to $6.6 million of dividend income received as a result of our investment in ADNOC drilling.
Interest Expense Interest expense totaled $19.2 million in fiscal year 2022 and $24.0 million in fiscal year 2021. The decrease in interest expense is primarily attributable to a lower interest rate on our 2.90% Senior Notes due 2031 (issued in September 2021) as compared to our 4.65% Senior Notes due 2025, which was fully redeemed in October 2021.
Income Taxes We had an income tax expense of $24.4 million in fiscal year 2022 compared to an income tax benefit of $103.7 million in fiscal year 2021. The effective income tax rate was 78.8 percent in fiscal year 2022 compared to 23.5 percent in fiscal year 2021. The effective rates differ from the U.S. federal statutory rate (21.0 percent for the fiscal years 2022 and 2021) primarily due to non-deductible permanent items, the foreign derived intangible income deduction (in fiscal year 2022), state and foreign income taxes, and adjustments to the deferred state income tax rate. Additionally, the effective income tax rate is higher in fiscal year 2022 as the low level of net income before tax increases the impact of the rate differences.
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.
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Discontinued Operations Income from discontinued operations was $0.4 million and $11.3 million in fiscal years 2022 and 2021, respectively. 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 seizure 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 2022 and 2021 is caused by 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) 2022 2021 % Change
Operating revenues $ 1,788,167 $ 1,026,364 74.2 %
Direct operating expenses 1,218,134 773,507 57.5
Depreciation and amortization 375,250 392,415 (4.4)
Research and development 26,728 21,811 22.5
Selling, general and administrative expense 43,796 51,089 (14.3)
Asset impairment charges 1,868 70,850 (97.4)
Restructuring charges 498 3,868 (87.1)
Segment operating income (loss) $ 121,893 $ (287,176) (142.4)
Financial Data and Other Operating Statistics1:
Direct margin (Non-GAAP)2
$ 570,033 $ 252,857 125.4
Revenue days3
59,672 39,199 52.2
Average active rigs4
163 107 52.3
Number of active rigs at the end of period5
176 127 38.6
Number of available rigs at the end of period 236 236 -
Reimbursements of "out-of-pocket" expenses $ 232,092 $ 113,897 103.8
(1)These operating metrics and financial data, including average active rigs, are provided to 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.
(2)Direct margin, which is considered a non-GAAP metric, is defined as operating revenues less direct operating expenses and is included as a supplemental disclosure because we believe it is useful in assessing and understanding our current operational performance, especially in making comparisons over time. See - Non-GAAP Measurements below for a reconciliation of segment operating income (loss) to direct margin.
(3)Defined as the number of contractual days we recognized revenue for during the period.
(4)Active rigs generate revenue for the Company; accordingly, 'average active rigs' represents the average number of rigs generating revenue during the applicable time period. This metric is calculated by dividing revenue days by total days in the applicable period (i.e., 365 days).
(5)Defined as the number of rigs generating revenue at the applicable end date of the time period.
Operating Revenues Operating revenues were $1.8 billion and $1.0 billion in fiscal year 2022 and 2021, respectively. Operating revenues increased $0.8 billion in fiscal year 2022 compared to fiscal year 2021. This increase is primarily driven by higher pricing and higher activity levels.
Direct Operating Expenses Direct operating expenses increased to $1.2 billion during the fiscal year ended September 30, 2022 as compared to $0.8 billion during the fiscal year ended September 30, 2021. This increase was primarily driven by an increase of $241.0 million in labor expense and an increase of $87.0 million in materials and supplies as we experienced higher activity levels and had an increase in field wages beginning in December 2021.
Depreciation and Amortization Depreciation expense decreased to $375.3 million during the fiscal year ended September 30, 2022 as compared to $392.4 million during the fiscal year ended September 30, 2021. The decrease was primarily attributable to the termination of depreciation on eight rigs located in the U.S. that were included in the ADNOC sale during the fourth quarter of fiscal year 2021 coupled with ongoing relatively low levels of capital expenditures during the 2022 fiscal year.
Selling, General and Administrative Expenses We had a $7.3 million decrease in selling, general and administrative costs during the fiscal year ended September 30, 2022 compared to the fiscal year ended September 30, 2021. This decrease was primarily driven by a $5.3 million decrease in professional services fees.
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Asset Impairment Charges During the fiscal year ended September 30, 2022, we identified two partial rig substructures that met the asset held-for-sale criteria and were reclassified as assets held-for-sale on our Consolidated Balance Sheets. The combined net book value of these assets of $2.0 million were written down to their estimated scrap value of $0.1 million, resulting in a non-cash impairment charge of $1.9 million during the fiscal year ended September 30, 2022 in the Consolidated Statement of Operations. Comparatively, during the fiscal year ended September 30, 2021, the Company developed 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 during the year ended September 30, 2021. During the same period, we also 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, which resulted in a non-cash impairment charge of $14.4 million during the year ended September 30, 2021.
Restructuring Charges For the fiscal years ended September 30, 2022 and 2021, we incurred $0.5 million and $3.9 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.
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) 2022 2021 % Change
Operating revenues $ 125,465 $ 126,399 (0.7) %
Direct operating expenses 90,415 97,249 (7.0)
Depreciation 9,175 10,557 (13.1)
Selling, general and administrative expense 2,661 2,624 1.4
Segment operating income $ 23,214 $ 15,969 45.4
Financial Data and Other Operating Statistics1:
Direct margin (Non-GAAP)2
$ 35,050 $ 29,150 20.2
Revenue days3
1,460 1,552 (5.9)
Average active rigs4
4 4 -
Number of active rigs at the end of period5
4 4 -
Number of available rigs at the end of period 7 7 -
Reimbursements of "out-of-pocket" expenses $ 26,077 $ 27,388 (4.8)
(1)These operating metrics and financial data, including average active rigs, are provided to 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.
(2)Direct margin, which is considered a non-GAAP metric, is defined as operating revenues less direct operating expenses and is included as a supplemental disclosure because we believe it is useful in assessing and understanding our current operational performance, especially in making comparisons over time. See - Non-GAAP Measurements below for a reconciliation of segment operating income (loss) to direct margin.
(3)Defined as the number of contractual days we recognized revenue for during the period.
(4)Active rigs generate revenue for the Company; accordingly, 'average active rigs' represents the average number of rigs generating revenue during the applicable time period. This metric is calculated by dividing revenue days by total days in the applicable period (i.e., 365 days).
(5)Defined as the number of rigs generating revenue at the applicable end date of the time period.
Operating Revenues Operating revenues were $125.5 million and $126.4 million in the fiscal year ended September 30, 2022 and 2021, respectively. The 0.7 percent decrease in operating revenue is primarily driven by lower reimbursable expenses and the mix of rigs working at full rates as opposed to being on lower standby or mobilization rates, partially offset by pricing increases which occurred in the later portion of the 2022 fiscal year.
Direct Operating Expenses Direct operating expenses decreased to $90.4 million during the fiscal year ended September 30, 2022 as compared to $97.2 million during the fiscal year ended September 30, 2021. The decrease was primarily driven by a $6.3 million favorable adjustment in self-insurance liabilities related to prior period claims coupled with the factors described above.
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International Solutions
The following table presents certain information with respect to our International Solutions reportable segment:
(in thousands, except operating statistics) 2022 2021 % Change
Operating revenues $ 136,072 $ 57,917 134.9 %
Direct operating expenses 120,780 68,672 75.9
Depreciation 4,156 2,013 106.5
Selling, general and administrative expense 8,779 8,028 9.4
Asset impairment charges 2,495 - -
Restructuring charges - 207 (100.0)
Segment operating loss $ (138) $ (21,003) (99.3)
Financial Data and Other Operating Statistics1:
Direct margin (Non-GAAP)2
$ 15,292 $ (10,755) (242.2)
Revenue days3
3,036 1,815 67.3
Average active rigs4
8 5 60.0
Number of active rigs at the end of period5
12 6 100.0
Number of available rigs at the end of period 28 30 (6.7)
Reimbursements of "out-of-pocket" expenses $ 4,910 $ 6,693 (26.6)
(1)These operating metrics and financial data, including average active rigs, are provided to 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.
(2)Direct margin, which is considered a non-GAAP metric, is defined as operating revenues less direct operating expenses and is included as a supplemental disclosure because we believe it is useful in assessing and understanding our current operational performance, especially in making comparisons over time. See - Non-GAAP Measurements below for a reconciliation of segment operating income (loss) to direct margin.
(3)Defined as the number of contractual days we recognized revenue for during the period.
(4)Active rigs generate revenue for the Company; accordingly, 'average active rigs' represents the average number of rigs generating revenue during the applicable time period. This metric is calculated by dividing revenue days by total days in the applicable period (i.e., 365 days).
(5)Defined as the number of rigs generating revenue at the applicable end date of the time period.
Operating Revenues Operating revenues increased $78.2 million in fiscal year 2022 compared to fiscal year 2021. This increase is primarily driven by higher activity levels. Additionally, in the first quarter of fiscal year 2022, we recognized $16.4 million in revenue related to the settlement of a contract drilling dispute related to drilling services provided from fiscal years 2016 through 2019 with YPF S.A. Refer to Note 10-Revenue from Contracts with Customers for additional details.
Operating Expenses Direct operating expenses increased to $120.8 million during the fiscal year ended September 30, 2022 as compared to $68.7 million during the fiscal year ended September 30, 2021. This increase was primarily driven by an increase of $25.9 million in labor expense and an increase of $25.4 million in materials and supplies as we experienced higher activity levels.
Asset Impairment Charges During the fiscal year ended September 30, 2022, we identified two international FlexRig® drilling rigs that met the asset held-for-sale criteria and were reclassified as assets held-for-sale on our Consolidated Balance Sheets. In conjunction with establishing a plan to sell these rigs we recognized a non-cash impairment charge of $2.5 million during the fiscal year ended September 30, 2022 in the Consolidated Statement of Operations, as the rigs aggregate net book value of $3.4 million exceeded the fair value of the rigs less estimated cost to sell of $0.9 million. During the fiscal year ended September 30, 2021, we recorded no impairment charges.
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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) 2022 2021 % Change
Operating revenues $ 66,287 $ 43,304 53.1 %
Direct operating expenses 50,683 50,064 1.2
Depreciation 1,701 1,426 19.3
Research and development - 127 (100.0)
Selling, general and administrative expense 1,183 1,205 (1.8)
Restructuring charges - 186 (100.0)
Operating income (loss) $ 12,720 $ (9,704) (231.1)
Operating Revenues We continue to use our Captive insurance companies to insure the deductibles for our domestic workers’ compensation, general liability, automobile liability claims programs, and medical stop-loss program and to insure the deductibles from the Company's international casualty and rig property programs. Intercompany premium revenues recorded by the Captives during the fiscal years ended September 30, 2022 and 2021 amounted to $57.0 million and $35.4 million, respectively, which were eliminated upon consolidation.
Direct Operating Expenses Direct operating expenses consisted primarily of $7.0 million and $12.6 million in adjustments to accruals for estimated losses allocated to the Captives and rig and casualty insurance premiums of $35.6 million and $21.9 million during the fiscal years ended September 30, 2022 and 2021, respectively. The change to accruals for estimated losses is primarily due to actuarial valuation adjustments by our third-party actuary.
Results of Operations for the Fiscal Years Ended September 30, 2021 and 2020
A discussion of our results of operations for the fiscal year ended September 30, 2021 compared to the fiscal year ended September 30, 2020 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, 2021, filed with the Securities and Exchange Commission ("SEC") on November 18, 2021.
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, highly rated corporate bonds and commercial paper, certificates of deposit and money market funds. However, in some international locations we may make short-term investments that are less conservative, as equivalent highly rated investments are unavailable. See-Note 2-Summary of Significant Accounting Policies, Risks and Uncertainties-International Solutions Drilling Risks.
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.
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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 rigs, the timing of collections on outstanding accounts receivable, the timing of payments to our vendors for operating costs, and capital expenditures. 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 or cash flows as we have been able to more than offset these cumulative cost trends with rate increases.
As of September 30, 2022 and 2021, we had cash and cash equivalents of $232.1 million and $917.5 million and short-term investments of $117.1 million and $198.7 million, respectively. During the fiscal year ended September 30, 2022, our cash, cash equivalents, and restricted cash balance decreased approximately $667.7 million compared to our balance at September 30, 2021. This change was primarily driven by the redemption of all the outstanding 2025 Notes, resulting in a cash outflow of $487.1 million during the during the fiscal year ended September 30, 2022. Additionally, the associated make-whole premium of $56.4 million was paid during the first fiscal quarter of 2022 contemporaneously with the October 27, 2021 debt extinguishment.
Our cash flows for the fiscal years ended September 30, 2022, 2021 and 2020 are presented below:
Year Ended September 30,
(in thousands) 2022 2021 2020
Net cash provided by (used in):
Operating activities $ 233,913 $ 136,440 $ 538,881
Investing activities (167,315) (161,994) (87,885)
Financing activities (734,305) 425,523 (297,220)
Net increase (decrease) in cash and cash equivalents and restricted cash $ (667,707) $ 399,969 $ 153,776
Operating Activities
Our operating net working capital (non-GAAP) as of September 30, 2022, 2021, and 2020 is presented below:
Year Ended September 30,
(in thousands) 2022 2021 2020
Total current assets $ 1,002,944 $ 1,586,566 $ 963,327
Less:
Cash and cash equivalents 232,131 917,534 487,884
Short-term investments 117,101 198,700 89,335
Assets held-for-sale 4,333 71,453 -
649,379 398,879 386,108
Total current liabilities 394,810 866,306 219,136
Less:
Dividends payable 26,693 27,332 27,226
Current portion of long-term debt, net - 483,486 -
Advance payment for sale of property, plant and equipment 600 86,524 -
$ 367,517 $ 268,964 $ 191,910
Operating net working capital (non-GAAP) $ 281,862 $ 129,915 $ 194,198
Cash flows provided by operating activities were approximately $233.9 million, $136.4 million, and $538.9 million for the fiscal year ended September 30, 2022, 2021, and 2020 respectively. The change in cash provided by operating activities between fiscal years 2022 and 2021 is primarily driven by higher activity and rates, partially offset by changes in working capital. The decrease in cash provided by operating activities between fiscal years 2021 and 2020 was primarily driven by lower operating activity and lower pricing. 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, short-term debt and advance payments for sale of property, plant and equipment.
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Operating net working capital was $281.9 million, $129.9 million and $194.2 million as of September 30, 2022, 2021 and 2020, respectively. This metric is considered a non-GAAP measure of the Company's liquidity. The Company considers operating net working capital to be a supplemental measure for presenting and analyzing trends in our cash flows from operations over time. Likewise, the Company believes that operating net working capital is useful to investors because it provides a means to evaluate the operating performance of the business using criteria that are used by our internal decision makers. The increase in operating net working capital between fiscal years 2022 and 2021 was primarily driven by higher rig activity and rates. Included in accounts receivable as of September 30, 2022 was $27.8 million of income tax receivables, of which $24.9 million was received subsequent to fiscal year end. The remainder is expected to be collected within the next fiscal year.
Investing Activities
Capital Expenditures Our capital expenditures were $250.9 million, $82.1 million and $140.8 million in fiscal years 2022, 2021 and 2020, respectively. The increase in capital expenditures between fiscal years 2022 and 2021 is driven by higher activity and spending on walking rig conversions. The decrease in capital expenditures between fiscal years 2021 and 2020 was driven by lower maintenance capital expenditures as a result of lower activity. Our fiscal year 2023 capital spending is currently estimated to be between $425 million and $475 million. This estimate includes normal capital maintenance requirements, information technology spending, skidding to walking conversions for a limited number of rigs and plans to reactivate several super-spec rigs.
Purchases & Sales of Short-Term Investments Our net sales of short-term investments during fiscal year 2022 were $79.6 million compared to net purchases of $107.4 million and $40.0 million in fiscal years 2021 and 2020, respectively. The change is driven by our ongoing liquidity management.
Purchases of Long-Term Investments Our net purchases of long-term investments were $29.2 million, $102.5 million and $0.6 million in fiscal years 2022, 2021 and 2020, respectively. The decrease in net purchases between fiscal years 2022 and 2021 is primarily driven by our $100.0 million cornerstone investment in ADNOC Drilling purchased during fiscal year 2021, the $22.0 million of proceeds received from the liquidation of our remaining equity securities in Schlumberger, Ltd, during the fiscal year ended September 30, 2022, offset by the purchase of a $33.0 million cornerstone investment in a convertible note in Galileo Holdco 2 and the purchase of $18.2 million in various geothermal investments during fiscal year 2022. The increase in net purchases between fiscal years 2021 and 2020 is primarily driven by our purchase of ADNOC Drilling equity securities (as mentioned above) during fiscal year 2021 and the absence of such activity in fiscal year 2020.
Sale of Assets Our proceeds from asset sales totaled $62.3 million, $43.5 million and $78.4 million in fiscal year 2022, 2021 and 2020, respectively. The increase in proceeds between fiscal years 2022 and 2021 is mainly driven by higher rig activity which drives higher reimbursement from customers for lost or damaged drill pipe. The increase is also attributable to the sale of our casing running and trucking assets that occurred during the fiscal year ended September 30, 2022. 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, which was the primary driver in the decrease in proceeds between fiscal years 2021 and 2020.
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. We received the $86.5 million in cash consideration in advance of delivering the rigs.
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. During the fiscal year ended September 30, 2022 and 2020, we repurchased 3.2 million common shares at an aggregate cost of $77.0 million and 1.5 million common shares at an aggregate cost of $28.5 million, respectively, which are held as treasury shares. There were no purchases of common shares in fiscal year 2021.
Dividends We paid dividends of $1.00 per share during fiscal years 2022 and 2021 compared to $2.38 per share during fiscal year 2020. Total dividends paid were $107.4 million, $109.1 million and $260.3 million in fiscal years 2022, 2021 and 2020, respectively. A cash dividend of $0.25 per share was declared on September 7, 2022 for shareholders of record on November 15, 2022, payable on December 1, 2022.
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.
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Redemption of 4.65% Senior Notes due 2025 On October 27, 2021, we redeemed all of the outstanding 2025 Notes, resulting in a cash outflow of $487.1 million. As a result, the associated make-whole premium of $56.4 million was paid during the first fiscal quarter of 2022 contemporaneously with the October 27, 2021 debt extinguishment. 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. Additionally, on March 8, 2022, we entered into the second amendment to the 2018 Credit Facility, which, among other things, raised the number of potential future extensions of the maturity date applicable to extending lenders from one to two such potential extensions and replaced provisions in respect of interest rate determinations that were based on the London Interbank Offered Rate with provisions based on the Secured Overnight Financing Rate. Lenders with $680.0 million of commitments under the 2018 Credit Facility also exercised their option to extend the maturity of the 2018 Credit Facility from November 12, 2025 to November 11, 2026. 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. As of September 30, 2022, there were no borrowings or letters of credit outstanding, leaving $750.0 million available to borrow under the 2018 Credit Facility. For a full description of the 2018 Credit Facility, see Note 7-Debt to the Consolidated Financial Statements.
As of September 30, 2022, we had $55.0 million in uncommitted bilateral credit facilities, for the purpose of obtaining the issuance of international letters of credit, bank guarantees, and performance bonds. Of the $55.0 million, $38.1 million of financial guarantees were outstanding as of September 30, 2022. Separately, we had $2.0 million in standby letters of credit and bank guarantees outstanding. In total, we had $40.1 million outstanding as of September 30, 2022. In October 2022, we increased one of our standby letters of credit by $1.9 million.
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, 2022, 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 2023.
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. In June 2022, we settled a registered exchange offer (the “Registered Exchange Offer”) to exchange the 2031 Notes for new, SEC-registered notes that are substantially identical to the terms of the 2031 Notes, except that the offer and issuance of the new notes have been registered under the Securities Act and certain transfer restrictions, registration rights and additional interest provisions relating to the 2031 Notes do not apply to the new notes. One hundred percent of the 2031 Notes were exchanged in the Registered Exchange Offer.
The indenture governing the 2031 Notes 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 indenture governing the 2031 Notes 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. The debt issuance cost was 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.
2022 FORM 10-K | 48
On October 27, 2021, we redeemed all of the outstanding 2025 Notes. As a result, the associated make-whole premium of $56.4 million and the write off of the unamortized discount and debt issuance costs of $3.7 million were recognized during the first fiscal quarter of 2022 contemporaneously with the October 27, 2021 debt extinguishment and recorded in Loss on Extinguishment of Debt on our Consolidated Statements of Operations during the fiscal year ended September 30, 2022.
Future Cash Requirements
Our operating cash requirements, scheduled debt repayments, interest payments, any declared dividends, and estimated capital expenditures for fiscal year 2023 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 unsecured senior notes totaled $550.0 million at September 30, 2022 and matures on September 29, 2031.
As of September 30, 2022, we had a $537.7 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 levels of 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, 2022, we had $3.9 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 16.6 percent at September 30, 2022 compared to 15.9 percent at September 30, 2021. For additional information regarding debt agreements, refer to Note 7-Debt to the Consolidated Financial Statements.
There were no other significant changes in our financial position since September 30, 2021.
Material Commitments
Our contractual obligations as of September 30, 2022 are summarized in the table below:
Obligations due by year
(in thousands) Total 2023 2024 2025 2026 2027 Thereafter
Long-term debt 550,000 - - - - - 550,000
Interest1
144,724 16,066 16,069 16,073 16,076 16,080 64,360
Operating leases2
31,613 9,767 7,801 4,501 2,033 2,046 5,465
Purchase obligations3
148,600 148,600 - - - - -
Total contractual obligations $ 874,937 $ 174,433 $ 23,870 $ 20,574 $ 18,109 $ 18,126 $ 619,825
(1)Interest on fixed-rate 2031 Notes was estimated based on principal maturities. See Note 7-Debt to our Consolidated Financial Statements.
(2)See Note 5-Leases to our Consolidated Financial Statements.
(3)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 new reproduction costs 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 revenues are primarily comprised of daywork drilling contracts for which the related revenues and expenses are recognized as services are performed and collection is reasonably assured. With most drilling contracts, we receive payments contractually designated for the mobilization and demobilization of drilling rigs and other equipment to and from the client’s drill site. Revenue associated with the mobilization and demobilization of our drilling rigs to and from the client’s drill site do not relate to a distinct good or service. These revenues are deferred and recognized ratably over the related contract term that drilling services are provided. The amount of demobilization revenue that we ultimately collect is dependent upon the specific contractual terms, most of which include provisions for reduced or no payment for demobilization when, among other things, the contract is renewed or extended with the same client, or when the rig is subsequently contracted with another client prior to the termination of the current contract. Since revenues associated with demobilization activity are typically variable, at each period end, they are estimated at the most likely amount, and constrained when the likelihood of a significant reversal is probable. Direct costs incurred for the mobilization, are deferred and recognized on a straight-line basis as the drilling service is provided. While costs incurred to relocate rigs and other drilling equipment to areas in which a contract has not been secured are expensed as incurred.
We also act as a principal for certain reimbursable services and auxiliary equipment provided by us to our clients, for which we incur costs and earn revenues. Many of these costs are variable, or dependent upon the activity that is performed each day under the related contract. Accordingly, reimbursements that we receive for out-of-pocket expenses are recorded as revenues and the out-of-pocket expenses for which they relate are recorded as operating costs during the period to which they relate within the series of distinct time increments. 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.
Non-GAAP Measurements
Direct Margin
Direct margin is considered a non-GAAP metric. We define "Direct margin" as operating revenues less direct operating expenses. Direct margin is included as a supplemental disclosure because we believe it is useful in assessing and understanding our current operational performance, especially in making comparisons over time. Direct margin is not a substitute for financial measures prepared in accordance with GAAP and should therefore be considered only as supplemental to such GAAP financial measures.
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The following table reconciles direct margin to segment operating income (loss), which we believe is the financial measure calculated and presented in accordance with GAAP that is most directly comparable to direct margin.
Year Ended September 30, 2022
(in thousands) North America Solutions Offshore Gulf of Mexico International Solutions
Segment operating income (loss) $ 121,893 $ 23,214 $ (138)
Add back:
Depreciation and amortization 375,250 9,175 4,156
Research and development 26,728 - -
Selling, general and administrative expense 43,796 2,661 8,779
Asset impairment charges 1,868 - 2,495
Restructuring charges 498 - -
Direct margin (Non-GAAP) $ 570,033 $ 35,050 $ 15,292
Year Ended September 30, 2021
(in thousands) North America Solutions Offshore Gulf of Mexico International Solutions
Segment operating income (loss) $ (287,176) $ 15,969 $ (21,003)
Add back:
Depreciation and amortization 392,415 10,557 2,013
Research and development 21,811 - -
Selling, general and administrative expense 51,089 2,624 8,028
Asset impairment charges 70,850 - -
Restructuring charges 3,868 - 207
Direct margin (Non-GAAP) $ 252,857 $ 29,150 $ (10,755)

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ITEM 7A. QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK
ITEM 7A. QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK
Our financial position is exposed to a variety of risks, including foreign currency exchange rate risk, commodity price risk, credit and capital market risk, interest rate risk and equity price risk.
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. 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, 2022, 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 $0.4 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.
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.
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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 SOFR-based, on any borrowings from our revolving credit facility. There were no outstanding borrowings under this facility at September 30, 2022, and our outstanding debt consisted of $550.0 million (face amount) in senior unsecured notes, which have a fixed rate of 2.90 percent and an estimated fair value of $430.7 million and $554.3 million as of September 30, 2022 and 2021, respectively.
Equity Price Risk
As of September 30, 2022, we had equity securities in ADNOC Drilling with a total fair value of $147.4 million. As of September 30, 2021 we had equity securities in Schlumberger Ltd. with a total fair value of $13.9 million. Our investment in ADNOC Drilling is subject to a three-year lockup period. We have applied the guidance in Topic 820, Fair Value Measurement, in the initial accounting of the transaction and the subsequent revaluation of the investment balance, concluding that the contractual restriction on the sale of an equity security that is publicly traded is not considered in measuring fair value. During the fiscal year ended September 30, 2022, we sold our remaining equity securities of approximately 467.5 thousand shares in Schlumberger, Ltd. and received proceeds of approximately $22.0 million.
A hypothetical 10 percent decrease in the market price for our marketable equity securities as of September 30, 2022 would decrease the fair value by $14.7 million. 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 9, 2022, the total fair value of our equity securities decreased to approximately $147.0 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
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA
INDEX TO CONSOLIDATED FINANCIAL STATEMENTS
PAGE
Management’s Report on Internal Control over Financial Reporting
Reports of Independent Registered Public Accounting Firm (PCAOB ID Number 00042)
Consolidated Financial Statements:
Consolidated Balance Sheets at September 30, 2022 and 2021
Consolidated Statements of Operations for the Years Ended September 30, 2022, 2021 and 2020
Consolidated Statements of Comprehensive Income (Loss) for the Years Ended September 30, 2022, 2021 and 2020
Consolidated Statements of Shareholders’ Equity for the Years Ended September 30, 2022, 2021 and 2020
Consolidated Statements of Cash Flows for the Years Ended September 30, 2022, 2021 and 2020
Notes to Consolidated Financial Statements
2022 FORM 10-K | 54
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, 2022. 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, 2022.
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, 2022, 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 16, 2022 November 16, 2022
2022 FORM 10-K | 55
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, 2022 and 2021, the related consolidated statements of operations, comprehensive income (loss), shareholders' equity and cash flows for each of the three years in the period ended September 30, 2022, 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, 2022 and 2021, and the results of its operations and its cash flows for each of the three years in the period ended September 30, 2022, 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, 2022, 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 16, 2022 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 matter communicated below is a matter arising from the current period audit of the financial statements that was communicated or required to be communicated to the audit committee and that: (1) relates to accounts or disclosures that are material to the financial statements and (2) involved our especially challenging, subjective or complex judgments. The communication of the critical audit matter 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 matter below, providing a separate opinion on the critical audit matter or on the accounts or disclosures to which it relates.
Self-Insurance Accruals
Description of the Matter
The Company's self-insurance liability for workers’ compensation and other casualty claims was $72.3 million at September 30, 2022. 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.
2022 FORM 10-K | 56
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 estimates to ranges of estimates independently developed by our actuarial specialists.
/s/ Ernst & Young LLP
We have served as the Company’s auditor since 1994.
Tulsa, Oklahoma
November 16, 2022
2022 FORM 10-K | 57
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, 2022, 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, 2022, 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, 2022 and 2021, the related consolidated statements of operations, comprehensive income (loss), shareholders’ equity and cash flows for each of the three years in the period ended September 30, 2022, and the related notes and our report dated November 16, 2022 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 16, 2022
2022 FORM 10-K | 58
HELMERICH & PAYNE, INC.
CONSOLIDATED BALANCE SHEETS
September 30,
(in thousands except share data and per share amounts) 2022 2021
ASSETS
Current Assets:
Cash and cash equivalents $ 232,131 $ 917,534
Restricted cash 36,246 18,350
Short-term investments 117,101 198,700
Accounts receivable, net of allowance of $2,975 and $2,068, respectively
458,713 228,894
Inventories of materials and supplies, net 87,957 84,057
Prepaid expenses and other, net 66,463 67,578
Assets held-for-sale 4,333 71,453
Total current assets 1,002,944 1,586,566
Investments 218,981 135,444
Property, plant and equipment, net 2,960,809 3,127,287
Other Noncurrent Assets:
Goodwill 45,653 45,653
Intangible assets, net 67,154 73,838
Operating lease right-of-use assets 39,064 49,187
Other assets, net 20,926 16,153
Total other noncurrent assets 172,797 184,831
Total assets $ 4,355,531 $ 5,034,128
LIABILITIES & SHAREHOLDERS' EQUITY
Current Liabilities:
Accounts payable $ 126,966 $ 71,996
Dividends payable 26,693 27,332
Current portion of long-term debt, net - 483,486
Accrued liabilities 241,151 283,492
Total current liabilities 394,810 866,306
Noncurrent Liabilities:
Long-term debt, net 542,610 541,997
Deferred income taxes 537,712 563,437
Other 113,387 147,757
Noncurrent liabilities - discontinued operations 1,540 2,013
Total noncurrent liabilities 1,195,249 1,255,204
Commitments and Contingencies (Note 16)
Shareholders' Equity:
Common stock, $0.10 par value, 160,000,000 shares authorized, 112,222,865 shares issued as of September 30, 2022 and 2021, and 105,293,662 and 107,898,859 shares outstanding as of September 30, 2022 and 2021, respectively
11,222 11,222
Preferred stock, no par value, 1,000,000 shares authorized, no shares issued
- -
Additional paid-in capital 528,278 529,903
Retained earnings 2,473,572 2,573,375
Accumulated other comprehensive loss (12,072) (20,244)
Treasury stock, at cost, 6,929,203 shares and 4,324,006 shares as of September 30, 2022 and 2021, respectively
(235,528) (181,638)
Total shareholders’ equity 2,765,472 2,912,618
Total liabilities and shareholders' equity $ 4,355,531 $ 5,034,128
The accompanying notes are an integral part of these consolidated financial statements.
2022 FORM 10-K | 59
HELMERICH & PAYNE, INC.
CONSOLIDATED STATEMENTS OF OPERATIONS
Year Ended September 30,
(in thousands, except per share amounts) 2022 2021 2020
OPERATING REVENUES
Drilling services $ 2,049,841 $ 1,210,800 $ 1,761,714
Other 9,103 7,768 12,213
2,058,944 1,218,568 1,773,927
OPERATING COSTS AND EXPENSES
Drilling services operating expenses, excluding depreciation and amortization 1,426,589 952,600 1,184,788
Other operating expenses 4,638 5,138 5,777
Depreciation and amortization 403,170 419,726 481,885
Research and development 26,563 21,724 21,645
Selling, general and administrative 182,366 172,195 167,513
Asset impairment charges 4,363 70,850 563,234
Restructuring charges 838 5,926 16,047
Gain on reimbursement of drilling equipment (29,443) (12,322) (26,959)
Other (gain) loss on sale of assets (5,432) 11,280 (19,816)
2,013,652 1,647,117 2,394,114
OPERATING INCOME (LOSS) FROM CONTINUING OPERATIONS 45,292 (428,549) (620,187)
Other income (expense)
Interest and dividend income 18,090 10,254 7,304
Interest expense (19,203) (23,955) (24,474)
Gain (loss) on investment securities 57,937 6,727 (8,720)
Gain on sale of subsidiary - - 14,963
Loss on extinguishment of debt (60,083) - -
Other (11,115) (5,657) (5,384)
(14,374) (12,631) (16,311)
Income (loss) from continuing operations before income taxes 30,918 (441,180) (636,498)
Income tax expense (benefit) 24,366 (103,721) (140,106)
Income (loss) from continuing operations 6,552 (337,459) (496,392)
Income from discontinued operations before income taxes 401 11,309 30,580
Income tax provision - - 28,685
Income from discontinued operations 401 11,309 1,895
NET INCOME (LOSS) $ 6,953 $ (326,150) $ (494,497)
Basic earnings (loss) per common share:
Income (loss) from continuing operations $ 0.05 $ (3.14) $ (4.62)
Income from discontinued operations - 0.10 0.02
Net income (loss) $ 0.05 $ (3.04) $ (4.60)
Diluted earnings (loss) per common share:
Income (loss) from continuing operations $ 0.05 $ (3.14) $ (4.62)
Income from discontinued operations - 0.10 0.02
Net income (loss) $ 0.05 $ (3.04) $ (4.60)
Weighted average shares outstanding:
Basic 105,891 107,818 108,009
Diluted 106,555 107,818 108,009
The accompanying notes are an integral part of these consolidated financial statements.
2022 FORM 10-K | 60
HELMERICH & PAYNE, INC.
CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (LOSS)
Year ended September 30,
(in thousands) 2022 2021 2020
Net income (loss) $ 6,953 $ (326,150) $ (494,497)
Other comprehensive income, net of income taxes:
Net change related to employee benefit plans, net of income taxes of $2.3 million at September 30, 2022, $1.8 million at September 30, 2021 and $0.8 million at September 30, 2020
8,172 5,944 2,447
Other comprehensive income 8,172 5,944 2,447
Comprehensive income (loss) $ 15,125 $ (320,206) $ (492,050)
The accompanying notes are an integral part of these consolidated financial statements.
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HELMERICH & PAYNE, INC.
CONSOLIDATED STATEMENTS OF SHAREHOLDERS' EQUITY
Common Stock Additional
Paid-In
Capital Retained Earnings Accumulated
Other
Comprehensive
Income (Loss) Treasury Stock
(in thousands, except per share amounts) Shares Amount Shares Amount Total
Balance at September 30, 2019
112,080 $ 11,208 $ 510,305 $ 3,714,307 $ (28,635) 3,642 $ (194,962) $ 4,012,223
Comprehensive income (loss):
Net loss - - - (494,497) - - - (494,497)
Other comprehensive income - - - - 2,447 - - 2,447
Dividends declared ($1.92 per share)
- - - (209,798) - - - (209,798)
Exercise of employee stock options, net of shares withheld for employee taxes - - (3,151) - - (110) 7,195 4,044
Vesting of restricted stock awards, net of shares withheld for employee taxes 71 7 (21,855) - - (329) 18,119 (3,729)
Stock-based compensation - - 36,329 - - - - 36,329
Share repurchases - - - - - 1,460 (28,505) (28,505)
Balance at September 30, 2020
112,151 $ 11,215 $ 521,628 $ 3,010,012 $ (26,188) 4,663 $ (198,153) $ 3,318,514
Comprehensive income (loss):
Net loss - - - (326,150) - - - (326,150)
Other comprehensive income - - - - 5,944 - - 5,944
Dividends declared ($1.00 per share)
- - - (109,236) - - - (109,236)
Vesting of restricted stock awards, net of shares withheld for employee taxes 71 7 (18,683) - - (339) 16,515 (2,161)
Stock-based compensation - - 27,858 - - - - 27,858
Cumulative effect adjustment for adoption of ASU No. 2016-13 - - - (1,251) - - - (1,251)
Other - - (900) - - - - (900)
Balance at September 30, 2021
112,222 $ 11,222 $ 529,903 $ 2,573,375 $ (20,244) 4,324 $ (181,638) $ 2,912,618
Comprehensive income:
Net Income - - - 6,953 - - - 6,953
Other comprehensive income - - - - 8,172 - - 8,172
Dividends declared ($1.00 per share)
- - - (106,756) - - - (106,756)
Vesting of restricted stock awards, net of shares withheld for employee taxes - - (28,608) - - (550) 23,109 (5,499)
Stock-based compensation - - 28,032 - - - - 28,032
Share repurchases - - - - - 3,155 (76,999) (76,999)
Other - - (1,049) - - - (1,049)
Balance at September 30, 2022
112,222 $ 11,222 $ 528,278 $ 2,473,572 $ (12,072) 6,929 $ (235,528) $ 2,765,472
The accompanying notes are an integral part of these consolidated financial statements.
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HELMERICH & PAYNE, INC.
CONSOLIDATED STATEMENTS OF CASH FLOWS
Year Ended September 30,
(in thousands) 2022 2021 2020
CASH FLOWS FROM OPERATING ACTIVITIES:
Net income (loss) $ 6,953 $ (326,150) $ (494,497)
Adjustment for income from discontinued operations (401) (11,309) (1,895)
Income (loss) from continuing operations 6,552 (337,459) (496,392)
Adjustments to reconcile net income (loss) to net cash provided by operating activities:
Depreciation and amortization 403,170 419,726 481,885
Asset impairment charges 4,363 70,850 563,234
Amortization of debt discount and debt issuance costs 1,200 1,423 1,817
Loss on extinguishment of debt 60,083 - -
Provision for credit loss 1,081 203 2,203
Stock-based compensation 28,032 27,858 36,329
Loss (gain) on investment securities (57,937) (6,727) 8,720
Gain on reimbursement of drilling equipment (29,443) (12,322) (26,959)
Other (gain) loss on sale of assets (5,432) 11,280 (19,816)
Gain on sale of subsidiary - - (14,963)
Deferred income tax benefit (28,488) (89,752) (157,555)
Other 6,533 13,794 (2,423)
Change in assets and liabilities:
Accounts receivable (235,562) (28,416) 300,807
Inventories of materials and supplies (5,228) 19,847 9,420
Prepaid expenses and other 6,224 (21,400) (5,506)
Other noncurrent assets 2,581 2,772 2,820
Accounts payable 53,242 31,027 (9,414)
Accrued liabilities 45,069 33,957 (138,414)
Deferred income tax liability 447 1,101 908
Other noncurrent liabilities (22,501) (1,274) 2,227
Net cash provided by operating activities from continuing operations 233,986 136,488 538,928
Net cash used in operating activities from discontinued operations (73) (48) (47)
Net cash provided by operating activities 233,913 136,440 538,881
CASH FLOWS FROM INVESTING ACTIVITIES:
Capital expenditures (250,894) (82,148) (140,795)
Other capital expenditures related to assets held-for-sale (21,645) - -
Purchase of short-term investments (165,109) (315,078) (134,641)
Purchase of long-term investments (51,241) (102,523) (550)
Proceeds from sale of short-term investments 244,728 207,716 94,646
Proceeds from sale of long-term investments 22,042 - -
Proceeds from sale of subsidiary - - 15,056
Proceeds from asset sales 62,304 43,515 78,399
Advance payment for sale of property, plant and equipment - 86,524 -
Other (7,500) - -
Net cash used in investing activities (167,315) (161,994) (87,885)
CASH FLOWS FROM FINANCING ACTIVITIES:
Dividends paid (107,395) (109,130) (260,335)
Proceeds from debt issuance - 548,719 -
Debt issuance costs - (3,935) -
Proceeds from stock option exercises - - 4,100
Payments for employee taxes on net settlement of equity awards (5,505) (2,162) (3,784)
Payment of contingent consideration from acquisition of business (250) (7,250) (8,250)
Payments for early extinguishment of long-term debt (487,148) - -
Make-whole premium payment (56,421) - -
Share repurchases (76,999) - (28,505)
Other (587) (719) (446)
Net cash provided by (used in) financing activities (734,305) 425,523 (297,220)
Net increase (decrease) in cash and cash equivalents and restricted cash (667,707) 399,969 153,776
Cash and cash equivalents and restricted cash, beginning of period 936,716 536,747 382,971
Cash and cash equivalents and restricted cash, end of period $ 269,009 $ 936,716 $ 536,747
The accompanying notes are an integral part of these consolidated financial statements.
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HELMERICH & PAYNE, INC.
CONSOLIDATED STATEMENTS OF CASH FLOWS (CONTINUED)
Year Ended September 30,
(in thousands) 2022 2021 2020
SUPPLEMENTAL DISCLOSURE OF CASH FLOW INFORMATION:
Cash paid during the period:
Interest paid $ 18,909 $ 26,706 $ 22,928
Income tax paid (received), net 17,669 (32,462) 46,700
Cash paid for amounts included in the measurement of lease liabilities:
Payments for operating leases 11,233 17,266 18,646
Non-cash operating and investing activities:
Changes in accounts payable and accrued liabilities related to purchases of property, plant and equipment (2,425) (1,526) 3,123
Changes in accounts receivable, property, plant and equipment and other noncurrent assets related to the sale of equipment - 9,290 -
Cumulative effect adjustment for adoption of ASU No. 2016-13 - (1,251) -
The accompanying notes are an integral part of these consolidated financial statements.
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HELMERICH & PAYNE, INC.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
NOTE 1 NATURE OF OPERATIONS
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.
Our drilling services operations are organized into the following reportable operating business segments: North America Solutions, Offshore Gulf of Mexico and International Solutions. Our real estate operations, our incubator program for new research and development projects and our wholly-owned captive insurance companies are included in "Other." Refer to Note 17-Business Segments and Geographic Information for further details on our reportable segments.
Our North America Solutions operations are primarily located in Texas, but traditionally also operate in other states, depending on demand. Such states include: Colorado, Louisiana, New Mexico, North Dakota, Ohio, Oklahoma, Pennsylvania, Utah, West Virginia and Wyoming. Additionally, Offshore Gulf of Mexico operations are conducted in Louisiana and in U.S. federal waters in the Gulf of Mexico and our International Solutions operations have rigs and/or services primarily located in four international locations: Argentina, Bahrain, Colombia and United Arab Emirates.
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 and undeveloped real estate.
Fiscal Year 2020 Dispositions
In December 2019, we closed on the sale of a wholly-owned subsidiary of Helmerich & Payne International Drilling Co. ("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. Prior to the sale, TerraVici was a component of the North America Solutions operating segment. This transaction did not represent a strategic shift in our operations and will not have a significant effect on our operations and financial results going forward.
NOTE 2 SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES, RISKS AND UNCERTAINTIES
Basis of Presentation
The accompanying consolidated financial statements are prepared in accordance with accounting principles generally accepted in the United States of America (“U.S. GAAP”).
We classified our former Venezuelan operation as a discontinued operation in the third quarter of fiscal year 2010, as more fully described in Note 3-Discontinued Operations. Unless indicated otherwise, the information in the Notes to Consolidated Financial Statements relates only to our continuing operations.
Principles of Consolidation
The Consolidated Financial Statements include the accounts of Helmerich & Payne, Inc. and its domestic and foreign subsidiaries. Consolidation of a subsidiary begins when the Company gains control over the subsidiary and ceases when the Company loses control of the subsidiary. Specifically, income, expenses and other comprehensive income or loss of a subsidiary acquired or disposed of during the fiscal year are included in the Consolidated Statements of Operations and Comprehensive Income from the date the Company gains control until the date when the Company ceases to control the subsidiary. All intercompany accounts and transactions have been eliminated upon consolidation.
Foreign Currencies
Our functional currency, together with all our foreign subsidiaries, is the U.S. dollar. Monetary assets and liabilities denominated in currencies other than the U.S. dollar are translated at exchange rates in effect at the end of the period, and the resulting gains and losses are recorded on our Consolidated Statements of Operations. Aggregate foreign currency losses of $5.9 million, $5.3 million and $8.8 million in fiscal years 2022, 2021 and 2020, respectively, are included in drilling services operating expenses.
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Use of Estimates
The preparation of our financial statements in conformity with U.S. GAAP requires management to make estimates and assumptions that affect reported amounts of assets and liabilities, disclosure of contingent assets and liabilities at the date of the financial statements, and the reported amounts of revenues and expenses during the reporting period. Actual results could differ from those estimates.
Cash, Cash Equivalents, and Restricted Cash
Cash and cash equivalents include cash on hand, demand deposits with banks and all highly liquid investments with original maturities of three months or less. Our cash, cash equivalents and short-term investments are subject to potential credit risk, and certain of our cash accounts carry balances greater than the federally insured limits.
We had restricted cash of $36.9 million and $19.2 million at September 30, 2022 and 2021, respectively. Of the total at September 30, 2022 and 2021, $1.1 million and $1.5 million, respectively, is related to the acquisition of drilling technology companies, and $35.8 million and $17.7 million, respectively, represents an amount management has elected to restrict for the purpose of potential insurance claims in our wholly-owned captive insurance companies. The restricted amounts are primarily invested in short-term money market securities.
Cash, cash equivalents, and restricted cash are reflected in the Consolidated Balance Sheets as follows:
September 30,
(in thousands) 2022 2021 2020
Cash and cash equivalents $ 232,131 $ 917,534 $ 487,884
Restricted cash 36,246 18,350 45,577
Restricted cash - long-term:
Other assets, net 632 832 3,286
Total cash, cash equivalents, and restricted cash $ 269,009 $ 936,716 $ 536,747
During the fiscal year ended September, 30, 2022, and to conform with the current year presentation, we reclassified $18.4 million and $45.6 million of restricted cash that was previously included in Prepaid expenses and other in our Consolidated Balance Sheets as of September 30, 2021 and 2020, respectively.
Accounts Receivable
Accounts receivable represents valid claims against our customers for our services rendered, net of allowances for credit losses. We perform credit evaluations of customers and do not typically require collateral in support for trade receivables. We provide an allowance for credit losses, when necessary, to cover estimated credit losses. Outstanding customer receivables are reviewed regularly for possible nonpayment indicators. We estimate expected credit losses over the life of our financial assets, which primarily consist of our accounts receivable. We evaluate our customers’ financial strength and liquidity based on aging of accounts receivable, payment history, and other relevant information, including ratings agency, credit ratings and alerts, and publicly available reports.
Inventories of Materials and Supplies
Inventories are primarily replacement parts and supplies held for consumption in our drilling operations. Inventories are valued at the lower of cost or net realizable value. Cost is determined on a weighted average basis and includes the cost of materials, shipping, duties and labor. Net realizable value is defined as the estimated selling price in the ordinary course of business, less reasonably predictable costs of completion, disposal and transportation. The reserves for excess and obsolete inventory were $28.0 million and $29.3 million for fiscal years 2022 and 2021, respectively.
Investments
We maintain investments in equity and debt securities of certain publicly traded and private companies. We recognize our equity securities that have readily determinable fair values at fair value, with changes in such values reflected in net income. Our equity securities without readily determinable fair values are measured at cost, less any impairments. Debt securities classified as available-for-sale are reported at fair value and subject to impairment testing. Other than impairment losses, unrealized gains/losses are recognized, net of the related tax effect, in other comprehensive income. Upon sale, realized gains/losses are reported in net income.
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Property, Plant, and Equipment
Property, plant and equipment are carried at cost less accumulated depreciation. Substantially all property, plant and equipment are depreciated using the straight-line method based on the estimated useful lives of the assets after deducting their salvage values. The amount of depreciation expense we record is dependent upon certain assumptions, including an asset’s estimated useful life, rate of consumption, and corresponding salvage value. We periodically review these assumptions and may change one or more of these assumptions. Changes in our assumptions may require us to recognize, on a prospective basis, increased or decreased depreciation expense.
We review long-lived assets for impairment whenever events or changes in circumstances indicate that the carrying amount of an asset may not be recoverable. Changes that could prompt such an assessment include a significant decline in revenue or cash margin per day, extended periods of low rig asset group utilization, changes in market demand for a specific asset, obsolescence, restructuring of our drilling fleet, and/or overall general market conditions. If the review of the long-lived assets indicates that the carrying value of these assets/asset groups is more than the estimated undiscounted future cash flows projected to be realized from the use of the asset and its eventual disposal an impairment charge is recognized, as required, to adjust the carrying value down to the estimated fair value of the asset. The estimated fair value 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.
Cash flows are estimated by management considering factors such as prospective market demand, margins, recent changes in rig technology and its effect on each rig’s marketability, any investment required to make a rig operational, suitability of rig size and make up to existing platforms, and competitive dynamics including industry utilization. Long-lived assets that are held for sale are recorded at the lower of carrying value or the fair value less costs to sell.
Goodwill and Intangible Assets
Goodwill represents the excess of the purchase price over the fair value of assets acquired and liabilities assumed in a business combination, at the date of acquisition. Goodwill is not amortized, but is tested for potential impairment at the reporting unit level at a minimum on an annual basis in the fourth fiscal quarter of each fiscal year or when it is more likely than not that the carrying value may exceed fair value. If an impairment is determined to exist, an impairment charge for the amount by which the carrying amount exceeds the reporting unit's fair value is recognized, limited to the total amount of goodwill allocated to that reporting unit. The reporting unit level is defined as an operating segment or one level below an operating segment.
Finite-lived intangible assets are amortized using the straight-line method over the period in which these assets contribute to our cash flows, generally estimated to be 5 to 20 years, and are evaluated for impairment in accordance with our policies for valuation of long-lived assets.
Drilling Revenues
Drilling services revenues are primarily 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. Revenues associated with mobilization and demobilization 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 both revenues and direct costs. Reimbursements for fiscal years 2022, 2021 and 2020 were $263.1 million, $148.0 million and $212.0 million, respectively. For fixed-term contracts that are terminated by customers prior to the expirations, contractual provisions customarily require early termination amounts to be paid to us. Revenues from early terminated contracts are recognized when all contractual requirements have been met. Early termination revenue for fiscal years 2022, 2021 and 2020 was approximately $0.7 million, $7.7 million and $73.4 million, respectively.
Rent Revenues and Related Property
We enter into leases with tenants in our rental properties consisting primarily of retail space. The lease terms of tenants occupying space in the retail centers generally range from three to ten years. Minimum rents are recognized on a straight-line basis over the term of the related leases. Overage and percentage rents are based on tenants’ sales volume. Recoveries from tenants for property taxes and operating expenses are recognized in other operating revenues in the Consolidated Statements of Operations.
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Our rent revenues are as follows:
Year Ended September 30,
(in thousands) 2022 2021 2020
Minimum rents $ 6,362 $ 5,589 $ 9,245
Overage and percentage rents 773 726 656
At September 30, 2022, minimum future rental income to be received on noncancellable operating leases was as follows:
Fiscal Year Amount
(in thousands)
2023 $ 5,214
2024 4,519
2025 3,733
2026 2,820
2027 1,575
Thereafter 2,241
Total $ 20,102
Leasehold improvement allowances are capitalized and amortized over the lease term.
At September 30, 2022 and 2021, the cost and accumulated depreciation for real estate properties were as follows:
September 30,
(in thousands) 2022 2021
Real estate properties $ 45,557 $ 43,302
Accumulated depreciation (30,510) (28,846)
$ 15,047 $ 14,456
Income Taxes
Current income tax expense is the amount of income taxes expected to be payable for the current fiscal year. Deferred income taxes are computed using the liability method and are provided on all temporary differences between the financial basis and the tax basis of our assets and liabilities.
We take tax positions in our tax returns from time to time that may not ultimately be allowed by the relevant taxing authority. When we take such positions, we evaluate the likelihood of sustaining those positions and determine the amount of tax benefit arising from such positions, if any, that should be recognized in our financial statements. We recognize uncertain tax positions we believe have a greater than 50 percent likelihood of being sustained. Tax benefits not recognized by us are recorded as a liability for unrecognized tax benefits, which represents our potential future obligation to various taxing authorities if the tax positions are not sustained. See Note 8-Income Taxes. Amounts for uncertain tax positions are adjusted in periods when new information becomes available or when positions are effectively settled. We recognize accrued interest related to unrecognized tax benefits in interest expense and penalties in other expense in the Consolidated Statements of Operations.
Earnings per Common Share
Basic earnings per share is computed utilizing the two-class method and is calculated based on the weighted-average number of common shares outstanding during the periods presented. Diluted earnings per share is computed using the weighted-average number of common and common equivalent shares outstanding during the periods utilizing the two-class method for stock options, nonvested restricted stock and performance share units. We have granted and expect to continue to grant to employees restricted stock grants that contain non-forfeitable rights to dividends. Such grants are considered participating securities under Accounting Standards Codification ("ASC") 260, Earnings Per Share. As such, we have included these grants in the calculation of our basic earnings per share.
Stock-Based Compensation
Stock-based compensation expense is determined using a fair-value-based measurement method for all awards granted. The fair value of restricted stock awards is determined based on the closing price of our shares on the grant date. The grant date fair value of performance share units is determined through the use of the Monte Carlo simulation method. The Monte Carlo simulation method requires the use of highly subjective assumptions. Our key assumptions in the method include the price and the expected volatility of our stock and our self-determined peer group of companies’ (the "Peer Group") stock, risk free rate of return, dividend yields and cross-correlations between the Company and our Peer Group.
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Stock-based compensation is recognized on a straight-line basis over the requisite service periods of the stock awards, which is generally the vesting period. Stock-based compensation expense is recorded as a component of drilling services operating expenses, research and development expenses and selling, general and administrative expenses in the Consolidated Statements of Operations. See Note 11-Stock-based Compensation for additional discussion on stock-based compensation.
Treasury Stock
Treasury stock purchases are accounted for under the cost method whereby the cost of the acquired stock is recorded as treasury stock. Gains and losses on the subsequent reissuance of shares are credited or charged to additional paid-in capital using the average-cost method. Treasury stock may be issued under the Helmerich & Payne, Inc. 2020 Omnibus Incentive Plan.
Comprehensive Income or Loss
Other comprehensive income or loss refers to revenues, expenses, gains, and losses that are included in comprehensive income or loss but excluded from net income or loss. We report the components of other comprehensive income or loss, net of tax, by their nature and disclose the tax effect allocated to each component in the Consolidated Statements of Comprehensive Income (Loss).
Leases
We lease various offices, warehouses, equipment and vehicles. Rental contracts are typically made for fixed periods of one to 15 years but may have extension options. Lease terms are negotiated on an individual basis and contain a wide range of different terms and conditions. The lease agreements do not impose any covenants, but leased assets may not be used as security for borrowing purposes.
Leases are recognized as a right-of-use asset and a corresponding liability within accrued liabilities and other non-current liabilities at the date at which the leased asset is available for use by the Company. Operating lease expense is recognized on a straight-line basis over the life of the lease. The right-of-use asset is depreciated over the shorter of the asset's useful life and the lease term on a straight-line basis for finance type leases.
Assets and liabilities arising from a lease are initially measured on a present value basis. Lease liabilities include the net present value of the following lease payments:
•Fixed payments (including in-substance fixed payments), less any lease incentives receivable
•Variable lease payments that are based on an index or a rate
•Amounts expected to be payable by the lessee under residual value guarantees
•The exercise price of a purchase option if the lessee is reasonably certain to exercise that option, and
•Payments of penalties for terminating the lease, if the lease term reflects the lessee exercising that option.
The lease payments are discounted using the interest rate implicit in the lease. If that rate cannot be determined, our incremental borrowing rate is used, which is the rate that we would have to pay to borrow the funds necessary to obtain an asset of similar value in a similar economic environment with similar terms and conditions.
Right-of-use assets are measured at cost and are comprised of the following:
•The amount of the initial measurement of lease liability
•Any lease payments made at or before the commencement date less any lease incentives received
•Any initial direct costs, and
•Asset retirement obligations related to that lease, as applicable.
Payments associated with short-term leases are recognized on a straight-line basis as an expense in profit or loss. Short-term leases are leases with a lease term of 12 months or less.
In determining the lease term, management considers all facts and circumstances that create an economic incentive to exercise an extension option, or not exercise a termination option. Extension options (or periods after termination options) are only included in the lease term if the lease is reasonably certain to be extended (or not terminated). The assessment is reviewed if a significant event or a significant change in circumstances occurs and is within our control. Refer to Note 5-Leases for additional information regarding our leases.
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Recently Issued Accounting Updates
Changes to U.S. GAAP are established by the Financial Accounting Standards Board (“FASB”) in the form of Accounting Standards Updates ("ASUs") to the FASB Accounting Standards Codification ("ASC"). We consider the applicability and impact of all ASUs. ASUs not listed below were assessed and determined to be either not applicable, clarifications of ASUs listed below, immaterial, or already adopted by the Company.
The following table provides a brief description of a recently adopted accounting pronouncement and our analysis of the effects on our financial statements:
Standard Description Date of
Adoption Effect on the Financial
Statements or Other Significant Matters
Recently Adopted Accounting Pronouncements
ASU No. 2019-12, Financial Instruments - Income Taxes (Topic 740): Simplifying the Accounting for Income Taxes This ASU simplifies the accounting for income taxes by removing certain exceptions related to Topic 740. The ASU also improves consistent application of and simplifies GAAP for other areas of Topic 740 by clarifying and amending existing guidance. This update is effective for annual and interim periods beginning after December 15, 2020. Early adoption of the amendment is permitted, including adoption in any interim period for public entities for periods for which financial statements have not yet been issued. An entity that elects to early adopt the amendments in an interim period should reflect any adjustments as of the beginning of the annual period that includes that interim period. Additionally, an entity that elects early adoption must adopt all the amendments in the same period. Upon adoption, the amendments addressed in this ASU will be applied either prospectively, retrospectively or on a modified retrospective basis through a cumulative effect adjustment to retained earnings. This update is effective for annual periods beginning after December 15, 2020. October 1, 2021 We adopted this ASU, as required, during the first quarter of fiscal year 2022. The adoption did not have a material effect on our Consolidated Financial Statements and disclosures.
Standards that are not yet adopted as of September 30, 2022
ASU No. 2020-06, Debt with conversion and other options (Subtopic 470-20) and Derivatives and Hedging - Contracts in Entity’s own equity (subtopic 815-40): Accounting For Convertible Instruments and Contracts In An Entity’s Own Equity This ASU reduces the complexity of accounting for convertible debt and other equity-linked instruments by reducing the number of accounting models for convertible debt instruments and convertible preferred stock. Limiting the accounting models results in fewer embedded conversion features being separately recognized from the host contract as compared with current GAAP. Convertible instruments that continue to be subject to separation models are (1) those with embedded conversion features that are not clearly and closely related to the host contract, that meet the definition of a derivative, and that do not qualify for a scope exception from derivative accounting and (2) convertible debt instruments issued with substantial premiums for which the premiums are recorded as paid-in capital. This update is effective for annual and interim periods beginning after December 15, 2021. Early adoption of the amendment is permitted.
October 1, 2022 We plan to adopt this ASU, as required, during the first quarter of fiscal year 2023. We do not believe the adoption will have a material effect on our Consolidated Financial Statements and disclosures.
ASU No. 2022-03, Fair Value Measurement (Topic 820): Fair Value Measurement of Equity Securities Subject to Contractual Sale Restrictions The amendments in this update clarify that a contractual restriction on the sale of an equity security is not considered part of the unit of account of the equity security and, therefore, is not considered in measuring fair value (i.e., the entity would not apply a discount related to the contractual sale restriction). Furthermore, an entity cannot, as a separate unit of account, recognize and measure a contractual sale restriction. The following disclosures for equity securities subject to contractual sale restrictions will be required: (1) the fair value of the equity securities subject to contractual sale restrictions reflected in the balance sheet, (2) the nature and remaining duration of the restriction(s), and (3) the circumstances that could cause a lapse in the restriction(s). This update is effective for annual and interim periods beginning after December 15, 2023. Early adoption of the amendment is permitted for both interim and annual financial statements. October 1, 2022 We plan to early adopt this ASU during the first quarter of fiscal year 2023. We do not believe the adoption will have a material effect on our Consolidated Financial Statements and disclosures.
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Allowance for Credit Losses
On October 1, 2020, we adopted ASU 2016-13 on a modified retrospective basis through a cumulative-effect adjustment without restating comparative periods, as permitted under the adoption provisions. Upon adoption, we recognized a $1.6 million increase to our allowance for credit losses and a corresponding cumulative adjustment to reduce retained earnings, net of income taxes, of $1.3 million. This transition adjustment reflects the development of our models to estimate expected credit losses over the life of our financial assets, which primarily consist of our accounts receivable. Pursuant to ASU 2016-13, we have evaluated our customers’ financial strength and liquidity based on aging of accounts receivable, payment history, and other relevant information, including ratings agency, credit ratings and alerts, and publicly available reports.
Concentration of Credit Risk
Financial instruments, which potentially subject us to concentrations of credit risk, consist primarily of temporary cash investments, short and long-term investments, and trade receivables. The industry concentration has the potential to impact our overall exposure to market and credit risks, either positively or negatively, in that our customers could be affected by similar changes in economic, industry or other conditions. However, we believe that the credit risk posed by this industry concentration is offset by the creditworthiness of our customer base. In fiscal years 2022, 2021 and 2020, no individual customers constituted 10 percent or more of our total consolidated revenues.
We place temporary cash investments in the United States with established financial institutions and primarily invest in a diversified portfolio of highly rated, short-term instruments. Our trade receivables, primarily with established companies in the oil and gas industry, may impact credit risk as customers may be similarly affected by prolonged changes in economic and industry conditions. International sales also present various risks including governmental activities that may limit or disrupt markets and restrict the movement of funds. Most of our international sales, however, are to large international or government-owned national oil companies.
Volatility of Market
Our operations can be materially affected by oil and gas prices. Oil and natural gas prices have been historically volatile and 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 a customer’s future spending levels. This volatility, along with the difficulty in predicting future prices, can lead many exploration and production companies to base their capital spending on more conservative estimates of commodity prices. As a result, demand for drilling services is not always purely a function of the movement of commodity prices.
In addition, 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 may cause difficulty 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 a reduction in customer spending and the demand for our services. This reduction in spending could have a material adverse effect on our operations.
Self-Insurance
We have accrued a liability for estimated workers’ compensation and other casualty claims incurred based upon case reserves plus an estimate of loss development and incurred but not reported claims. The estimate is based upon historical trends. Insurance recoveries related to such liability are recorded when considered probable.
We self-insure a significant portion of expected losses relating to workers’ compensation, general 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. Estimates are recorded for incurred outstanding liabilities for workers’ compensation, general, and automobile liability claims that are incurred but not reported. Estimates are based on adjusters’ estimates, historical experience and statistical methods commonly used within the insurance industry that we believe are reliable. We have also engaged a third-party actuary to perform a review of our casualty losses as well as losses in our captive insurance companies. 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.
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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. 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 an 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. Direct operating costs consisted primarily of adjustments to accruals for estimated losses of $7.0 million, $12.6 million, and $16.4 million and rig and casualty insurance premiums of $35.6 million, $21.9 million, and $6.7 million during the fiscal years ended September 30, 2022, 2021, and 2020 respectively. These operating costs were recorded within drilling services operating expenses in our Consolidated Statement of Operations. Intercompany premium revenues recorded by the Captives during the fiscal years ended September 30, 2022, 2021, and 2020 amounted to $57.0 million, $35.4 million, and $36.9 million respectively, which were eliminated upon consolidation. These intercompany insurance premiums are reflected as segment operating expenses within the North America Solutions, Offshore Gulf of Mexico, and International Solutions reportable operating segments and are reflected as intersegment sales within "Other." The Company self-insures employee health plan exposures in excess of employee deductibles. Starting in the second quarter of fiscal year 2020, the Captive insurer issued a stop-loss program that will reimburse the Company's health plan for claims that exceed $50,000. This program is reviewed at the end of each policy year by an outside actuary. Our medical stop loss operating expenses for the fiscal year ended September 30, 2022, 2021, and 2020 were $11.8 million, $12.0 million, and $8.0 million respectively.
International Solutions Drilling Risks
International Solutions drilling operations may significantly contribute to our revenues and net operating income (loss). There can be no assurance that we will be able to successfully conduct such operations, and a failure to do so may have an adverse effect on our financial position, results of operations, and cash flows. Also, the success of our International Solutions operations will be subject to numerous contingencies, some of which are beyond management’s control. These contingencies include general and regional economic conditions, fluctuations in currency exchange rates, modified exchange controls, changes in international regulatory requirements and international employment issues, risk of expropriation of real and personal property and the burden of complying with foreign laws. Additionally, in the event that extended labor strikes occur or a country experiences significant political, economic or social instability, we could experience shortages in labor and/or material and supplies necessary to operate some of our drilling rigs, thereby potentially causing an adverse material effect on our business, financial condition and results of operations.
We have also experienced certain risks specific to our Argentine operations. In Argentina, while our dayrate is denominated in U.S. dollars, we are paid the equivalent in Argentine pesos. 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. Argentina also has a history of implementing currency controls that restrict the conversion and repatriation of U.S. dollars. In September 2020, Argentina implemented additional currency controls in an effort to preserve Argentina's U.S. dollar reserves. As a result of these currency controls, our ability to remit funds from our Argentine subsidiary to its U.S. parent has been limited. In the past, the Argentine government has also instituted price controls on crude oil, diesel and gasoline prices and instituted an exchange rate freeze in connection with those prices. These price controls and an exchange rate freeze could be instituted again in the future. Further, there are additional concerns regarding Argentina's debt burden, notwithstanding Argentina's restructuring deal with international bondholders in August 2020, as Argentina attempts to manage its substantial sovereign debt issues. These concerns could further negatively impact Argentina's economy and adversely affect our Argentine operations. Argentina’s economy is 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 subsidiaries 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.
We recorded aggregate foreign currency losses of $5.9 million, $5.3 million, and $8.8 million the fiscal years ended September 30, 2022, 2021, and 2020 respectively.
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 hold only a minority interest or pursuant to arrangements under which we conduct operations under contract to local entities. While we believe that neither operating through such entities nor pursuant to such arrangements would have a material adverse effect on our operations or revenues, 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 acceptable to us.
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Although we attempt to minimize the potential impact of such risks by operating in more than one geographical area, during the fiscal year ended September 30, 2022, approximately 6.7 percent of our operating revenues were generated from international locations compared to 5.0 percent during the fiscal year ended September 30, 2021. During the fiscal year ended September 30, 2022, approximately 81.6 percent of operating revenues from international locations were from operations in South America compared to 48.9 percent during the fiscal year ended September 30, 2021. Substantially all of the South American operating revenues were from Argentina and Colombia. 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.
NOTE 3 DISCONTINUED OPERATIONS
Noncurrent liabilities from discontinued operations include an uncertain tax liability related to the country of Venezuela. Expenses incurred for in-country obligations are reported as discontinued operations within our Consolidated Statements of Operations.
The activity for each fiscal year presented was due to the remeasurement of an uncertain tax liability as a result of the devaluation of the Venezuela Bolivar. Early in 2018, the Venezuelan government announced that it changed the existing dual-rate foreign currency exchange system by eliminating its heavily subsidized foreign exchange rate, which was 10 Bolivars per United States dollar, and relaunched an exchange system known as DICOM. The Venezuela government also established a new currency called the “Sovereign Bolivar,” which was determined by the elimination of five zeros from the old currency. The DICOM floating rate was approximately 4,181,782, and 436,677 Bolivars per United States dollar at September 30, 2021 and 2020, respectively. In October 2021, the Venezuelan government launched another monetary overhaul by cutting six zeros from the Bolivar in response to hyperinflation and to simplify accounting. As such, as of September 30, 2022, the DICOM floating rate was approximately eight Bolivars per United States dollar. The DICOM floating rate may not reflect the barter market exchange rates.
NOTE 4 PROPERTY, PLANT AND EQUIPMENT
Property, plant and equipment as of September 30, 2022 and 2021 consisted of the following:
(in thousands) Estimated Useful Lives September 30, 2022 September 30, 2021
Drilling services equipment 4 - 15 years
$ 6,369,888 $ 6,229,011
Tubulars 4 years
569,496 573,900
Real estate properties 10 - 45 years
45,557 43,302
Other 2 - 23 years
422,479 459,741
Construction in progress1
70,119 47,587
7,477,539 7,353,541
Accumulated depreciation (4,516,730) (4,226,254)
Property, plant and equipment, net $ 2,960,809 $ 3,127,287
Assets held-for-sale $ 4,333 $ 71,453
(1)Included in construction in progress are costs for projects in progress to upgrade or refurbish certain rigs in our existing fleet. Additionally, we include other advances for capital maintenance purchase-orders that are open/in process. As these various projects are completed, the costs are then classified to their appropriate useful life category.
Impairments - Fiscal Year 2020
Consistent with our policy, we evaluate our drilling rigs and related equipment for impairment whenever events or changes in circumstances indicate the carrying value of these assets may exceed the estimated undiscounted future net cash flows. Our evaluation, among other things, includes a review of external market factors and an assessment on the future marketability of specific rigs’ asset group.
During the second quarter of fiscal year 2020, several significant economic events took place that severely impacted the current demand on drilling services, including the significant drop in crude oil prices caused by OPEC+'s price war coupled with the decrease in the demand due to the COVID-19 pandemic. To maintain a competitive edge in a challenging market, the Company’s management introduced a new strategy focused on operating various types of highly capable upgraded rigs and phasing out the older, less capable fleet. This resulted in grouping the super-spec rigs of our legacy Domestic FlexRig® 3 asset group and our FlexRig® 5 asset group creating a new "Domestic super-spec FlexRig®" asset group, while combining the legacy Domestic conventional asset group, FlexRig® 4 asset group and FlexRig® 3 non-super-spec rigs into one asset group (Domestic non-super-spec asset group). Given the current and projected low utilization for our Domestic non-super-spec asset group and all International asset groups, we considered these economic factors to be indicators that these asset groups may be impaired.
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As a result of these indicators, we performed impairment testing at March 31, 2020 on each of our Domestic non super-spec and International conventional, FlexRig® 3, and FlexRig® 4 asset groups, which had an aggregate net book value of $605.8 million. We concluded that the net book value of each asset group was not recoverable through estimated undiscounted cash flows and recorded a non-cash impairment charge of $441.4 million in the Consolidated Statement of Operations for the fiscal year ended September 30, 2020. Of the $441.4 million total impairment charge recorded, $292.4 million and $149.0 million was recorded in the North America Solutions and International Solutions segments, respectively. No further impairments were recognized in fiscal year 2020. Impairment was measured as the amount by which the net book value of each asset group exceeded its fair value as of the assessment date.
The most significant assumptions used in our undiscounted cash flow model include timing on awards of future drilling contracts, drilling rig utilization, estimated remaining useful life, and net proceeds received upon future sale/disposition. These assumptions are classified as Level 3 inputs by ASC Topic 820 Fair Value Measurement and Disclosures as they are based upon unobservable inputs and primarily rely on management assumptions and forecasts.
In determining the fair value of each asset group, we utilized a combination of income and market approaches. The significant assumptions in the valuation are based on those of a market participant and are classified as Level 2 and Level 3 inputs by ASC Topic 820 Fair Value Measurement and Disclosures.
As of March 31, 2020, the Company also recorded an additional non-cash impairment charge related to in-progress drilling equipment and rotational inventory of $44.9 million and $38.6 million, respectively, which had aggregate book values of $68.4 million and $38.6 million, respectively, in the Consolidated Statement of Operations for the fiscal year ended September 30, 2020. Of the $83.5 million total impairment charge recorded for in-progress drilling equipment and rotational inventory, $75.8 million and $7.7 million was recorded in the North America Solutions and International Solutions segments, respectively.
Depreciation
Depreciation in the Consolidated Statements of Operations of $396.0 million, $412.5 million and $474.7 million includes abandonments of $6.6 million, $2.0 million and $4.0 million for the fiscal years 2022, 2021 and 2020, respectively.
Assets Held-for-Sale
The following table summarizes the balance (in thousands) of our assets held-for-sale at the dates indicated below:
Balance at September 30, 2020
$ -
Plus:
Asset additions 77,929
Less:
Sale of assets held-for-sale (6,476)
Balance at September 30, 2021
71,453
Plus:
Asset additions 2,580
Less:
Sale of assets held-for-sale (67,592)
Reclassification to assets held and used (2,108)
Balance at September 30, 2022
$ 4,333
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 developed 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 represented their fair value less estimated cost to sell as of the assessment date, and were reclassified as held-for-sale in the second and third quarters 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 fiscal year ended September 30, 2022 and September 30, 2021, we completed the sale of assets with a net book value of $2.6 million and $6.5 million, respectively, that were originally classified as held-for-sale during the second and third quarters of fiscal year 2021.
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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 Company P.J.S.C. ("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 were 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 were delivered to ADNOC Drilling as of September 30, 2021 and, therefore, the total cash proceeds of $86.5 million was recorded in Accrued Liabilities within our Consolidated Balance Sheets as of September 30, 2021.
As of September 30, 2022, ADNOC Drilling accepted delivery of all eight rigs resulting in a gain of $3.1 million, after $27.8 million of selling costs, during the fiscal year ended September 30, 2022. Upon final acceptance of delivery, these rigs were removed from assets classified as held-for-sale as of September 30, 2022. The gain is recorded in Other (Gain) Loss on Sale of Assets within our Consolidated Statement of Operations for the fiscal year ended September 30, 2022. We paid approximately $21.6 million in cash charges attributable to selling costs for the eight rigs during fiscal year 2022.
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 on 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 Statements of Operations during the year ended September 30, 2021. During the fiscal year ended September 30, 2022, we closed on the sale of these assets in two separate transactions. The sale of our trucking services assets was completed on November 3, 2021 while the sale of our casing running services assets was completed on November 15, 2021 for total consideration less costs to sell of $6.0 million, in addition to the possibility of future earnout proceeds, resulting in a loss of $3.4 million during the fiscal year ended September 30, 2022. Losses related to the sale of these assets are recorded in Other (Gain) Loss on Sale of Assets within our Consolidated Statements of Operations. During the year ended September 30, 2022 we recognized $1.1 million in earnout proceeds associated with the sale of our trucking services assets within Other (Gain) Loss on Sale of Assets on the Consolidated Statements of Operations.
During the first quarter of fiscal year 2022, we identified two partial rig substructures that met the asset held-for-sale criteria and were reclassified as Assets Held-for-Sale on our Consolidated Balance Sheets. The combined net book value of the rig substructures of $2.0 million were written down to their estimated scrap value of $0.1 million, resulting in a non-cash impairment charge of $1.9 million within our North America Solutions segment and recorded in the Consolidated Statement of Operations for fiscal year ended September 30, 2022. During the second quarter of fiscal year 2022, we completed the sale of these assets, resulting in no gain or loss as a result of the sale.
During the first quarter of fiscal year 2022, we identified two international FlexRig® drilling rigs located in Colombia that met the asset held-for-sale criteria and were reclassified as Assets Held-for-Sale on our Consolidated Balance Sheets. In conjunction with establishing a plan to sell the two international FlexRig® drilling rigs, we recognized a non-cash impairment charge of $2.5 million within our International Solutions segment and recorded in the Consolidated Statement of Operations during the fiscal year ended September 30, 2022, as the rigs aggregate net book value of $3.4 million exceeded the fair value of the rigs less estimated cost to sell of $0.9 million. During the second quarter of fiscal year ended September 30, 2022, we completed the sale of the two international FlexRig® drilling rigs for total consideration of $0.9 million, resulting in no gain or loss as a result of the sale.
The significant assumptions utilized in the valuations of held-for-sale were based on our intended method of disposal, historical sales of similar assets, and market quotes and are classified as Level 2 and Level 3 inputs by ASC Topic 820, Fair Value Measurement and Disclosures. Although we believe the assumptions used in our analysis are reasonable and appropriate, different assumptions and estimates could materially impact the analysis and our resulting conclusion.
(Gain)/Loss on Sale of Assets
Prior to the fiscal year ended September 30, 2022, Gain on Reimbursement of Drilling Equipment and Other (Gain) Loss on Sale of Assets was presented in the aggregate as Gain (Loss) on Sale of Assets on our Consolidated Statements of Operations. To conform with the current fiscal year presentation, we reclassified amounts previously presented in the Gain (Loss) on Sale of Assets during the years ended September 30, 2021 and 2020, as presented below.
Gain on Reimbursement of Drilling Equipment
We recognized a gain of $29.4 million, $12.3 million, $27.0 million in fiscal years 2022, 2021 and 2020, respectively, related to customer reimbursement for the current replacement value of lost or damaged drill pipe. Gains related to these asset sales are recorded in Gains on Reimbursement of Drilling Equipment within our Consolidated Statements of Operations.
Other (Gain)/Loss on Sale of Assets
We recognized a (gain) loss of $(5.4) million, $11.3 million and $(19.8) million in fiscal years 2022, 2021 and 2020, respectively, related to the sale of rig equipment and other capital assets. These amounts are recorded in Other (Gain) Loss on Sale of Assets within our Consolidated Statements of Operations.
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Fiscal Year 2022 During the first quarter of fiscal year 2022, we closed on the sale of our trucking and casing running assets resulting in a loss of $3.4 million, as mentioned above. We also recognized a gain of $1.1 million in earnout proceeds associated with the sale of our trucking services assets during the fiscal year ended September 30, 2022.
During the same fiscal period, ADNOC Drilling accepted delivery of all eight rigs resulting in an aggregate gain of $3.1 million, as mentioned above. We also recognized a gain of $4.2 million related to the sale of other held-for-sale assets (discussed above) during the fiscal year ended September 30, 2022.
Fiscal Year 2021 During the fiscal year ended September 30, 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. Additionally during the fiscal year ended September 30, 2021, we sold excess drilling equipment and spares, which resulted in a loss of $31.2 million and we also sold assets previously classified as held-for-sale, which resulted in a $3.1 million gain.
Fiscal Year 2020 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 and an aggregate net book value of $13.5 million, resulting in a gain of $27.2 million.
NOTE 5 LEASES
Lease Position
(in thousands) September 30, 2022 September 30, 2021
Operating lease commitments, including probable extensions1
$ 44,769 $ 56,667
Discounted using the lessee's incremental borrowing rate $ 41,002 $ 52,372
(Less): short-term leases recognized on a straight-line basis as expense (1,052) (1,761)
(Less): other (218) (123)
Lease liability recognized $ 39,732 $ 50,488
Of which:
Current lease liabilities $ 12,382 $ 12,624
Non-current lease liabilities 27,350 37,864
(1)Our future minimal rental payments exclude optional extensions that have not been exercised but are probable to be exercised in the future, those probable extensions are included in the operating lease liability balance.
The recognized right-of-use assets relate to the following types of assets:
(in thousands) September 30, 2022 September 30, 2021
Properties $ 38,925 $ 48,176
Equipment 125 935
Other 14 76
Total right-of-use assets $ 39,064 $ 49,187
Lease Costs
The following table presents certain information related to the lease costs for our operating leases:
Year ended September 30,
(in thousands) 2022 2021
Operating lease cost $ 9,687 $ 13,686
Short-term lease cost 1,546 3,580
Total lease cost $ 11,233 $ 17,266
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Lease Terms and Discount Rates
The table below presents certain information related to the weighted average remaining lease terms and weighted average discount rates for our operating leases:.
September 30, 2022 September 30, 2021
Weighted average remaining lease term 5.9 6.7
Weighted average discount rate 2.5 % 2.5 %
Lease Obligations
Future minimum rental payments required under operating leases having initial or remaining non-cancelable lease terms in excess of one year at September 30, 2022 (in thousands) are as follows:
Fiscal Year Amount
2023 $ 9,767
2024 7,801
2025 4,501
2026 2,033
2027 2,046
Thereafter 5,465
Total1
$ 31,613
(1)Our future minimal rental payments exclude optional extensions that have not been exercised but are probable to be exercised in the future, those probable extensions are included in the operating lease liability balance.
Total rent expense was $11.2 million, $17.3 million and $18.6 million for the fiscal years ended September 30, 2022, 2021 and 2020, respectively. The future minimum lease payments for our Tulsa corporate office and our Tulsa industrial facility represent a material portion of the amounts shown in the table above. The lease agreement for our Tulsa corporate office commenced on May 30, 2003 and has subsequently been amended, most recently on April 1, 2021. The agreement will expire on January 31, 2025; however, we have two five-year renewal options, which were not recognized as part of our right-of-use assets and lease liabilities. The lease agreement for our Tulsa industrial facility, where we perform maintenance and assembly of FlexRig® components commenced on December 21, 2018 and will expire on June 30, 2025; however, we have two two-year renewal options which were recognized as part of our right-of-use assets and lease liabilities.
During the fiscal year ended September 30, 2021, we downsized and relocated our Houston assembly facility to a new location. Refer to Note 18-Restructuring Charges for additional details. As a result, and during fiscal year 2021, we entered into a lease agreement for a new assembly facility located in Galena Park, Texas. This lease agreement commenced on January 1, 2021 and will expire on December 31, 2030; however, we have one unpriced renewal option for a minimum of five years and a maximum of 10 years, which was not recognized as part of our right-of-use assets and lease liabilities. This contract is accounted for as an operating lease resulting in an operating lease right-of-use asset of $12.2 million and $16.0 million, and minimum lease liability of $12.5 million and $16.2 million, as of September 30, 2022 and 2021, respectively.
NOTE 6 GOODWILL AND INTANGIBLE ASSETS
Goodwill
Goodwill represents the excess of the purchase price over the fair values of the assets acquired and liabilities assumed in a business combination, at the date of acquisition. Goodwill is not amortized but is tested for potential impairment at the reporting unit level, at a minimum on an annual basis in the fourth fiscal quarter, or when indications of potential impairment exist. All of our goodwill is within our North America Solutions reportable segment.
During the fiscal years ended September 30, 2022 and 2021, we had no additions or impairments to goodwill. As of September 30, 2022 and September 30, 2021, the goodwill balance was $45.7 million.
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Intangible Assets
Finite-lived intangible assets are amortized using the straight-line method over the period in which these assets contribute to our cash flows and are evaluated for impairment in accordance with our policies for valuation of long-lived assets. All of our intangible assets are within our North America Solutions reportable segment. Intangible assets consisted of the following:
September 30, 2022 September 30, 2021
(in thousands) Weighted Average Estimated Useful Lives Gross Carrying Amount Accumulated Amortization Net Gross Carrying Amount Accumulated Amortization Net
Finite-lived intangible asset:
Developed technology 15 years $ 89,096 $ 28,137 $ 60,959 $ 89,096 $ 22,182 $ 66,914
Intellectual property 13 years 2,000 328 1,672 1,500 216 1,284
Trade name 20 years 5,865 1,475 4,390 5,865 1,158 4,707
Customer relationships 5 years 4,000 3,867 133 4,000 3,067 933
$ 100,961 $ 33,807 $ 67,154 $ 100,461 $ 26,623 $ 73,838
Amortization expense in the Consolidated Statements of Operations was $7.2 million for fiscal years 2022, 2021 and 2020, and is estimated to be $6.6 million for fiscal year 2023, and approximately $6.4 million for fiscal year 2024 through 2027.
Impairment - Fiscal Year 2020
Due to the market conditions described in Note 4-Property, Plant and Equipment, during the second quarter of fiscal year 2020, we concluded that goodwill and intangible assets might be impaired and tested the H&P Technologies reporting unit, where the goodwill balance is allocated and the intangible assets are recorded, for recoverability. This resulted in a goodwill only non-cash impairment charge of $38.3 million recorded in the Consolidated Statement of Operations during the fiscal year ended September 30, 2020.
The recoverable amount of the H&P Technologies reporting unit was determined based on a fair value calculation which uses cash flow projections based on the Company's financial projections presented to the Board covering a five-year period, and a discount rate of 14.0 percent. Cash flows beyond that five-year period were extrapolated using the fifth-year data with no implied growth factor. The reporting unit level is defined as an operating segment or one level below an operating segment.
The recoverable amount of the intangible assets tested for impairment within the H&P Technologies reporting unit is determined based on undiscounted cash flow projections using the Company's financial projections presented to the Board covering a five-year period and extrapolated for the remaining weighted average useful lives of the intangible assets.
The most significant assumptions used in our cash flow model include timing of awarded future contracts, commercial pricing terms, utilization, discount rate, and the terminal value. These assumptions are classified as Level 3 inputs by ASC Topic 820 Fair Value Measurement and Disclosures as they are based upon unobservable inputs and primarily rely on management assumptions and forecasts. Although we believe the assumptions used in our analysis and the probability-weighted average of expected future cash flows are reasonable and appropriate, different assumptions and estimates could materially impact the analysis and our resulting conclusion.
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NOTE 7 DEBT
We had the following unsecured long-term debt outstanding with maturities shown in the following table:
September 30, 2022 September 30, 2021
(in thousands) Face Amount Unamortized Discount and Debt Issuance Cost Book Value Face Amount Unamortized Discount and Debt Issuance Cost Book Value
Unsecured senior notes:
Due March 19, 20251
$ - $ - $ - $ 487,148 $ (3,662) $ 483,486
Due September 29, 2031 550,000 (7,390) 542,610 550,000 (8,003) 541,997
550,000 (7,390) 542,610 1,037,148 (11,665) 1,025,483
Less: long-term debt due within one year $ - - - (487,148) 3,662 (483,486)
Long-term debt $ 550,000 $ (7,390) $ 542,610 $ 550,000 $ (8,003) $ 541,997
(1)Debt was extinguished prior to maturity date. Refer to 'Senior Notes' section below.
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 per annum.
The indenture governing the 2031 Notes 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 indenture governing the 2031 Notes 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. The debt issuance cost was 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. As a result, the associated make-whole premium of $56.4 million and the write off of the unamortized discount and debt issuance costs of $3.7 million were recognized during the first fiscal quarter of 2022 contemporaneously with the October 27, 2021 debt extinguishment and recorded in Loss on Extinguishment of Debt on our Consolidated Statements of Operations during the fiscal year ended September 30, 2022.
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. Additionally, on March 8, 2022, we entered into the second amendment to the 2018 Credit Facility, which, among other things, raised the number of potential future extensions of the maturity date applicable to extending lenders from one to two such potential extensions and replaced provisions in respect of interest rate determinations that were based on the London Interbank Offered Rate with provisions based on the Secured Overnight Financing Rate. Lenders with $680.0 million of commitments under the 2018 Credit Facility also exercised their option to extend the maturity of the 2018 Credit Facility from November 12, 2025 to November 11, 2026. 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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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. In March 2022, the 2018 Credit Facility was amended to change the benchmark rate from the London Interbank Offered Rate ("LIBOR") to the Secured Overnight Financing Rate ("SOFR"). Following the amendment, we can elect to borrow at either an adjusted SOFR rate or an adjusted base rate, plus an applicable margin. The adjusted SOFR rate is the forward-looking term rate based on SOFR for the applicable tenor of one, three, or six months, plus 0.10 percent per annum. The adjusted base rate is a fluctuating rate per annum equal to the highest of (i) the administrative agent's prime rate, (ii) the federal funds effective rate plus 0.50 percent, or (iii) the one-month adjusted SOFR rate plus 1.0 percent. 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 applicable margin for SOFR borrowings and adjusted base rate borrowings ranges from 0.875 percent to 1.500 percent per annum and zero to 0.50 percent per annum, respectively. Commitment fees for both rates range from 0.075 percent to 0.200 percent per annum. Based on the unsecured debt rating of the Company on September 30, 2022, the spread over SOFR would have been 1.125 percent had borrowings been outstanding under the 2018 Credit Facility and commitment fees would have been 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, 2022, 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, 2022, we had $55.0 million in uncommitted bilateral credit facilities, for the purpose of obtaining the issuance of international letters of credit, bank guarantees, and performance bonds. Of the $55.0 million, $38.1 million of financial guarantees were outstanding as of September 30, 2022. Separately, we had $2.0 million in standby letters of credit and bank guarantees outstanding. In total, we had $40.1 million outstanding as of September 30, 2022. In October 2022, we increased one of our standby letters of credit by $1.9 million.
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, 2022, we were in compliance with all debt covenants.
At September 30, 2022, aggregate maturities of long-term debt are as follows (in thousands):
Year ending September 30,
2023 $ -
2024 -
2025 -
2026 -
2027 -
Thereafter - Due 2031 550,000
$ 550,000
NOTE 8 INCOME TAXES
Income Tax (Benefit) Provision and Rate
The components of the provision (benefit) for income taxes are as follows:
Year Ended September 30,
(in thousands) 2022 2021 2020
Current:
Federal $ 40,245 $ (15,466) $ 15,431
Foreign 10,703 772 1,495
State 1,906 725 523
52,854 (13,969) 17,449
Deferred:
Federal (32,382) (81,760) (127,096)
Foreign (1,310) 4,106 (12,390)
State 5,204 (12,098) (18,069)
(28,488) (89,752) (157,555)
Total provision (benefit) $ 24,366 $ (103,721) $ (140,106)
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The amounts of domestic and foreign income (loss) before income taxes are as follows:
Year Ended September 30,
(in thousands) 2022 2021 2020
Domestic $ (14,411) $ (412,556) $ (458,364)
Foreign 45,329 (28,624) (178,134)
$ 30,918 $ (441,180) $ (636,498)
The reconciliation of our effective income tax rates to the U.S. Federal income tax rate is as follows:
Year Ended September 30,
2022 2021 2020
U.S. Federal income tax rate 21.0 % 21.0 % 21.0 %
Effect of foreign taxes 31.7 0.1 (0.2)
State income taxes, net of federal tax benefit 21.7 2.6 2.8
Other impact of foreign operations 3.5 - (0.5)
Non-deductible meals and entertainment 1.0 (0.1) (0.2)
Equity compensation 9.6 (0.8) (0.3)
Excess officer's compensation 3.8 - (0.2)
Foreign derived intangible income (13.8) - -
Other 0.3 0.7 (0.4)
Effective income tax rate 78.8 % 23.5 % 22.0 %
Effective tax rates differ from the U.S. federal statutory rate of 21.0 percent due to state and foreign income taxes and the tax effect of non-deductible expenditures.
Deferred Taxes
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 valuation allowances are provided. The carrying value of the net deferred tax assets is 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.
The components of our net deferred tax liabilities are as follows:
September 30,
(in thousands) 2022 2021
Deferred tax liabilities:
Property, plant and equipment $ 558,293 $ 598,798
Marketable securities 9,766 1,669
Other 24,460 26,244
Total deferred tax liabilities 592,519 626,711
Deferred tax assets:
Pension reserves 4,811 5,791
Self-insurance reserves 7,333 7,862
Net operating loss, foreign tax credit, and other federal tax credit carryforwards 8,673 25,474
Financial accruals 31,022 31,910
Other 13,678 17,963
Total deferred tax assets 65,517 89,000
Valuation allowance (10,710) (25,726)
Net deferred tax assets 54,807 63,274
Net deferred tax liabilities $ 537,712 $ 563,437
The change in our net deferred tax assets and liabilities is impacted by foreign currency remeasurement.
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As of September 30, 2022, we had federal, state and foreign tax net operating loss carryforwards of approximately $4.5 million, $45.7 million and $14.3 million, respectively, federal and foreign research and development tax credits of approximately $0.4 million and $0.5 million, respectively, and foreign tax credit carryforwards of approximately $0.9 million which will expire in fiscal 2023 through 2042 and some of which can be carried forward indefinitely. Certain of these carryforwards are subject to various rules which impose limitations on their utilization. The valuation allowance is primarily attributable to foreign net operating loss carryforwards of $3.1 million, foreign tax credit carryforwards of $0.9 million, and equity compensation of $6.8 million which more likely than not will not be utilized.
Unrecognized Tax Benefits
We recognize accrued interest related to unrecognized tax benefits in interest expense, and penalties in other expense in the Consolidated Statements of Operations. As of September 30, 2022, 2021 and 2020, we had accrued interest and penalties of $3.0 million, $2.9 million and $2.8 million, respectively. A reconciliation of the change in our gross unrecognized tax benefits are as follows:
(in thousands) 2022 2021 2020
Unrecognized tax benefits at October 1, $ 1,678 $ 13,440 $ 15,759
Gross decreases - current period effect of tax positions (718) (11,648) (2,338)
Gross increases - current period effect of tax positions - - 20
Expiration of statute of limitations for assessments - (114) (1)
Unrecognized tax benefits at September 30, $ 960 $ 1,678 $ 13,440
As of September 30, 2022, 2021 and 2020, our liability for unrecognized tax benefits includes $0.7 million and $1.4 million and $13.0 million, respectively, of unrecognized tax benefits related to discontinued operations that, if recognized, would not affect the effective tax rate. The remaining unrecognized tax benefits would affect the effective tax rate if recognized. The liabilities for unrecognized tax benefits and related interest and penalties are included in other noncurrent liabilities in our Consolidated Balance Sheets.
For the next 12 months, we cannot predict with certainty whether we will achieve ultimate resolution of any uncertain tax position associated with our U.S. and international operations that could result in increases or decreases of our unrecognized tax benefits. However, we do not expect any such increases or decreases to have a material effect on our results of operations or financial position.
Tax Returns
We file a consolidated U.S. federal income tax return, as well as income tax returns in various states and foreign jurisdictions. The tax years that remain open to examination by U.S. federal and state jurisdictions include fiscal years 2018 through 2021, with exception of certain state jurisdictions currently under audit. The tax years remaining open to examination by foreign jurisdictions include 2003 through 2021.
NOTE 9 SHAREHOLDERS’ EQUITY
The Company has 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. During the fiscal year ended September 30, 2022 and 2020, we repurchased 3.2 million common shares at an aggregate cost of $77.0 million and 1.5 million common shares at an aggregate cost of $28.5 million, respectively, which are held as treasury shares. There were no repurchases of common shares during the fiscal year ended September 30, 2021.
During the year ended September 30, 2022, we declared $106.8 million in cash dividends. A cash dividend of $0.25 per share was declared on September 7, 2022 for shareholders of record on November 15, 2022, payable on December 1, 2022. As a result, we recorded a Dividend Payable of $26.7 million on our Consolidated Balance Sheets as of September 30, 2022.
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Accumulated Other Comprehensive Loss
Components of accumulated other comprehensive loss were as follows:
September 30,
(in thousands) 2022 2021 2020
Pre-tax amounts:
Unrealized actuarial loss (15,703) (26,268) (33,923)
$ (15,703) $ (26,268) $ (33,923)
After-tax amounts:
Unrealized actuarial loss (12,072) (20,244) (26,188)
$ (12,072) $ (20,244) $ (26,188)
The following is a summary of the changes in accumulated other comprehensive loss, net of tax, by component for the fiscal year ended September 30, 2022:
(in thousands) Defined Benefit Pension Plan
Balance at September 30, 2021 $ (20,244)
Activity during the period
Amounts reclassified from accumulated other comprehensive loss 8,172
Net current-period other comprehensive income 8,172
Balance at September 30, 2022
$ (12,072)
NOTE 10 REVENUE FROM CONTRACTS WITH CUSTOMERS
Drilling Services Revenue
The majority of our drilling services are performed on a “daywork” contract basis, 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. These drilling services, including our technology solutions, represent a series of distinct daily services that are substantially the same, with the same pattern of transfer to the customer. Because our customers benefit equally throughout the service period and our efforts in providing drilling services are incurred relatively evenly over the period of performance, revenue is recognized over time using a time-based input measure as we provide services to the customer. For any contracts that include a provision for pooled term days at contract inception, followed by the assignment of days to specific rigs throughout the contract term, we have elected, as a practical expedient, to recognize revenue in the amount to which the entity has a right to invoice, as permitted by ASC 606.
Contracts generally contain renewal or extension provisions exercisable at the option of the customer at prices mutually agreeable to us and the customer. For contracts that are terminated by customers prior to the expirations of their fixed terms, contractual provisions customarily require early termination amounts to be paid to us. Revenues from early terminated contracts are recognized when all contractual requirements have been met. During the fiscal years ended September 30, 2022, 2021 and 2020, early termination revenue associated with term contracts was approximately $0.7 million, $7.7 million and $73.4 million, respectively.
We also act as a principal for certain reimbursable services and auxiliary equipment provided by us to our clients, for which we incur costs and earn revenues. Many of these costs are variable, or dependent upon the activity that is performed each day under the related contract. Accordingly, reimbursements that we receive for out-of-pocket expenses are recorded as revenues and the out-of-pocket expenses for which they relate are recorded as operating costs during the period to which they relate within the series of distinct time increments. All of our revenues are recognized net of sales taxes, when applicable.
With most drilling contracts, we also receive payments contractually designated for the mobilization and demobilization of drilling rigs and other equipment to and from the client’s drill site. Revenue associated with the mobilization and demobilization of our drilling rigs to and from the client’s drill site do not relate to a distinct good or service. These revenues are deferred and recognized on a straight-line basis over the related contract term that drilling services are provided.
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Demobilization fees expected to be received upon contract completion are estimated at contract inception and recognized on a straight-line basis over the contract term. The amount of demobilization revenue that we ultimately collect is dependent upon the specific contractual terms, most of which include provisions for reduced or no payment for demobilization when, among other things, the contract is renewed or extended with the same client, or when the rig is subsequently contracted with another client prior to the termination of the current contract. Since revenues associated with demobilization activity are typically variable, at each period end, they are estimated at the most likely amount, and constrained when the likelihood of a significant reversal is probable. Any change in the expected amount of demobilization revenue is accounted for with the net cumulative impact of the change in estimate recognized in the period during which the revenue estimate is revised.
On November 12, 2021, we settled a drilling contract dispute related to drilling services provided from fiscal years 2016 through 2019 with YPF S.A. (Argentina) ("YPF"). The settlement required that YPF make a one-time cash payment to H&P in the amount of $11.0 million and enter into drilling service contracts for three drilling rigs, each with multi-year terms. In addition, both parties were released of all outstanding claims against each other, and as a result, H&P recognized $5.4 million in revenue primarily due to accrued contingent liabilities for disputed amounts. Total revenue recognized as a result of the settlement in the amount of $16.4 million is included in Drilling Services Revenue within the International Solutions segment on our Consolidated Statements of Operations for the fiscal year ended September 30, 2022.
Contract Costs
Mobilization costs include certain direct costs incurred for mobilization of contracted rigs. These costs relate directly to a contract, enhance resources that will be used in satisfying the future performance obligations, and are expected to be recovered. These costs are capitalized when incurred and recorded as current or noncurrent contract fulfillment cost assets (depending on the length of the initial contract term), and are amortized on a systematic basis consistent with the pattern of the transfer of the goods or services to which the asset relates which typically includes the initial term of the related drilling contract or a period longer than the initial contract term if management anticipates a customer will renew or extend a contract, which we expect to benefit from the cost of mobilizing the rig. Abnormal mobilization costs are fulfillment costs that are incurred from excessive resources, wasted or spoiled materials, and unproductive labor costs that are not otherwise anticipated in the contract price and are expensed as incurred. As of September 30, 2022 and 2021, we capitalized fulfillment costs of $6.3 million and $4.3 million respectively, which is included within Prepaid Expenses and Other Assets on our Consolidated Balance Sheets.
If capital modification costs are incurred for rig modifications or if upgrades are required for a contract, these costs are considered to be capital improvements. These costs are capitalized as property, plant and equipment and depreciated over the estimated useful life of the improvement.
Remaining Performance Obligations
The total aggregate transaction price allocated to the unsatisfied performance obligations, commonly referred to as backlog, as of September 30, 2022 was approximately $1.2 billion, of which $0.8 billion is expected to be recognized during fiscal year 2023, and approximately $0.4 billion in fiscal year 2024 and thereafter. These amounts do not include anticipated contract renewals. Additionally, contracts that currently contain month-to-month terms are represented in our backlog as one month of unsatisfied performance obligations. Our contracts are subject to cancellation or modification at the election of the customer; however, due to the level of capital deployed by our customers on underlying projects, we have not been materially adversely affected by contract cancellations or modifications in the past.
Contract Assets and Liabilities
Amounts owed from our customers under our revenue contracts are typically billed on a monthly basis as the service is being provided and are due within 30 days of billing. Such amounts are classified as accounts receivable on our Consolidated Balance Sheets. Under certain of our contracts, we recognize revenues in excess of billings, referred to as contract assets, within Prepaid expenses and Other current assets within our Consolidated Balance Sheets.
In some instances, we may be entitled to receive payments in advance of satisfying our performance obligations under the contract. We recognize a liability for these payments in excess of revenue recognized, referred to as deferred revenue or contract liabilities, within Accrued liabilities and Other noncurrent liabilities in our Consolidated Balance Sheets. Contract balances are presented at the net amount at a contract level.
The following table summarizes the balances of our contract assets (net of allowance for estimated credit losses) and liabilities at the dates indicated:
(in thousands) September 30, 2022 September 30, 2021
Contract assets, net $ 6,319 $ 4,513
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(in thousands) September 30, 2022
Contract liabilities balance at October 1, 2020 $ 8,636
Payment received/accrued and deferred 30,721
Revenue recognized during the period (30,071)
Contract liabilities balance at September 30, 2021 9,286
Payment received/accrued and deferred 58,202
Revenue recognized during the period (46,842)
Contract liabilities balance at September 30, 2022 $ 20,646
NOTE 11 STOCK-BASED COMPENSATION
On March 3, 2020, the Helmerich & Payne, Inc. 2020 Omnibus Incentive Plan (the “2020 Plan”) was approved by our stockholders. The 2020 Plan is a stock and cash-based incentive plan that, among other things, authorizes the Board or Human Resources Committee of the Board to grant executive officers, employees and non-employee directors stock options, stock appreciation rights, restricted shares and restricted share units (including performance share units), share bonuses, other share-based awards and cash awards. Restricted stock may be granted for no consideration other than prior and future services. The purchase price per share for stock options may not be less than market price of the underlying stock on the date of grant. Stock options expire ten years after the grant date. Awards outstanding under the Helmerich & Payne, Inc. 2010 Long-Term Incentive Plan and the Helmerich & Payne, Inc. 2016 Omnibus Incentive Plan (the "2016 Plan") remain subject to the terms and conditions of those plans. Beginning with fiscal year 2019, we replaced stock options with performance share units as a component of our executives' long-term equity incentive compensation. As a result, there were no stock options granted during the fiscal years ended September 30, 2022, 2021, and 2020. We have also eliminated stock options as an element of our non-employee director compensation program. At September 30, 2022, we had 2.4 million outstanding exercisable stock options with weighted-average exercise prices of $63.90.
During the fiscal year ended September 30, 2022, 743,920 shares of restricted stock awards and 227,385 performance share units were granted under the 2020 Plan.
A summary of compensation cost for stock-based payment arrangements recognized in Drilling Services Operating Expense, Research and Development Expense and Selling, General and Administrative Expense on our Consolidated Statements of Operations, in fiscal years 2022, 2021 and 2020 is as follows:
September 30,
(in thousands) 2022 2021 2020
Stock-based compensation expense
Drilling services operating $ 5,142 $ 5,927 $ 9,086
Research and development 1,551 1,271 765
Selling, general and administrative 21,339 20,660 29,960
Restructuring charges1
- - (3,482)
$ 28,032 $ 27,858 $ 36,329
.
(1)These restructuring charges are specific to the stock-based compensation benefit which resulted from the recognition of forfeitures in fiscal year 2020. Refer to Note 18-Restructuring Charges to our Consolidated Financial Statements for details.
Restricted Stock
Restricted stock awards consist of our common stock. Awards granted prior to September 30, 2020 are time-vested over four years, and awards granted after September 30, 2020 are time vested over three years. Non-forfeitable dividends are paid on non-vested shares of restricted stock. We recognize compensation expense on a straight-line basis over the vesting period. The fair value of restricted stock awards is determined based on the closing price of our shares on the grant date. As of September 30, 2022, there was $24.8 million of total unrecognized compensation cost related to unvested restricted stock awards. That cost is expected to be recognized over a weighted-average period of 1.7 years.
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A summary of the status of our restricted stock awards as of September 30, 2022, and of changes in restricted stock outstanding during the fiscal years ended September 30, 2022, 2021 and 2020, is as follows:
2022 2021 2020
(shares in thousands) Shares1
Weighted-Average Grant Date Fair Value per Share Shares1
Weighted-Average Grant Date Fair Value per Share Shares1
Weighted-Average Grant Date Fair Value per Share
Non-vested restricted stock outstanding at October 1, 1,412 $ 37.36 1,280 $ 49.81 1,085 $ 61.28
Granted 744 25.83 701 25.61 781 39.99
Vested2
(610) 39.81 (534) 51.79 (501) 59.46
Forfeited (53) 30.98 (35) 35.76 (85) 48.98
Non-vested restricted stock outstanding at September 30, 1,493 $ 30.85 1,412 $ 37.36 1,280 $ 49.81
(1)Restricted stock shares include restricted phantom stock units under our Director Deferred Compensation Plan. These phantom stock units confer the economic benefits of owning company stock without the actual ownership, transfer or issuance of any shares. Phantom stock units are subject to a vesting period of one year from the grant date. During the fiscal years ended September 30, 2022, 2021, and 2020, 14,199, 18,906, and 20,616 restricted phantom stock units were granted, respectively. During the fiscal years ended September 30, 2022, and 2021, 18,906 and 20,616 restricted phantom stock units vested during the period, respectively. There were no restricted phantom stock units that vested during fiscal year 2020, as it was the first year that restricted phantom stock units were granted.
(2)The number of restricted stock awards vested includes shares that we withheld on behalf of our employees to satisfy the statutory tax withholding requirements.
Performance Units
We have made awards to certain employees that are subject to market-based performance conditions ("performance units"). Subject to the terms and conditions set forth in the applicable performance share unit award agreements and the 2020 Plan, grants of performance units are subject to a vesting period of three years (the “Vesting Period”) that is dependent on the achievement of certain performance goals. Such performance unit grants consist of two separate components. Performance units that comprise the first component are subject to a three-year performance cycle. Performance units that comprise the second component are further divided into three separate tranches, each of which is subject to a separate one-year performance cycle within the full three-year performance cycle. The vesting of the performance units is generally dependent on (i) the achievement of the Company’s total shareholder return (“TSR”) performance goals relative to the TSR achievement of a peer group of companies (the “Peer Group”) over the applicable performance cycle, and (ii) the continued employment of the recipient of the performance unit award throughout the Vesting Period. The Vesting Period for performance units granted in December 2018 ended on December 31, 2021 and the performance units earned were settled in shares of common stock during the second quarter of fiscal year 2022.
At the end of the Vesting Period, recipients receive dividend equivalents, if any, with respect to the number of vested performance units. The vesting of units ranges from zero to 200 percent of the units granted depending on the Company’s TSR relative to the TSR of the Peer Group on the vesting date.
The grant date fair value of performance units was determined through use of the Monte Carlo simulation method. The Monte Carlo simulation method requires the use of highly subjective assumptions. Our key assumptions in the method include the price and the expected volatility of our stock and our self-determined Peer Group companies' stock, risk free rate of return and cross-correlations between the Company and our Peer Group companies. The valuation model assumes dividends are immediately reinvested. As of September 30, 2022, there was $8.9 million of unrecognized compensation cost related to unvested performance units. That cost is expected to be recognized over a weighted-average period of 1.8 years.
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A summary of the status of our performance units as of September 30, 2022, 2021 and 2020 and changes in non-vested performance units outstanding during the fiscal years ended September 30, 2022, 2021 and 2020 is presented below:
2022 2021 2020
(in thousands, except per share amounts) Shares Weighted-Average Grant Date Fair Value per Share Shares Weighted-Average Grant Date Fair Value per Share Shares Weighted-Average Grant Date Fair Value per Share
Non-vested performance units outstanding at October 1, 699 $ 41.55 337 $ 51.09 145 $ 62.66
Granted 227 30.12 313 29.77 259 43.40
Vested 1
(161) 62.66 - - - -
Dividend rights performance units credited 15 32.82 60 49.64 - -
Forfeited (54) 34.16 (11) 43.40 (67) 46.35
Non-vested performance units outstanding September 30,2
726 $ 33.67 699 $ 41.55 $ 337 $ 51.09
(1)The number of performance units vested includes units that we withheld on behalf of our employees to satisfy the statutory tax withholding requirements.
(2)Of the total non-vested performance units at the end of the period, specified performance criteria has been achieved with respect to 96,819 performance units which is calculated based on the payout percentage for the completed performance period. The vesting and number of the remainder of non-vested performance units reflected at the end of the period is contingent upon our achievement of specified target performance criteria. If we meet the specified maximum performance criteria, approximately 1,145,726 additional performance units could vest or become eligible to vest.
The weighted-average fair value calculations for performance units granted within the fiscal period are based on the following weighted-average assumptions set forth in the table below.
2022 2021 2020
Risk-free interest rate1
1.0 % 0.2 % 1.6 %
Expected stock volatility2
67.3 % 62.3 % 34.8 %
Expected term (in years) 3 3 3
(1)The risk-free interest rate is based on U.S. Treasury securities for the expected term of the performance units.
(2)Expected volatilities are based on the daily closing price of our stock based upon historical experience over a period which approximates the expected term of the performance units.
NOTE 12 EARNINGS (LOSS) PER COMMON SHARE
ASC 260, Earnings per Share, requires companies to treat unvested share-based payment awards that have non-forfeitable rights to dividends or dividend equivalents as a separate class of securities in calculating earnings per share. We have granted and expect to continue to grant to employees restricted stock grants that contain non-forfeitable rights to dividends. Such grants are considered participating securities under ASC 260. As such, we are required to include these grants in the calculation of our basic earnings per share and calculate basic earnings per share using the two-class method. The two-class method of computing earnings per share is an earnings allocation formula that determines earnings per share for each class of common stock and participating security according to dividends declared (or accumulated) and participation rights in undistributed earnings.
Basic earnings per share is computed utilizing the two-class method and is calculated based on the weighted-average number of common shares outstanding during the periods presented.
Diluted earnings per share is computed using the weighted-average number of common and common equivalent shares outstanding during the periods utilizing the two-class method for stock options, non-vested restricted stock and performance units.
Under the two-class method of calculating earnings per share, dividends paid and a portion of undistributed net income, but not losses, are allocated to unvested restricted stock grants that receive dividends, which are considered participating securities.
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The following table sets forth the computation of basic and diluted earnings (loss) per share:
September 30,
(in thousands, except per share amounts) 2022 2021 2020
Numerator:
Income (loss) from continuing operations $ 6,552 $ (337,459) $ (496,392)
Income from discontinued operations 401 11,309 1,895
Net income (loss) 6,953 (326,150) (494,497)
Adjustment for basic earnings (loss) per share
Losses allocated to unvested shareholders (1,508) (1,350) (2,647)
Numerator for basic earnings (loss) per share:
From continuing operations 5,044 (338,809) (499,039)
From discontinued operations 401 11,309 1,895
5,445 (327,500) (497,144)
Numerator for diluted earnings (loss) per share:
From continuing operations 5,044 (338,809) (499,039)
From discontinued operations 401 11,309 1,895
$ 5,445 $ (327,500) $ (497,144)
Denominator:
Denominator for basic earnings (loss) per share - weighted-average shares 105,891 107,818 108,009
Effect of dilutive shares from stock options, restricted stock and performance share units 664 - -
Denominator for diluted earnings (loss) per share - adjusted weighted-average shares 106,555 107,818 108,009
Basic earnings (loss) per common share:
Income (loss) from continuing operations $ 0.05 $ (3.14) $ (4.62)
Income from discontinued operations - 0.10 0.02
Net income (loss) $ 0.05 $ (3.04) $ (4.60)
Diluted earnings (loss) per common share:
Income (loss) from continuing operations $ 0.05 $ (3.14) $ (4.62)
Income from discontinued operations - 0.10 0.02
Net income (loss) $ 0.05 $ (3.04) $ (4.60)
We had a net loss for fiscal years 2021 and 2020. Accordingly, our diluted earnings per share calculation for those years were equivalent to our basic earnings per share calculation since diluted earnings per share excluded any assumed exercise of equity awards. These were excluded because they were deemed to be anti-dilutive, meaning their inclusion would have reduced the reported net loss per share in the applicable period.
The following potentially dilutive average shares attributable to outstanding equity awards were excluded from the calculation of diluted earnings (loss) per share because their inclusion would have been anti-dilutive:
(in thousands, except per share amounts) 2022 2021 2020
Potentially dilutive shares excluded as anti-dilutive 2,543 3,894 4,004
Weighted-average price per share $ 62.36 $ 57.23 $ 60.72
NOTE 13 FAIR VALUE MEASUREMENT OF FINANCIAL INSTRUMENTS
We have certain assets and liabilities that are required to be measured and disclosed at fair value. Fair value is defined as the exchange price that would be received to sell an asset or paid to transfer a liability (an exit price) in the principal or most advantageous market for the asset or liability in an orderly transaction between market participants at the measurement date. We use the fair value hierarchy established in ASC 820-10 to measure fair value to prioritize the inputs:
•Level 1 - Quoted prices (unadjusted) in active markets for identical assets or liabilities that the reporting entity can access at the measurement date.
•Level 2 - Observable inputs, other than quoted prices included in Level 1, such as quoted prices for similar assets or liabilities in active markets; quoted prices for similar assets and liabilities in markets that are not active; or other inputs that are observable or can be corroborated by observable market data.
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•Level 3 - Unobservable inputs that are supported by little or no market activity and that are significant to the fair value of the assets or liabilities. This includes pricing models, discounted cash flow methodologies and similar techniques that use significant unobservable inputs.
The Company's assessment of the significance of a particular input to the fair value measurement in its entirety requires judgment and considers factors specific to the asset or liability.
Recurring Fair Value Measurements
The following tables summarize our financial assets and liabilities measured at fair value on a recurring basis and indicate the level in the fair value hierarchy in which we classify the fair value measurement.
September 30, 2022
(in thousands) Fair Value Level 1 Level 2 Level 3
Assets
Short-term investments:
Corporate debt securities $ 98,264 - 98,264 -
U.S. government and federal agency securities 18,837 18,837 - -
Total short-term investments 117,101 18,837 98,264 -
Investments:
Non-qualified supplemental savings plan 14,301 14,301 - -
Equity investment in ADNOC Drilling 147,370 147,370 - -
Debt security investment in Galileo 33,000 - - 33,000
Other debt securities 565 - - 565
Total investments 195,236 161,671 - 33,565
Liabilities
Contingent consideration $ 4,022 $ - $ - $ 4,022
September 30, 2021
(in thousands) Fair Value Level 1 Level 2 Level 3
Assets
Short-term investments:
Corporate debt securities $ 192,950 $ - $ 192,950 $ -
U.S. government and federal agency securities 5,750 5,750 - -
Total short-term investments 198,700 5,750 192,950 -
Investments:
Non-qualified supplemental savings plan 18,221 18,221 - -
Equity and debt securities 14,358 13,858 - 500
Cornerstone investment in ADNOC Drilling 100,000 100,000 - -
Total investments 132,579 132,079 - 500
Liabilities
Contingent consideration $ 2,996 $ - $ - $ 2,996
Short-term Investments Short-term investments primarily include securities classified as trading securities. Both realized and unrealized gains and losses on trading securities are included in other income (expense) in the Consolidated Statements of Operations. These securities are recorded at fair value. Level 1 inputs include U.S. agency issued debt securities with active markets and money market funds. For these items, quoted current market prices are readily available. Level 2 inputs include corporate bonds measured using broker quotations that utilize observable market inputs.
Long-term Investments Our long-term investments include debt and equity securities and assets held in a Non-Qualified Supplemental Savings Plan ("Savings Plan") and are recorded within Investments on our Consolidated Balance Sheets. Our assets that we hold in the Savings Plan are comprised of mutual funds that are measured using Level 1 inputs.
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During September 2021, the Company made a $100.0 million cornerstone investment in ADNOC Drilling in advance of its announced IPO, representing 159.7 million shares of ADNOC Drilling, equivalent to a one percent ownership stake and subject to a three-year lockup period. ADNOC Drilling’s IPO was completed on October 3, 2021, and its shares are listed and traded on the Abu Dhabi Securities Exchange. Our investment is classified as a long-term equity investment within Investments in our Consolidated Balance Sheets. We have applied the guidance in Topic 820, Fair Value Measurement, in the initial accounting of the transaction and the subsequent revaluation of the investment balance, concluding that the contractual restriction on the sale of an equity security that is publicly traded is not considered in measuring fair value. During the fiscal year ended September 30, 2022, we recognized a gain of $47.4 million on our Consolidated Statements of Operations, as a result of the change in fair value of the investment during the period. As of September 30, 2022, this investment is classified as a Level 1 investment based on the quoted stock price on the Abu Dhabi Securities Exchange.
During the fiscal year ended September 30, 2022, the Company made a $33.0 million cornerstone investment in Galileo Holdco 2 Limited Technologies ("Galileo Holdco 2"), part of the group of companies known as Galileo Technologies (“Galileo”) in the form of a convertible note. Galileo specializes in liquification, natural gas compression and re-gasification modular systems and technologies to make the production, transportation, and consumption of natural gas, biomethane, and hydrogen more economically viable. The convertible note bears interest at 5.0 percent per annum with a maturity date of the earlier of April 2027 or an exit event (as defined in the agreement as either an initial public offering or a sale of Galileo). If the conversion option is exercised, the note would convert into common shares of the parent of Galileo Holdco 2 ("Galileo Parent"). We do not intend to sell this investment prior to its maturity date or an exit event. As of September 30, 2022, the fair value of the convertible note was approximately equal to the cost basis.
All of our long-term debt securities, including our investment in Galileo, are classified as available-for-sale and are measured using Level 3 unobservable inputs based on the absence of market activity. The following table reconciles changes in the fair value of our Level 3 assets for the periods presented below:
Year Ended
(in thousands) 2022 2021
Assets at beginning of period $ 500 $ 500
Purchases 36,065 -
Transfers out1
(3,000) -
Assets at end of period $ 33,565 $ 500
(1)Conversion from debt to equity security
The following table provides quantitative information (in thousands) about our Level 3 unobservable significant inputs related to our debt security investment with Galileo at September 30, 2022:
Fair Value Valuation Technique Unobservable Inputs
$ 33,000 Black-Scholes-Merton model Discount rate 22.4 %
Risk-free rate 4.0 %
Equity volatility 92.5 %
The above significant unobservable inputs are subject to change based on changes in economic and market conditions. The use of significant unobservable inputs creates uncertainty in the measurement of fair value as of the reporting date. Significant increases or decreases in the discount rate, risk-free rate, and equity volatility in isolation would result in a significantly lower or higher fair value measurement. It is not possible for us to predict the effect of future economic or market conditions on our estimated fair values.
During the fiscal year ended September 30, 2022, we sold our remaining equity securities of approximately 467.5 thousand shares in Schlumberger, Ltd. and received proceeds of approximately $22.0 million. For the fiscal year ended September 30, 2022, we recorded a total gain of $8.2 million related to this investment, which included a $0.5 million gain recognized upon the sale of our investment and a $7.7 million gain as a result of the change in fair value of the investment during the period. This activity is reported in Gain (Loss) on Investment Securities in our Consolidated Statements of Operations. This investment was classified as Level 1 and based on the quoted stock price.
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Contingent Consideration
Other financial instruments measured using Level 3 unobservable inputs primarily consist of potential earnout payments associated with our business acquisitions in fiscal year 2019 and certain consulting services. Contingent consideration is recorded in Accrued Liabilities and Other Noncurrent Liabilities on the Consolidated Balance Sheets based on the expected timing of milestone achievements. The following table reconciles changes in the fair value of our Level 3 liabilities for the periods presented below:
(in thousands) 2022 2021
Liabilities at beginning of period $ 2,996 $ 9,123
Additions 1,500 -
Total gains or losses:
Included in earnings (224) 1,123
Settlements1
(250) (7,250)
Liabilities at end of period $ 4,022 $ 2,996
(1)Settlements represent earnout payments that have been paid or earned during the period.
Nonrecurring Fair Value Measurements
We have certain assets that are subject to measurement at fair value on a nonrecurring basis. For these nonfinancial assets, measurement at fair value in periods subsequent to their initial recognition is applicable if they are determined to be impaired. These assets generally include property, plant and equipment, goodwill, intangible assets, and operating lease right-of-use assets. If measured at fair value in the Consolidated Balance Sheets, these would generally be classified within Level 2 or 3 of the fair value hierarchy. Further details on any changes in valuation of these assets is provided in their respective footnotes.
Other Equity Securities
We also hold various other equity securities without readily determinable fair values. These equity securities are measured at cost, less any impairments, and recorded within Investments on our Consolidated Balance Sheets. As of September 30, 2022 and 2021, the aggregate balance of these equity securities was $23.7 million and $2.9 million, respectively. During the fiscal year ended September 30, 2022 and 2021, we did not record any impairments on these investments.
The following table reconciles changes in the balance of our equity securities, without readily determinable fair values, for the periods presented below:
Year Ended
September 30,
(in thousands) 2022
Assets at beginning of period $ 2,865 $ -
Purchases 15,177 2,865
Transfers in1
3,000 -
Unrealized gain included in earnings 2,703 -
Assets at end of period $ 23,745 $ 2,865
(1)Conversion from debt to equity security
Geothermal Investments
As of September 30, 2022 and 2021 the aggregate balance of our debt and equity security investments in geothermal energy was $23.7 million and $2.7 million, respectively. All of our geothermal investments are considered a Level 3 input based on the absence of market activity. These investments include assets measured on both a recurring and nonrecurring basis (discussed in the subsections above).
Other Financial Instruments
The carrying amount of cash and cash equivalents and restricted cash approximates fair value due to the short-term nature of these items. The majority of cash equivalents are invested in highly liquid money-market mutual funds invested primarily in direct or indirect obligations of the U.S. Government and in federally insured deposit accounts. The carrying value of accounts receivable, other current and noncurrent assets, accounts payable, accrued liabilities and other liabilities approximated fair value at September 30, 2022 and 2021.
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The following information presents the supplemental fair value information for our current and long-term fixed-rate debt at September 30, 2022 and 2021:
September 30,
(in millions) 2022 2021
Current portion of long-term debt, net1
Carrying value $ - $ 483.5
Fair value - 541.6
Long-term debt, net
Carrying value 542.6 542.0
Fair value 430.7 554.3
(1)On October 27, 2021 we redeemed the outstanding 2025 Notes. See Note 7-Debt to our Consolidated Financial Statements.
The fair values of the current and long-term fixed-rate debt is based on broker quotes at September 30, 2022 and 2021. The notes are classified within Level 2 of the fair value hierarchy as they are not actively traded in markets.
NOTE 14 EMPLOYEE BENEFIT PLANS
We maintain a domestic noncontributory defined benefit pension plan covering certain U.S. employees who meet certain age and service requirements. In July 2003, we revised the Helmerich & Payne, Inc. Employee Retirement Plan (“Pension Plan”) to close the Pension Plan to new participants effective October 1, 2003, and reduce benefit accruals for current participants through September 30, 2006, at which time benefit accruals were discontinued and the Pension Plan was frozen.
The following table provides a reconciliation of the changes in the pension benefit obligations and fair value of Pension Plan assets over the two-year period ended September 30, 2022 and a statement of the funded status as of September 30, 2022 and 2021:
September 30,
(in thousands) 2022 2021
Accumulated benefit obligation $ 60,463 $ 110,352
Changes in projected benefit obligations:
Projected benefit obligation at beginning of year $ 110,352 $ 116,146
Interest cost 2,537 2,925
Actuarial (gain) loss (16,260) 7,111
Benefits paid (36,166) (15,749)
Other - (81)
Projected benefit obligation at end of year $ 60,463 $ 110,352
Change in plan assets:
Fair value of plan assets at beginning of year $ 87,255 $ 86,103
Actual return on plan assets (14,324) 11,835
Employer contribution 5,000 5,066
Benefits paid (36,167) (15,749)
Fair value of plan assets at end of year $ 41,764 $ 87,255
Funded status of the plan at end of year $ (18,699) $ (23,097)
Fluctuations in actuarial gains and losses during the period are primarily due to changes in the discount rate and investment returns. The mortality table issued by the Society of Actuaries in October 2021 was used for the September 30, 2022 pension calculation.
The amounts recognized in the Consolidated Balance Sheets at September 30, 2022 and 2021 are as follows:
September 30,
(in thousands) 2022 2021
Accrued liabilities $ - $ -
Noncurrent liabilities-other (18,699) (23,097)
Net amount recognized $ (18,699) $ (23,097)
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The amounts recognized in Accumulated Other Comprehensive Income (Loss) at September 30, 2022 and 2021, and not yet reflected in net periodic benefit cost, are as follows:
September 30,
(in thousands) 2022 2021
Net actuarial loss $ 15,703 $ 26,268
Unrecognized actuarial gains/losses outside of a corridor of the greater of: 1) 10 percent of the Projected Benefit Obligation, or 2) the fair value of assets, are amortized into expense for the year on a straight-line basis over the average remaining service years of participants. Amortization is not carried from year-to-year as the calculation resets each year.
The weighted average assumptions used for the pension calculations were as follows:
September 30,
2022 2021 2020
Discount rate for net periodic benefit costs 2.75 % 2.66 % 3.16 %
Discount rate for year-end obligations 5.44 % 2.75 % 2.66 %
Expected return on plan assets 4.25 % 3.50 % 4.65 %
We made a voluntary contribution of $5.0 million in both fiscal year 2022 and fiscal year 2021. In fiscal year 2023, we do not expect minimum contributions required by law to be needed. However, we may make contributions in fiscal year 2023 if needed to fund unexpected distributions in lieu of liquidating pension assets.
Components of the net periodic pension expense were as follows:
Year Ended September 30,
(in thousands) 2022 2021 2020
Interest cost $ 2,537 $ 2,925 $ 3,598
Expected return on plan assets1
(2,481) (3,722) (4,784)
Recognized net actuarial loss 2,080 3,205 2,718
Settlement expense 9,031 3,448 3,001
Other - (81) -
Net pension expense $ 11,167 $ 5,775 $ 4,533
(1)The Company uses the fair value of plan assets in determining the expected return on plan assets.
We record settlement expense when benefit payments exceed the total annual interest costs. During March 2022, the Company's domestic noncontributory defined benefit pension plan was amended to include a limited lump sum distribution option and a special eligibility window to be available to certain participants. During the period beginning on May 2, 2022 and ending on June 30, 2022, these participants could elect the limited lump sum distribution. This one-time lump sum was subsequently paid in August 2022 and resulted in a pension settlement charge of $7.8 million during the year ended September 30, 2022.
The following table reflects the expected benefits to be paid from the Pension Plan in each of the next five fiscal years, and in the aggregate for the five years thereafter (in thousands):
Year Ended September 30,
2023 2024 2025 2026 2027 2028 - 2032 Total
$ 5,479 $ 5,049 $ 5,614 $ 5,088 $ 5,376 $ 22,827 $ 49,433
Investment Strategy and Asset Allocation
Our investment policy and strategies are established with a long-term view in mind. The investment strategy is intended to help pay the cost of the Pension Plan while providing adequate security to meet the benefits promised under the Pension Plan. We maintain a diversified asset mix to minimize the risk of a material loss to the portfolio value that might occur from devaluation of any single investment. In determining the appropriate asset mix, our financial strength and ability to fund potential shortfalls are considered. Pension Plan assets are invested in portfolios of diversified public-market equity securities and fixed income securities. The Pension Plan does not directly hold securities of the Company.
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The expected long-term rate of return on Pension Plan assets is based on historical and projected rates of return for current and planned asset classes in the Pension Plan’s investment portfolio after analyzing historical experience and future expectations of the return and volatility of various asset classes.
During the 2021 fiscal year, we implemented a glide-path strategy with a goal to reduce risk as certain funded levels are achieved and began aligning our fixed income exposure with our pension liabilities. The target allocation for 2023 and the asset allocation for the Pension Plan at the end of fiscal years 2022 and 2021, by asset category, were as follows:
Target Allocation September 30,
Asset Category 2023 2022 2021
U.S. equities 17 % 18 % 46 %
International equities 12 11 17
Fixed income 71 71 37
Total 100 % 100 % 100 %
Plan Assets
The fair value of Pension Plan assets at September 30, 2022 and 2021, summarized by level within the fair value hierarchy described in Note 13-Fair Value Measurement of Financial Instruments, are as follows:
September 30, 2022
(in thousands) Total Level 1 Level 2 Level 3
Short-term investments $ 555 $ 555 $ - $ -
Mutual funds:
Domestic stock funds 7,318 7,318 - -
Bond funds 29,093 29,093 - -
International stock funds 4,739 4,739 - -
Total mutual funds 41,150 41,150 - -
Oil and gas properties 59 - - 59
Total $ 41,764 $ 41,705 $ - $ 59
September 30, 2021
(in thousands) Total Level 1 Level 2 Level 3
Short-term investments $ 2,444 $ 2,444 $ - $ -
Mutual funds:
Domestic stock funds 35,212 35,212 - -
Bond funds 17,679 17,679 - -
Balanced funds 17,520 17,520 - -
International stock funds 14,379 14,379 - -
Total mutual funds 84,790 84,790 - -
Oil and gas properties 21 - - 21
Total $ 87,255 $ 87,234 $ - $ 21
As of September 30, 2022 and 2021, the Pension Plan’s financial assets utilizing Level 1 inputs are valued based on quoted prices in active markets for identical securities. As of September 30, 2022 and 2021, the Pension Plan’s assets utilizing Level 3 inputs consist of oil and gas properties. The fair value of oil and gas properties is determined by Wells Fargo Bank, N.A., based upon actual revenue received for the previous twelve-month period and experience with similar assets.
Defined Contribution Plan
Substantially all employees on the U.S. payroll may elect to participate in our 401(k)/Thrift Plan by contributing a portion of their earnings. We contribute an amount equal to 100 percent of the first five percent of the participant’s compensation subject to certain limitations. The annual expense incurred for this defined contribution plan was $24.8 million, $13.6 million and $23.8 million in fiscal years 2022, 2021 and 2020, respectively.
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NOTE 15 SUPPLEMENTAL BALANCE SHEET INFORMATION
The following reflects the activity in our reserve for expected credit losses on trade receivables for fiscal years 2022, 2021 and 2020:
September 30,
(in thousands) 2022 2021 2020
Reserve for credit losses:
Balance at October 1, $ 2,068 $ 1,820 $ 9,927
Provision for credit loss 1,077 203 2,203
(Write-off) recovery of credit loss (170) 45 (10,310)
Balance at September 30, $ 2,975 $ 2,068 $ 1,820
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Accounts receivable, prepaid expenses and other current assets, net, accrued liabilities and noncurrent liabilities -other at September 30, 2022 and 2021 consist of the following:
September 30,
(in thousands) 2022 2021
Accounts receivable, net of reserve:
Trade receivables $ 430,944 $ 204,424
Income tax receivable 27,769 24,470
Total accounts receivable, net of reserve $ 458,713 $ 228,894
Prepaid expenses and other current assets, net:
Deferred mobilization $ 5,048 $ 3,734
Prepaid insurance 7,498 7,313
Prepaid value added tax 6,628 7,682
Prepaid maintenance and rent 13,092 5,540
Accrued demobilization, net 6,319 4,513
Prepaid operating expenses - 17,959
Prepaid equipment 10,091 -
Other 17,787 20,837
Total prepaid expenses and other current assets, net $ 66,463 $ 67,578
Accrued liabilities:
Accrued operating costs $ 26,539 $ 20,872
Payroll and employee benefits 58,604 69,311
Taxes payable, other than income tax 26,786 25,329
Self-insurance liabilities 38,422 40,060
Deferred income 19,821 8,546
Advance payment for sale of property, plant and equipment - 86,524
Deferred mobilization revenue 8,959 4,662
Accrued income taxes 40,833 881
Contingent liability 2,750 5,985
Operating lease liability 12,382 12,624
Other 6,055 8,698
Total accrued liabilities $ 241,151 $ 283,492
Noncurrent liabilities - Other:
Pension and other non-qualified retirement plans $ 40,423 $ 47,263
Self-insurance liabilities 38,422 40,910
Contingent liability 1,272 1,759
Deferred revenue 3,162 1,003
Uncertain tax positions including interest and penalties 2,381 2,578
Operating lease liability 27,350 37,864
Payroll tax deferral1
- 15,424
Other 377 956
Total noncurrent liabilities - other $ 113,387 $ 147,757
(1)Deferral related to the provisions within the Coronavirus Aid, Relief, and Economic Security Act, enacted on March 27, 2020, which allows for the deferral of the employer share of Social Security tax.
NOTE 16 COMMITMENTS AND CONTINGENCIES
Purchase Commitments
Equipment, parts and supplies are ordered in advance to promote efficient construction and capital improvement progress. At September 30, 2022, we had purchase commitments for equipment, parts and supplies of approximately $148.6 million.
Lease Obligations
Refer to Note 5-Leases for additional information on our lease obligations.
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Guarantee Arrangements
We are contingently liable to sureties in respect of bonds issued by the sureties in connection with certain commitments entered into by us in the normal course of business. We have agreed to indemnify the sureties for any payments made by them in respect of such bonds.
Contingencies
During the ordinary course of our business, contingencies arise resulting from an existing condition, situation or set of circumstances involving an uncertainty as to the realization of a possible gain or loss contingency. We account for gain contingencies in accordance with the provisions of ASC 450, Contingencies, and, therefore, we do not record gain contingencies or recognize income until realized. The property and equipment of our Venezuelan subsidiary was seized by the Venezuelan government on June 30, 2010. 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., seeking damages for the seizure of their 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 May 2018, an employee of our subsidiary, HPIDC, was involved in a car accident in his personal vehicle while not clocked in for work. The accident resulted in a fatality of a passenger in the other vehicle. The estate of the victim, his widow and children subsequently brought a lawsuit against the employee and HPIDC in Texas State District Court in January 2020. In February 2022, trial began in the matter and the jury reached a verdict against HPIDC and our employee for approximately $126.0 million, including interest. In March 2022, the court entered a judgment consistent with the findings of the jury. In April 2022, the Company and its insurers filed post-trial motions, none of which were granted by the trial judge. However, on June 23, 2022, Plaintiffs' counsel filed a Voluntary Remittitur with the trial court, which formally reduced the verdict to $60.0 million. The Company and its insurers are currently filing motions to appeal the judgement. Accordingly, the Company cannot make an estimate of the possible loss at this time. As of September 30, 2022, we have incurred expenses, mainly legal fees, against the insurance deductible. At this time, we believe our insurance policies will be responsive to the amounts over our $3.0 million insurance deductible and that foreseeable exposures to the Company exceeding the deductible will be recovered through insurance. Accordingly, we do not believe this exposure will exceed our insurance coverage limits.
The Company and its subsidiaries are parties to various other pending legal actions arising in the ordinary course of our business. We maintain insurance against certain business risks subject to certain deductibles. Although no assurance can be given, we believe, based on our experiences to date and taking into account established reserves and insurance, that the ultimate resolution of such items will not have a material adverse impact on our financial condition, cash flows, or results of operations. When we determine a loss is probable of occurring and is reasonably estimable, we accrue an undiscounted liability for such contingencies based on our best estimate using information available at that time. If the estimated loss is a range of potential outcomes and there is no better estimate within the range, we accrue the amount at the low end of the range. We disclose contingencies where an adverse outcome may be material, or in the judgment of management, we conclude the matter should otherwise be disclosed.
NOTE 17 BUSINESS SEGMENTS AND GEOGRAPHIC INFORMATION
Description of the Business
We are a performance-driven drilling solutions and technologies company based in Tulsa, Oklahoma with operations in all major U.S. onshore oil and gas producing basins as well as South America and the Middle East. Our drilling operations consist mainly of contracting Company-owned drilling equipment primarily to large oil and gas exploration companies. We believe we are the recognized industry leader in drilling as well as technological innovation. We focus on offering our customers an integrated solutions-based approach by combining proprietary rig technology, automation software, and digital expertise into our rig operations rather than a product-based offering, such as a rig or separate technology package. Our drilling services operations are organized into the following reportable operating business segments: North America Solutions, Offshore Gulf of Mexico and International Solutions.
Each reportable operating segment is a strategic business unit that is managed separately, and consolidated revenues and expenses reflect the elimination of all material intercompany transactions. Our real estate operations, our incubator program for new research and development projects, and our wholly-owned captive insurance companies are included in "Other." External revenues included in “Other” primarily consist of rental income.
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Segment Performance
We evaluate segment performance based on income or loss from continuing operations (segment operating income (loss)) before income taxes which includes:
•Revenues from external and internal customers
•Direct operating costs
•Depreciation and amortization
•Allocated general and administrative costs
•Asset impairment charges
•Restructuring charges
but excludes gain on reimbursement of drilling equipment, other (gain) loss on sale of assets, and corporate selling, general and administrative costs, corporate depreciation, and corporate restructuring charges.
General and administrative costs are allocated to the segments based primarily on specific identification and, to the extent that such identification is not practical, other methods may be used which we believe to be a reasonable reflection of the utilization of services provided.
Summarized financial information of our reportable segments for the fiscal years ended September 30, 2022, 2021 and 2020 is shown in the following tables:
September 30, 2022
(in thousands) North America Solutions Offshore Gulf of Mexico International Solutions Other Eliminations Total
External sales $ 1,788,167 $ 125,465 $ 136,072 $ 9,240 $ - $ 2,058,944
Intersegment - - - 57,047 (57,047) -
Total sales 1,788,167 125,465 136,072 66,287 (57,047) 2,058,944
Segment operating income (loss) 121,893 23,214 (138) 12,720 (6,422) 151,267
Depreciation and amortization 375,250 9,175 4,156 1,701 - 390,282
September 30, 2021
(in thousands) North America Solutions Offshore Gulf of Mexico International Solutions Other Eliminations Total
External sales $ 1,026,364 $ 126,399 $ 57,917 $ 7,888 $ - $ 1,218,568
Intersegment - - - 35,416 (35,416) -
Total sales 1,026,364 126,399 57,917 43,304 (35,416) 1,218,568
Segment operating income (loss) (287,176) 15,969 (21,003) (9,704) (1,580) (303,494)
Depreciation and amortization 392,415 10,557 2,013 1,426 - 406,411
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September 30, 2020
(in thousands) North America Solutions Offshore Gulf of Mexico International Solutions Other Eliminations Total
External sales $ 1,474,380 $ 143,149 $ 144,185 $ 12,213 $ - $ 1,773,927
Intersegment - - - 36,901 (36,901) -
Total sales 1,474,380 143,149 144,185 49,114 (36,901) 1,773,927
Segment operating income (loss) (393,902) 7,478 (162,368) 4,403 - (544,389)
Depreciation and amortization 438,039 11,681 17,531 1,241 - 468,492
The following table reconciles segment operating income (loss) per the tables above to income (loss) from continuing operations before income taxes as reported on the Consolidated Statements of Operations:
Year Ended September 30,
(in thousands) 2022 2021 2020
Segment operating income (loss) $ 151,267 $ (303,494) $ (544,389)
Gain on reimbursement of drilling equipment 29,443 12,322 26,959
Other gain (loss) on sale of assets 5,432 (11,280) 19,816
Corporate selling, general and administrative costs, corporate depreciation and corporate restructuring charges (140,850) (126,097) (122,573)
Operating income (loss) from continuing operations 45,292 (428,549) (620,187)
Other income (expense)
Interest and dividend income 18,090 10,254 7,304
Interest expense (19,203) (23,955) (24,474)
Gain (loss) on investment securities 57,937 6,727 (8,720)
Gain on sale of subsidiary - - 14,963
Loss on extinguishment of debt (60,083) - -
Other (11,115) (5,657) (5,384)
Total unallocated amounts (14,374) (12,631) (16,311)
Income (loss) from continuing operations before income taxes $ 30,918 $ (441,180) $ (636,498)
The following table reconciles segment total assets to total assets as reported on the Consolidated Balance Sheets:
Year Ended September 30,
(in thousands) 2022 2021
Total assets1
North America Solutions $ 3,406,824 $ 3,418,569
Offshore Gulf of Mexico 80,993 84,580
International Solutions 330,974 269,820
Other 120,305 95,398
3,939,096 3,868,367
Investments and corporate operations 416,435 1,165,761
Total assets from continuing operations $ 4,355,531 $ 5,034,128
(1)Assets by segment exclude investments in subsidiaries and intersegment activity.
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The following table presents revenues from external customers by country based on the location of service provided:
Year Ended September 30,
(in thousands) 2022 2021 2020
Operating revenues
United States $ 1,920,026 $ 1,158,230 $ 1,626,407
Argentina 91,385 27,855 84,402
Bahrain 16,986 27,435 28,653
United Arab Emirates 5,698 957 24,716
Colombia 22,003 1,674 6,414
Other foreign 2,846 2,417 3,335
Total $ 2,058,944 $ 1,218,568 $ 1,773,927
The following table presents property, plant and equipment by country based on the location of service provided:
Year Ended September 30,
(in thousands) 2022 2021
Property, plant and equipment, net
United States $ 2,872,145 $ 3,042,140
Argentina 54,789 50,944
Colombia 21,809 22,959
Other foreign 12,066 11,244
Total $ 2,960,809 $ 3,127,287
NOTE 18 RESTRUCTURING CHARGES
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. During the third quarter of fiscal year 2021, we commenced a voluntary separation program at our local office in Argentina for which we incurred severance charges for employees who were voluntarily terminated.
Additionally, during fiscal year 2021, we continued to take measures to lower our cost structure based on activity levels. During fiscal year 2021, we incurred 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. These charges are included in other restructuring expenses within the table below.
The following table summarizes the Company's restructuring charges incurred during the year ended September 30, 2021:
Year Ended September 30, 2021
(in thousands) North America Solutions International Solutions Corporate Total
Employee termination benefits $ 54 $ 207 $ 1,215 $ 1,476
Other restructuring expenses 3,815 - 635 $ 4,450
Total restructuring charges $ 3,869 207 $ 1,850 $ 5,926
Beginning in the third quarter of fiscal year 2020, we implemented cost controls and began evaluating further measures to respond to the combination of weakened commodity prices, uncertainties related to the COVID-19 pandemic, and the resulting market volatility. We restructured our operations to accommodate scale during an industry downturn and to re-organize our operations to align to new marketing and management strategies. We commenced a number of restructuring efforts as a result of this evaluation, which included, among other things, a reduction in our capital allocation plans, changes to our organizational structure, and a reduction of staffing levels. Costs incurred during the fiscal year ended September 30, 2020 in connection with the restructuring were primarily comprised of severance benefits to employees who were voluntarily or involuntarily terminated, benefits related to forfeitures and costs related to modification of stock-based compensation awards.
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The following table summarizes the Company's restructuring charges incurred during the year ended September 30, 2020:
Year Ended September 30, 2020
(in thousands) North America Solutions Offshore Gulf of Mexico International Solutions Other Corporate G&A Total
Employee termination benefits $ 10,041 $ 1,432 $ 2,991 $ 321 $ 4,745 $ 19,530
Stock-based compensation benefit (3,036) (178) (11) (61) (197) (3,483)
Total restructuring charges $ 7,005 $ 1,254 $ 2,980 $ 260 $ 4,548 $ 16,047
These expenses are recorded within restructuring charges on our Consolidated Statements of Operations for the fiscal years ended September 30, 2021 and 2020.
NOTE 19 SUBSEQUENT EVENTS
As part of our commitment to return cash to shareholders, on October 17, 2022, the Board of Directors of the Company declared a quarterly cash supplemental dividend of $0.235 per share on the Company’s common stock, payable on December 1, 2022, to stockholders of record at the close of business on November 15, 2022. The payable date and record date of this supplemental dividend coincides with the dates applicable to the Company’s base dividend of $0.25 per share, which was declared on September 7, 2022.
In October 2022, we purchased a $14.1 million equity investment, representing approximately 106 million shares, in Tamboran Resources Limited ("Tamboran"). Tamboran's shares are listed and publicly traded on the Australian Securities Exchange. Additionally, during September 2022, we entered into a fixed-term drilling services agreement with Tamboran. The expected $30.3 million of revenue to be earned over the term of the contract is included within our contract backlog as of September 30, 2022, as mobilization is expected to commence in fiscal year 2023.
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ITEM 9. CHANGES IN AND DISAGREEMENTS WITH ACCOUNTANTS
ITEM 9. CHANGES IN AND DISAGREEMENTS WITH ACCOUNTANTS ON ACCOUNTING AND FINANCIAL DISCLOSURE
None.

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ITEM 9A. CONTROLS AND PROCEDURES
ITEM 9A. CONTROLS AND PROCEDURES
a) Evaluation of Disclosure Controls and Procedures.
Our management, with the participation of our Chief Executive Officer and Chief Financial Officer, evaluated the effectiveness of our disclosure controls and procedures as of the end of the period covered by this report. Based on that evaluation, the Chief Executive Officer and Chief Financial Officer concluded that our disclosure controls and procedures as of the end of the period covered by this report have been designed and are effective at the reasonable assurance level so that the information required to be disclosed by us in our SEC filings, is recorded, processed, summarized and reported within the time periods specific in the SEC’s rules, regulations, and forms and is accumulated and communicated to management, including our Chief Executive Officer and Chief Financial Officer, as appropriate to allow timely decisions regarding financial disclosure. We believe that a controls system, no matter how well designed and operated, cannot provide absolute assurance that the objectives of the controls system are met, and no evaluation of controls can provide absolute assurance that all control issues and instances of fraud, if any, within a company have been detected.
b) Management’s Report on Internal Control over Financial Reporting.
A copy of our Management’s Report on Internal Control over Financial Reporting is included in Item 8 of this Form 10-K.
c) Attestation Report of the Independent Registered Public Accounting Firm.
A copy of the report of Ernst & Young LLP, our independent registered public accounting firm, is included in Item 8 of this Form 10-K.
d) Changes in Internal Control Over Financial Reporting.
There have been no material changes in our internal controls over financial reporting during the year ended September 30, 2022 that have materially affected, or is reasonably likely to materially affect, our internal controls over financial reporting.

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ITEM 9B. OTHER INFORMATION
ITEM 9B. OTHER INFORMATION
None.

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ITEM 10. DIRECTORS, EXECUTIVE OFFICERS AND CORPORATE GOVERNANCE
ITEM 10. DIRECTORS, EXECUTIVE OFFICERS AND CORPORATE GOVERNANCE
The information required by this item is incorporated herein by reference to the material under the captions “Proposal 1-Election of Directors,” “Corporate Governance” and “Executive Officers” in our definitive Proxy Statement for the Annual Meeting of Stockholders to be held in calendar year 2023, to be filed with the SEC no later than 120 days after September 30, 2022.
We have adopted a Code of Ethics for our Principal Executive Officer and Senior Financial Officers. The text of this code is located on our website under “http://ir.helmerichpayne.com/websites/helmerichandpayne/English/4500.html.” Our Internet address is www.helmerichpayne.com. We intend to disclose any amendments to or waivers from this code on our website.
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ITEM 11. EXECUTIVE COMPENSATION
ITEM 11. EXECUTIVE COMPENSATION
The information required by this item regarding executive compensation, as well as director compensation and compensation committee interlocks and insider participation, is incorporated herein by reference to the material beginning with the caption “Compensation Committee Report” and ending with the caption “Pay Ratio Disclosure”, as well as under the captions “Director Compensation in Fiscal Year 2022” and “Corporate Governance-Compensation Committee Interlocks and Insider Participation” in our definitive Proxy Statement for the Annual Meeting of Stockholders to be held in calendar year 2023, to be filed with the SEC no later than 120 days after September 30, 2022.

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ITEM 12. SECURITY OWNERSHIP OF CERTAIN BENEFICIAL OWNERS
ITEM 12. SECURITY OWNERSHIP OF CERTAIN BENEFICIAL OWNERS AND MANAGEMENT AND RELATED STOCKHOLDER MATTERS
The information required by this item is incorporated herein by reference to the material under the captions “Summary of All Existing Equity Compensation Plans,” “Security Ownership of Certain Beneficial Owners” and “Security Ownership of Directors and Management” in our definitive Proxy Statement for the Annual Meeting of Stockholders to be held in calendar year 2023, to be filed with the SEC no later than 120 days after September 30, 2022.

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ITEM 13. CERTAIN RELATIONSHIPS AND RELATED TRANSACTIONS
ITEM 13. CERTAIN RELATIONSHIPS AND RELATED TRANSACTIONS, AND DIRECTOR INDEPENDENCE
The information required by this item is incorporated herein by reference to the material under the captions “Corporate Governance-Transactions With Related Persons, Promoters and Certain Control Persons” and “Corporate Governance-Director Independence” in our definitive Proxy Statement for the Annual Meeting of Stockholders to be held in calendar year 2023, to be filed with the SEC no later than 120 days after September 30, 2022.

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ITEM 14. PRINCIPAL ACCOUNTING FEES AND SERVICES
ITEM 14. PRINCIPAL ACCOUNTANT FEES AND SERVICES
The information required by this item is incorporated herein by reference to the material under the caption “Proposal 2-Ratification of Appointment of Independent Auditors-Audit Fees” in our definitive Proxy Statement for the Annual Meeting of Stockholders to be held in calendar year 2023, to be filed with the SEC no later than 120 days after September 30, 2022.
PART IV

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ITEM 15. EXHIBITS, FINANCIAL STATEMENT SCHEDULES
ITEM 15. EXHIBITS AND FINANCIAL STATEMENT SCHEDULES
1.Financial Statements: Our consolidated financial statements, together with the notes thereto and the report of Ernst & Young LLP dated November 16, 2022, are listed below and included in Item 8 - “Financial Statements and Supplementary Data” of this Form 10-K.
Page
Report of Independent Registered Public Accounting Firm (PCAOB ID Number 00042)
Consolidated Balance Sheets at September 30, 2022 and 2021
Consolidated Statements of Operations for the Years Ended September 30, 2022, 2021 and 2020
Consolidated Statements of Comprehensive Income (Loss) for the Years Ended September 30, 2022, 2021 and 2020
Consolidated Statements of Shareholders’ Equity for the Years Ended September 30, 2022, 2021 and 2020
Consolidated Statements of Cash Flows for the Years Ended September 30, 2022, 2021 and 2020
Notes to Consolidated Financial Statements
2.Financial Statement Schedules: All schedules are omitted because they are not applicable or required or because the required information is contained in the financial statements or included in the notes thereto.
3.Exhibits: The following documents are included as exhibits to this Form 10-K. Exhibits incorporated by reference are duly noted as such.
3.1
Amended and Restated Certificate of Incorporation of Helmerich & Payne, Inc. (incorporated herein by reference to Exhibit 3.1 of the Company’s Form 8-K filed on March 14, 2012, SEC File No. 001-04221).
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3.2 Amended and Restated By-laws of Helmerich & Payne, Inc. (incorporated herein by reference to Exhibit 3.1 of the Company’s Form 8-K filed on June 2, 2021, SEC File No. 001-04221).
4.1 Description of Securities Registered Pursuant to Section 12 of the Securities Exchange Act of 1934 (incorporated herein by reference to Exhibit 4.1 of the Company’s Annual Report on Form 10-K for the fiscal year ended September 30, 2021, SEC File No. 001-04221).
4.2 Indenture, dated March 19, 2015, among Helmerich & Payne International Drilling Co., Helmerich & Payne, Inc. and Wells Fargo Bank, National Association, as trustee (incorporated herein by reference to Exhibit 4.1 of the Company’s Form 8-K filed on March 19, 2015, SEC File No. 001-04221).
4.3 Indenture, dated December 20, 2018, among Helmerich & Payne, Inc., Helmerich & Payne International Drilling Co. and Wells Fargo Bank, National Association, as trustee (incorporated herein by reference to Exhibit 4.1 of the Company’s Form 8-K filed on December 20, 2018, SEC File No. 001-04221).
4.4 First Supplemental Indenture, dated December 20, 2018, to the Indenture, dated December 20, 2018, among Helmerich & Payne, Inc., Helmerich & Payne International Drilling Co. and Wells Fargo Bank, National Association, as trustee (including the forms of 4.65% Senior Note due 2025) (incorporated herein by reference to Exhibit 4.2 of the Company’s Form 8-K filed on December 20, 2018, SEC File No. 001-04221).
4.5 Second Supplemental Indenture, dated September 29, 2021, to the Indenture, dated December 20, 2018, between Helmerich & Payne, Inc. and Wells Fargo Bank, National Association, as trustee (including the form of 2.900% Senior Note due 2031) (incorporated herein by reference to Exhibit 4.2 of the Company’s Form 8-K filed on September 29, 2021, SEC File No. 001-04221).
4.6 Registration Rights Agreement, dated September 29, 2021, among Helmerich & Payne, Inc. and the initial purchasers named therein (incorporated herein by reference to Exhibit 4.3 of the Company’s Form 8-K filed on September 29, 2021, SEC File No. 001-04221)
10.1 Credit Agreement, dated November 13, 2018, among Helmerich & Payne, Inc., the lenders from time to time party thereto and Wells Fargo Bank, National Association (incorporated herein by reference to Exhibit 10.2 of the Company’s Annual Report on Form 10-K for the fiscal year ended September 30, 2018, SEC File No. 001-04221).
10.2 Amendment No. 1 to Credit Agreement, dated November 13, 2019, among Helmerich & Payne, Inc., the lenders party thereto and Wells Fargo Bank, National Association (incorporated herein by reference to Exhibit 10.2 of the Company's Annual Report on Form 10-K for the fiscal year ended September 30, 2019, SEC File No. 001-04221).
10.3 Amendment No. 2 to Credit Agreement, Dated March 8, 2022, among Helmerich & Payne, Inc., the lenders party thereto and Wells Fargo Bank, National Association.
*10.4 Form of Change of Control Agreement applicable to executive officers and certain other employees of Helmerich & Payne, Inc., adopted September 9, 2020 (incorporated herein by reference to Exhibit 10.1 of the Company’s Form 8-K filed on September 14, 2020, SEC File No. 001-04221).
*10.5 Helmerich & Payne, Inc. 2010 Long-Term Incentive Plan (incorporated herein by reference to Appendix “A” of the Company’s Proxy Statement on Schedule 14A filed on January 26, 2011, SEC File No. 001-04221).
*10.6 Form of Agreements for the Helmerich & Payne, Inc. 2010 Long-Term Incentive Plan applicable to certain executives: (i) Nonqualified Stock Option Agreement and (ii) Restricted Stock Award Agreement (incorporated herein by reference to Exhibit 10.1 of the Company’s Form 8-K filed on March 14, 2012, SEC File No. 001-04221).
*10.7 Form of Agreements for the Helmerich & Payne, Inc. 2010 Long-Term Incentive Plan applicable to participants other than certain executives: (i) Nonqualified Stock Option Agreement and (ii) Restricted Stock Award Agreement (incorporated herein by reference to Exhibit 10.2 of the Company’s Form 8-K filed on March 14, 2012, SEC File No. 001-04221).
*10.8 Form of Agreements for the Helmerich & Payne, Inc. 2010 Long-Term Incentive Plan applicable to Directors: (i) Nonqualified Stock Option Agreement and (ii) Restricted Stock Award Agreement (incorporated by reference to Exhibit 10.3 of the Company’s Form 8-K filed on March 14, 2012, SEC File No. 001-04221).
*10.9 Helmerich & Payne, Inc. 2016 Omnibus Incentive Plan (incorporated herein by reference to Appendix “A” of the Company’s Proxy Statement on Schedule 14A filed on January 19, 2016, SEC File No. 001-04221).
*10.10 Form of Agreements for the Helmerich & Payne, Inc. 2016 Omnibus Incentive Plan applicable to certain executives: (i) Nonqualified Stock Option Agreement and (ii) Restricted Stock Award Agreement (incorporated herein by reference to Exhibit 10.26 of the Company’s Annual Report on Form 10-K for the fiscal year ended September 30, 2016, SEC File No. 001-04221).
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*10.11 Form of Agreements for the Helmerich & Payne, Inc. 2016 Omnibus Incentive Plan applicable to participants other than certain executives: (i) Nonqualified Stock Option Agreement and (ii) Restricted Stock Award Agreement (incorporated herein by reference to Exhibit 10.27 of the Company’s Annual Report on Form 10-K for fiscal year ended September 30, 2016, SEC File No. 001-04221).
*10.12 Form of Agreements for the Helmerich & Payne, Inc. 2016 Omnibus Incentive Plan applicable to Directors: (i) Nonqualified Stock Option Agreement and (ii) Restricted Stock Award Agreement (incorporated herein by reference to Exhibit 10.28 of the Company’s Annual Report on Form 10-K for the fiscal year ended September 30, 2016, SEC File No. 001-04221).
*10.13 Supplemental Retirement Income Plan for Salaried Employees of Helmerich & Payne, Inc. (incorporated herein by reference to Exhibit 10.1 of the Company’s Quarterly Report on Form 10-Q for the quarter ended December 31, 2008, SEC File No. 001-04221).
*10.14 Supplemental Savings Plan for Salaried Employees of Helmerich & Payne, Inc. (incorporated herein by reference to Exhibit 10.2 of the Company’s Quarterly Report on Form 10-Q for the quarter ended December 31, 2008, SEC File No. 001-04221).
*10.15 Helmerich & Payne, Inc. Director Deferred Compensation Plan (incorporated herein by reference to Exhibit 10.3 of the Company’s Quarterly Report on Form 10-Q for the quarter ended December 31, 2008, SEC File No. 001-04221).
*10.16 Form of Performance-Vested Restricted Share Unit Award Agreement for the Helmerich & Payne, Inc. 2016 Omnibus Incentive Plan (incorporated herein by reference to Exhibit 10.1 of the Company’s Form 8-K filed on December 18, 2018, SEC File No. 001-04221).
*10.17 Helmerich & Payne, Inc. 2020 Omnibus Incentive Plan (incorporated herein by reference to Appendix “A” of the Company’s Proxy Statement on Schedule 14A filed on January 21, 2020, SEC File No. 001-04221).
*10.18 Helmerich & Payne, Inc. Director Deferred Compensation Plan (incorporated herein by reference to Exhibit 10.2 of the Company’s Quarterly Report on Form 10-Q for the quarter ended March 31, 2020, SEC File No. 001-04221).
*10.19 Form of Restricted Stock Award Agreement for the Helmerich & Payne, Inc. 2020 Omnibus Incentive Plan applicable to Directors (incorporated herein by reference to Exhibit 10.1 of the Company’s Quarterly Report on Form 10-Q for the quarter ended June 30, 2020, SEC File No. 001-04221).
*10.20 Form of Annual Three-Year Performance-Vested Restricted Share Unit Award Agreement for the Helmerich & Payne, Inc. 2020 Omnibus Incentive Plan (incorporated herein by reference to Exhibit 10.27 of the Company's Annual Report on Form 10-K for the fiscal year ended September 30, 2020, SEC File No. 001-04221).
*10.21 Form of Standard Three-Year Performance-Vested Restricted Share Unit Award Agreement for the Helmerich & Payne, Inc. 2020 Omnibus Incentive Plan (incorporated herein by reference to Exhibit 10.28 of the Company's Annual Report on Form 10-K for the fiscal year ended September 30, 2020, SEC File No. 001-04221).
*10.22 Form of Restricted Stock Award Agreement for the Helmerich & Payne, Inc. 2020 Omnibus Incentive Plan applicable to employees (incorporated herein by reference to Exhibit 10.29 of the Company's Annual Report on Form 10-K for the fiscal year ended September 30, 2020, SEC File No. 001-04221).
*10.23 Amendment to Standard Three-Year Performance-Vested Restricted Share Unit Award Agreement for the 2020 Helmerich & Payne, Inc. 2020 Omnibus Incentive Plan, dated June 6, 2022 (incorporated herein by reference to Exhibit 10.1 of the Company’s Quarterly Report on Form 10-Q for the quarter ended June 30, 2022, SEC File No. 001-04221).
*10.24 Helmerich & Payne, Inc. Amended and Restated 2020 Omnibus Incentive Plan (incorporated herein by reference to Appendix "A" of the Company's Proxy Statement on Schedule 14A filed on January 18, 2022, SEC File No. 001-04221).
*10.25 Form of Restricted Stock Agreement for the Helmerich & Payne Amended and Restated 2020 Omnibus Incentive Plan applicable to Directors (incorporated herein by reference to Exhibit 10.3 of the Company’s Quarterly Report on Form 10-Q for the quarter ended March 31, 2022, SEC File No. 001-04221).
*10.26 Form of Annual Three-Year Performance-Vested Restricted Share Unit Award Agreement for the Helmerich & Payne, Inc. Amended and Restated 2020 Omnibus Incentive Plan (incorporated herein by reference to Exhibit 10.4 of the Company’s Quarterly Report on Form 10-Q for the quarter ended March 31, 2022, SEC File No. 001-04221).
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*10.27 Form of Standard Three-Year Performance-Vested Restricted Share Unit Award Agreement for the Helmerich & Payne, Inc. Amended and Restated 2020 Omnibus Incentive Plan (incorporated herein by reference to Exhibit 10.5 of the Company’s Quarterly Report on Form 10-Q for the quarter ended March 31, 2022, SEC File No. 001-04221).
*10.28 Form of Restricted Stock Award Agreement applicable to employees for the Helmerich & Payne, Inc. Amended and Restated 2020 Omnibus Incentive Plan (incorporated herein by reference to Exhibit 10.6 of the Company’s Quarterly Report on Form 10-Q for the quarter ended March 31, 2022, SEC File No. 001-04221).
21 List of Subsidiaries of the Company.
23.1 Consent of Independent Registered Public Accounting Firm.
31.1 Certification of Chief Executive Officer pursuant to Rule 13a-14(a) promulgated under the Securities Exchange Act of 1934, as amended, as adopted pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.
31.2 Certification of Chief Financial Officer pursuant to Rule 13a-14(a) promulgated under the Securities Exchange Act of 1934, as amended, as adopted pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.
32 Certification of Chief Executive Officer and Chief Financial Officer Pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002.
101 Financial statements from this Form 10-K formatted in Inline eXtensible Business Reporting Language (XBRL): (i) the Consolidated Balance Sheets, (ii) the Consolidated Statements of Operations, (iii) the Consolidated Statements of Comprehensive Income (Loss), (iv) the Consolidated Statements of Shareholders’ Equity, (v) the Consolidated Statements of Cash Flows and (vi) the Notes to Consolidated Financial Statements.
104 Cover Page Interactive Date File (formatted as Inline XBRL and contained in Exhibit 101).
*Management or Compensatory Plan or Arrangement.