UNITED STATES
SECURITIES AND EXCHANGE COMMISSION
Washington, D.C. 20549

FORM 10-K
(Mark One)

☒	ANNUAL REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934	
 For the fiscal year ended December 31, 2021
or
						
☐	TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934	
For the transition period from ________ to ________
Commission file number 001-38048
Altus Midstream Company
(Exact name of registrant as specified in its charter)

Delaware	 		 	81-4675947	
(State or other jurisdiction of
incorporation or organization)	 		 	(I.R.S. Employer Identification
No.)	
One Post Oak Central, 2000 Post Oak Boulevard, Suite 100, Houston, Texas 77056-4400
(Address of principal executive offices) (Zip Code)
Registrant’s telephone number, including area code (713) 296-6000

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

Title of each class	  	Trading Symbol(s)		Name of each exchange on which registered	
Class A common stock, $0.0001 par value	  	ALTM		Nasdaq Global Market	
Securities registered pursuant to section 12(g) of the Act: None
Indicate by check mark if the registrant is a well-known seasoned issuer, as defined in Rule 405 of the Securities Act. Yes ☐ No ☒
Indicate by check mark if the registrant is not required to file reports pursuant to Section 13 or Section 15(d) of the Act. Yes ☐ No ☒
Indicate by check mark whether the registrant (1) has filed all reports required to be filed by Section 13 or 15(d) of the Securities Exchange Act of 1934 during the preceding 12 months (or for such shorter period that the registrant was required to file such reports), and (2) has been subject to such filing requirements for the past 90 days. Yes ☒ No ☐
Indicate by check mark whether the registrant has submitted electronically every Interactive Data File required to be submitted pursuant to Rule 405 of Regulation S-T (§ 232.405 of this chapter) during the preceding 12 months (or for such shorter period that the registrant was required to submit such files). Yes ☒ No ☐
Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer, a smaller reporting company, or an emerging growth company. See the definitions of “large accelerated filer,” “accelerated filer,” “smaller reporting company,” and “emerging growth company” in Rule 12b-2 of the Exchange Act.

Large accelerated filer		☐	Accelerated filer	 	☒		Emerging growth company		☒	
Non-accelerated filer		☐	Smaller reporting company	 	☐					
If an emerging growth company, indicate by check mark if the registrant has elected not to use the extended transition period for complying with any new or revised financial accounting standards provided pursuant to Section 13(a) of the Exchange Act. ☐
Indicate by check mark whether the registrant has filed a report on and attestation to its management’s assessment of the effectiveness of its internal control over financial reporting under Section 404(b) of the Sarbanes-Oxley Act (15 U.S.C. 7262(b)) by the registered public accounting firm that prepared or issued its audit report. ☐
Indicate by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the Act):   Yes ☐ No ☒

Aggregate market value of the voting and non-voting common equity held by non-affiliates of registrant as of June 30, 2021	$	219,150,084 		
Number of shares of registrant’s Class A common stock, $0.0001 issued and outstanding as of January 31, 2022	16,246,460 		
Number of shares of registrant’s Class C common stock, $0.0001 issued and outstanding as of January 31, 2022	— 		
Documents Incorporated By Reference
Portions of registrant’s proxy statement relating to registrant’s 2021 annual meeting of stockholders have been incorporated by reference in Part II and Part III of this Annual Report on Form 10-K.

TABLE OF CONTENTS

									
Item		Page	
	PART I		
			
1.	BUSINESS	1	
1A.	RISK FACTORS	9	
1B.	UNRESOLVED STAFF COMMENTS	23	
2.	PROPERTIES	1	
3.	LEGAL PROCEEDINGS	23	
4.	MINE SAFETY DISCLOSURES	24	
			
	PART II		
			
5.	MARKET FOR THE REGISTRANT’S COMMON EQUITY, RELATED STOCKHOLDER MATTERS, AND ISSUER PURCHASES OF EQUITY SECURITIES	25	
6.	SELECTED FINANCIAL DATA	26	
7.	MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS	27	
7A.	QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK	44	
8.	FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA	47	
9.	CHANGES IN AND DISAGREEMENTS WITH ACCOUNTANTS ON ACCOUNTING AND FINANCIAL DISCLOSURE	44	
9A.	CONTROLS AND PROCEDURES	45	
9B.	OTHER INFORMATION	45	
9C.	DISCLOSURE REGARDING FOREIGN JURISDICTIONS THAT PREVENT INSPECTIONS	45	
			
	PART III		
			
10.	DIRECTORS, EXECUTIVE OFFICERS AND CORPORATE GOVERNANCE	46	
11.	EXECUTIVE COMPENSATION	46	
12.	SECURITY OWNERSHIP OF CERTAIN BENEFICIAL OWNERS AND MANAGEMENT AND RELATED STOCKHOLDER MATTERS	46	
13.	CERTAIN RELATIONSHIPS AND RELATED TRANSACTIONS, AND DIRECTOR INDEPENDENCE	46	
14.	PRINCIPAL ACCOUNTING FEES AND SERVICES	46	
			
	PART IV		
			
15.	EXHIBITS, FINANCIAL STATEMENT SCHEDULES	47	
16.	FORM 10-K SUMMARY	47	

i

FORWARD-LOOKING STATEMENTS AND RISK

This Annual Report on Form 10-K includes “forward-looking statements” within the meaning of Section 27A of the Securities Act of 1933, as amended (the Securities Act), and Section 21E of the Securities Exchange Act of 1934, as amended (the Exchange Act). All statements other than statements of historical facts included or incorporated by reference in this Annual Report on Form 10-K, including, without limitation, statements regarding the Company’s future financial position, business strategy, budgets, projected revenues, projected costs and plans, and objectives of management for future operations, are forward-looking statements. Such forward-looking statements are based on the Company’s examination of historical operating trends, production and growth forecasts of Apache Corporation’s Alpine High field development and other data in the Company’s possession or available from third parties. In addition, forward-looking statements generally can be identified by the use of forward-looking terminology such as “may,” “will,” “could,” “expect,” “intend,” “project,” “estimate,” “anticipate,” “plan,” “believe,” “continue,” “seek,” “guidance,” “might,” “outlook,” “possibly,” “potential,” “prospect,” “should,” “would,” or similar terminology, but the absence of these words does not mean that a statement is not forward looking. Although the Company believes that the expectations reflected in such forward-looking statements are reasonable under the circumstances, it can give no assurance that such expectations will prove to have been correct. Important factors that could cause actual results to differ materially from the Company’s expectations include, but are not limited to, its assumptions about:
•the ability of Altus and the Contributed Entities (as defined herein) to consummate the BCP Business Combination (as defined herein);
•the timing of the consummation of the BCP Business Combination;
•the ability of Altus to integrate the Contributed Entities’ operations and achieve or realize any anticipated benefits, savings, or growth from the BCP Business Combination;
•the scope, duration, and reoccurrence of any epidemics or pandemics (including, specifically, the coronavirus disease 2019 (COVID-19) pandemic and any related variants) and the actions taken by third parties, including, but not limited to, governmental authorities, customers, contractors, and suppliers, in response to such epidemics or pandemics;
•the mandate, availability, and effectiveness of vaccine programs and other therapeutics related to the treatment of COVID-19;
•the market prices of oil, natural gas, natural gas liquids (NGLs), and other products or services;
•pipeline and gathering system capacity and availability;
•production rates, throughput volumes, reserve levels, and development success of dedicated oil and gas fields;
•economic and competitive conditions;
•the availability of capital;
•cash flow and the timing of expenditures;
•capital expenditures and other contractual obligations;
•weather conditions;
•inflation rates;
•the availability of goods and services;
•the impact of political pressure, and the influence of environmental groups and other stakeholders, on decisions and policies related to the industries in which the Company and its affiliates operate;
•legislative, regulatory, or policy changes;
•terrorism or cyberattacks;
•occurrence of property acquisitions or divestitures;
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•the integration of acquisitions;
•a decline in oil, natural gas, and NGL production, and the impact of general economic conditions on the demand for oil, natural gas, and NGLs;
•the impact of environmental, health and safety, and other governmental regulations and of current or pending legislation, including initiatives addressing the impact of global climate change;
•environmental risks;
•the effects of competition;
•the retention of key members of senior management and key technical personnel;
•increases in interest rates;
•the effectiveness of the Company’s business strategy;
•changes in technology;
•market-related risks, such as general credit, liquidity, and interest-rate risks;
•the timing, amount, and terms of the Company’s future issuances of equity and debt securities; and
•other factors disclosed under Item 1A—Risk Factors, Item 7—Management’s Discussion and Analysis of Financial Condition and Results of Operations, Item 7A—Quantitative and Qualitative Disclosures About Market Risk and elsewhere in this Annual Report on Form 10-K.
Other factors or events that could cause the Company’s actual results to differ materially from the Company’s expectations may emerge from time to time, and it is not possible for the Company to predict all such factors or events. All subsequent written and oral forward-looking statements attributable to the Company, or persons acting on its behalf, are expressly qualified in their entirety by the cautionary statements. All forward-looking statements speak only as of the date of this Annual Report on Form 10-K. Except as required by law, the Company disclaims any obligation to update or revise its forward-looking statements, whether based on changes in internal estimates or expectations, new information, future developments, or otherwise.

iii

GLOSSARY OF TERMS

The following are abbreviations and definitions of certain terms used in this Annual Report on Form 10-K and certain terms which are commonly used in the exploration, production, and midstream sectors of the oil and natural gas industry:
•Bbl. One stock tank barrel of 42 United States (U.S.) gallons liquid volume used herein in reference to crude oil, condensate or NGLs.
•Bbl/d. One Bbl per day.
•Bcf. One billion cubic feet of natural gas.
•Bcf/d. One Bcf per day.
•Btu. One British thermal unit, which is the quantity of heat required to raise the temperature of a one-pound mass of water by one degree Fahrenheit.
•Field. An area consisting of a single reservoir or multiple reservoirs all grouped on, or related to, the same individual geological structural feature or stratigraphic condition. The field name refers to the surface area, although it may refer to both the surface and the underground productive formations.
•Formation. A layer of rock which has distinct characteristics that differs from nearby rock.
•MBbl. One thousand barrels of crude oil, condensate or NGLs.
•MBbl/d. One MBbl per day.
•Mcf. One thousand cubic feet of natural gas.
•Mcf/d. One Mcf per day.
•MMBbl. One million barrels of crude oil, condensate or NGLs.
•MMBtu. One million British thermal units.
•MMcf. One million cubic feet of natural gas.
•MMcf/d. One MMcf per day.
•NGLs. Natural gas liquids. Hydrocarbons found in natural gas, which may be extracted as liquefied petroleum gas and natural gasoline.
•Reserves. Estimated remaining quantities of oil and natural gas and related substances anticipated to be economically producible, as of a given date, by application of development projects to known accumulations. In addition, there must exist, or there must be a reasonable expectation that there will exist, the legal right to produce or a revenue interest in the production, installed means of delivering oil and natural gas or related substances to market and all permits and financing required to implement the project.

References to “Altus,” “ALTM,” and the “Company” mean Altus Midstream Company and its consolidated subsidiaries, unless otherwise specifically stated.
References to “Apache” mean Apache Corporation and its consolidated subsidiaries. References to the Company’s Class A common stock, $0.0001 par value (Class A Common Stock), and Class C common stock, $0.0001 par value (Class C Common Stock), reflect such share amounts as retrospectively restated to reflect the Company’s reverse stock split, which was effected June 30, 2020.
iv

PART I

ITEMS 1. and 2. BUSINESS AND PROPERTIES
Corporate History
Altus Midstream Company was originally incorporated on December 12, 2016 in Delaware under the name Kayne Anderson Acquisition Corp. (KAAC) for the purpose of effecting a merger, capital stock exchange, asset acquisition, stock purchase, reorganization, or similar business combination with one or more businesses. KAAC completed its initial public offering in the second quarter of 2017, after which its securities began trading on the Nasdaq Capital Market (Nasdaq).
On August 3, 2018, Altus Midstream LP was formed in Delaware as a limited partnership and wholly-owned subsidiary of the Company. On August 8, 2018, KAAC and Altus Midstream LP entered into a contribution agreement (the Altus Contribution Agreement) with certain wholly-owned subsidiaries of Apache Corporation (Apache), including four Delaware limited partnerships (collectively, Altus Midstream Operating) and their general partner (Altus Midstream Subsidiary GP LLC, a Delaware limited liability company, and together with Altus Midstream Operating, the Altus Midstream Entities). The Altus Midstream Entities were formed by Apache between May 2016 and January 2017 for the purpose of acquiring, developing, and operating midstream oil and gas assets in the Alpine High resource play and surrounding areas (Alpine High).
On November 9, 2018 (the Closing Date) and pursuant to the terms of the Altus Contribution Agreement, KAAC acquired from Apache the entire equity interests of the Altus Midstream Entities and options to acquire equity interests in five separate third-party pipeline projects (the Pipeline Options). The acquisition of the entities and the Pipeline Options is referred to herein as the Altus Combination. In exchange, the consideration provided to Apache included economic voting and non-economic voting shares in KAAC and common partnership units representing limited partner interests in Altus Midstream LP (Common Units).
Following the Closing Date and in connection with the closing of the Altus Combination:
•KAAC changed its name to Altus Midstream Company;
•Altus Midstream Company’s wholly-owned subsidiary, Altus Midstream GP LLC, a Delaware limited liability company (Altus Midstream GP), is the sole general partner of Altus Midstream LP;
•Altus Midstream Company operates its business through Altus Midstream LP and its subsidiaries, which include Altus Midstream Operating (collectively, Altus Midstream);
•Altus Midstream Company held approximately 23.1 percent of the outstanding Common Units and a controlling interest in Altus Midstream LP and Apache held the remaining 76.9 percent; and
•Altus Midstream Company’s Class A common stock, $0.0001 par value (Class A Common Stock), continued trading on the Nasdaq under the new symbol “ALTM.”
For further information on Altus’ equity structure, refer to Note 10—Equity and Warrants set forth in Part IV, Item 15 of this Annual Report on Form 10-K.
Business Combination with BCP
On October 21, 2021, the Company announced that it will combine with privately-owned BCP Raptor Holdco LP (BCP and, together with BCP Raptor Holdco GP, LLC, the Contributed Entities) in an all-stock transaction, pursuant to the Contribution Agreement dated as of that same date and entered into by and among Altus, Altus Midstream LP (the Partnership), New BCP Raptor Holdco, LLC (the Contributor), and BCP (the BCP Contribution Agreement). The combination creates an integrated midstream company in the Texas Delaware Basin offering services for residue gas, NGLs, crude oil and water. There are numerous expected commercial and financial synergies generated from the complementary midstream systems and enhanced scale of the business. The combined business will have a more diversified asset profile and customer base, with a lower risk profile than either entity on a stand-alone basis. BCP is the parent company of EagleClaw Midstream, which includes EagleClaw Midstream Ventures, the Caprock Midstream and Pinnacle Midstream businesses, and a 26.7 percent interest in the Permian Highway Pipeline. Pursuant to the BCP Contribution Agreement, Contributor will contribute all of the equity interests of the Contributed Entities (the Contributed Interests) to the Partnership, with each Contributed Entity becoming a wholly-owned subsidiary of the Partnership (the BCP Business Combination).
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As consideration for the contribution of the Contributed Interests, the Company will issue 50 million shares of Class C Common Stock (and Altus Midstream LP will issue a corresponding number of Common Units) to BCP’s unitholders, which are principally funds affiliated with Blackstone and I Squared Capital. The transaction is expected to close during the first quarter of 2022 following completion of customary closing conditions.
As a result of the transaction, the Company’s current stockholders will continue to hold their shares of Class A Common Stock and Class C Common Stock (collectively, Altus Common Stock), and Contributor or its designees will collectively own approximately 75% of the issued and outstanding shares of Altus Common Stock. Apache Midstream LLC, a wholly-owned subsidiary of APA Corporation, which currently owns approximately 79% of the issued and outstanding shares of Altus Common Stock, will own approximately 20% of the issued and outstanding shares of Altus Common Stock, and the remaining current stockholders will own approximately 5% of the issued and outstanding shares of Altus Common Stock.
Business Overview
Altus Midstream Company has no independent operations or material assets outside its partnership interests in Altus Midstream, which are reported on a consolidated basis. The Company’s segment analysis and presentation is the same as that of Altus Midstream. Altus Midstream owns gas gathering, processing, and transmission assets in the Permian Basin of West Texas, anchored by midstream service contracts to service Apache’s production from Alpine High. Additionally, Altus owns equity interests in four intrastate Permian Basin pipelines (the Equity Method Interest Pipelines) that have access to various points along the Texas Gulf Coast. The Company’s operations consist of one reportable segment.
Through the Company’s website, www.altusmidstream.com, you can access, free of charge, electronic copies of the charters of the committees of Altus’ board of directors, other documents related to corporate governance (including Altus’ Code of Business Conduct), and documents the Company files with the Securities and Exchange Commission (SEC), including Annual Reports on Form 10-K, Quarterly Reports on Form 10-Q, and Current Reports on Form 8-K, as well as any amendments to these reports filed or furnished pursuant to Section 13(a) or 15(d) of the Exchange Act. Access to these electronic filings is available as soon as reasonably practicable after Altus electronically files such material with, or furnishes it to, the SEC. You may also request printed copies of the Company’s certificate of incorporation, bylaws, committee charters, or other governance documents free of charge by writing to Altus’ corporate secretary at the address on the cover of this Annual Report on Form 10-K. From time to time, the Company also posts announcements, updates, and investor information on its website in addition to copies of all recent press releases. Information on Altus’ website or any other website is not incorporated by reference into, and does not constitute a part of, this Annual Report on Form 10-K.
Assets of Altus Midstream
As of December 31, 2021, Altus Midstream’s assets included approximately 182 miles of in-service natural gas gathering pipelines, approximately 46 miles of residue gas pipelines with four market connections, and approximately 38 miles of NGL pipelines. Three cryogenic processing trains, each with nameplate capacity of 200 MMcf/d, were placed into service during 2019. Other assets include an NGL truck loading terminal with six Lease Automatic Custody Transfer units and eight NGL bullet tanks with 90,000 gallon capacity per tank. The Company’s existing gathering, processing, and transmission infrastructure is expected to provide capacity levels capable of fulfilling its midstream contracts to service Apache’s production from Alpine High and potential third-party customers as market activity in the area continues to develop.
Equity Method Interest Pipelines
As of December 31, 2021, the Company owned equity interests in four Equity Method Interest Pipelines. Each Equity Method Interest Pipeline is operated by a third-party limited liability entity, as further described below. For a more in-depth discussion of the estimated capital resources, liquidity, and timing associated with each Equity Method Interest Pipeline, please see Part II, Item 7—Management’s Discussion and Analysis of Financial Condition and Results of Operations and Part IV, Item 15, Note 9—Equity Method Interests, set forth in this Annual Report on Form 10-K.
Gulf Coast Express Pipeline
In December 2018, Altus Midstream closed on the exercise of its Pipeline Option with Kinder Morgan Texas Pipeline LLC (Kinder Morgan), thereby acquiring a 15 percent equity interest in the Gulf Coast Express Pipeline Project (GCX). Altus Midstream acquired an additional 1 percent equity interest in May 2019, for a total 16 percent equity interest in GCX. GCX is a long-haul natural gas pipeline with capacity of approximately 2.0 Bcf/d and transports natural gas from the Waha area in northern Pecos County, Texas, to the Agua Dulce Hub near the Texas Gulf Coast. GCX is operated by Kinder Morgan and was placed into service in September 2019.
2

EPIC Crude Oil Pipeline
In March 2019, Altus Midstream closed on the exercise of its Pipeline Option with EPIC Pipeline LP, thereby acquiring a 15 percent equity interest in the EPIC crude oil pipeline (EPIC). The long-haul crude oil pipeline extends from the Orla area in northern Reeves County, Texas to the Port of Corpus Christi, Texas, and has Permian Basin initial throughput capacity of approximately 600 MBbl/d. The project includes terminals in Orla, Pecos, Crane, Robstown, Hobson, and Gardendale, Texas with Port of Corpus Christi connectivity and export access. It services Delaware Basin, Midland Basin, and Eagle Ford Shale production. EPIC is operated by EPIC Consolidated Operations, LLC and was placed into service in early 2020.
Permian Highway Pipeline
In May 2019, Altus Midstream closed on the exercise of its Pipeline Option with Kinder Morgan, thereby acquiring an approximate 26.7 percent equity interest in the Permian Highway Pipeline (PHP). The long-haul natural gas pipeline has capacity of approximately 2.1 Bcf/d and transports natural gas from the Waha area in northern Pecos County, Texas to the Katy, Texas area with connections to U.S. Gulf Coast and Mexico markets. PHP is operated by Kinder Morgan and was placed into service in January 2021.
Shin Oak NGL Pipeline
In July 2019, Altus Midstream closed on the exercise of its Pipeline Option with Enterprise Products Operating LLC (Enterprise Products), thereby acquiring a 33 percent equity interest in Breviloba LLC, which owns the Shin Oak NGL Pipeline (Shin Oak). The long-haul NGL pipeline has capacity of up to 550 MBbl/d and transports NGL production from the Orla area in northern Reeves County, Texas, through the Waha area in northern Pecos County, Texas, and on to Mont Belvieu, Texas. Shin Oak is operated by Enterprise Products and was placed into service during 2019.
Salt Creek NGL Pipeline
Altus Midstream’s option to acquire a 50 percent equity interest in the Salt Creek NGL Pipeline, an intra-basin NGL pipeline, was not exercised and expired on March 2, 2020.
Altus’ Relationship with Apache
About Apache
Apache is an independent energy company that explores for, develops, and produces natural gas, crude oil, and NGLs. As a result of the Altus Combination, Apache is the largest single owner of the Company’s voting common stock and also has an approximate 76.9 percent noncontrolling interest in Altus Midstream.
Additionally, as a result of the Altus Combination, Apache received certain equity instruments, which may impact its ownership and the ownership interest of Altus Midstream LP’s limited partners. For further information on the consideration received by Apache, please refer to Note 10—Equity and Warrants, within Part IV, Item 15 of this Annual Report on Form 10-K.
Apache’s Alpine High Resource Play
Altus’ midstream infrastructure and facilities were initially constructed to service Apache’s production from Alpine High. Alpine High lies in the southern portion of the Delaware Basin, primarily in Reeves County, Texas. The play contains multiple geologic formations and target zones spanning the hydrocarbon phase window from dry gas to wet gas to oil. During 2018 and 2019, Apache focused on geological testing and transitioned to initial tests of full-field development of the Alpine High play, drilling 100 wells and 82 wells, respectively. Given the prevailing gas and NGL price environment and disappointing performance of multi-well development pads in the second half of 2019, Apache materially reduced planned investment and future drilling plans at Alpine High.
This reduced investment level prompted Altus management to assess its long-lived infrastructure assets for impairment given the expected reduction to future throughput volumes. As a result of this assessment, Altus recorded impairments on its gathering, processing, and transmission assets in the fourth quarter of 2019. For further discussion of these impairments, please see Part II, Item 7—Management’s Discussion and Analysis of Financial Condition and Results of Operations and Note 1—Summary of Significant Accounting Policies and Note 4—Property, Plant, and Equipment in the Notes to Consolidated Financial Statements, each included within Part IV, Item 15 of this Annual Report on Form 10-K.
3

Agreements with Apache
The Company and/or its consolidated subsidiaries have entered into certain agreements with Apache. Those material agreements are described in further detail below.
Midstream Service Agreements
Apache has been Altus Midstream’s most significant customer since operations commenced in the second quarter of 2017. Altus Midstream Operating has contracted to provide gas gathering, compression, processing, transmission, and NGL transmission services pursuant to acreage dedications provided by Apache, comprising the entire Alpine High acreage discussed above. The Company is pursuing similar long-term commercial service contracts with third parties that could be accommodated by existing capacity.
In addition, Apache agreed that any gas produced from Apache-operated wells located within the dedication area that is owned by other working interest owners and royalty owners is dedicated to Altus Midstream, so long as Apache has the right to market such gas. The agreements, with the exception of the Gas Processing Agreement, are effective for primary terms beginning on July 1, 2018 and ending March 31, 2032. The primary term will automatically extend for two five-year periods unless Apache provides at least nine months’ prior written notice of its election not to extend the primary term. The covenants under the agreements are intended to run with the land and will be binding on any transferee of the interests within the dedicated area. The Company entered into a new Gas Processing Agreement with Apache with an effective date of September 1, 2021, which superseded the prior agreement. The contractual periods documented above, other than the effective date of the new Gas Processing Agreement, remain unchanged.
During 2020, Altus Midstream entered into separate agreements to provide compressor maintenance, operations, and related services to Apache for a fixed monthly fee per compressor serviced. Please refer to Note 3—Revenue Recognition set forth in Part IV, Item 15 in the Notes to Consolidated Financial Statements of this Annual Report on Form 10-K.
Operational Services Agreement
Prior to the Altus Combination, Apache provided operations, maintenance, and management services to Altus Midstream Operating, pursuant to an agreement hereby referred to as the “Services Agreement.” In accordance with the terms of the Services Agreement, Apache received a fixed fee per month for its overhead and indirect costs incurred on behalf of Altus Midstream Operating. Altus Midstream Operating had no banking or cash management activities prior to the Altus Combination, and therefore, all costs incurred by Altus Midstream Operating were paid by Apache. In connection with the closing of the Altus Combination, the Services Agreement was superseded by the COMA (as defined below).
Construction, Operations, and Maintenance Agreement
In connection with the closing of the Altus Combination, the Company entered into a construction, operations, and maintenance agreement with Apache (the COMA), pursuant to which Apache provides certain services related to the design, development, construction, operation, management, and maintenance of the Company’s assets, on the Company’s behalf.
Under the COMA, the Company paid or will pay fees to Apache of (i) $3.0 million from November 9, 2018 through December 31, 2019, (ii) $5.0 million for the period of January 1, 2020 through December 31, 2020, (iii) $7.0 million for the period of January 1, 2021 through December 31, 2021, and (iv) $9.0 million annually thereafter, adjusted based on actual internal overhead and general and administrative costs incurred, until terminated. In addition, Apache may be reimbursed for certain internal costs and third-party costs incurred in connection with its role as service provider under the COMA.
The COMA will continue to be effective until terminated (i) upon the mutual consent of Altus and Apache, (ii) by either of Altus and Apache, at its respective option, upon 30 days’ prior written notice in the event Apache or an affiliate no longer owns a direct or indirect interest in at least 50 percent of the voting or other equity securities of Altus, or (iii) by Altus if Apache fails to perform any of its covenants or obligations due to willful misconduct of certain key personnel and such failure has a material adverse financial impact on Altus. The Company anticipates that the COMA will be terminated upon closing of the BCP Business Combination.
Purchase Rights and Restrictive Covenants Agreement
At the closing of the Altus Combination, Altus and Apache entered into a purchase rights and restrictive covenants agreement (the Purchase Rights and Restrictive Covenants Agreement). Under the Purchase Rights and Restrictive Covenants Agreement, until the later of the five-year anniversary of the Closing Date or the date on which Apache and its affiliates cease to own a majority of the Company’s voting common stock, Apache is obligated to provide the Company with (i) the first right
4

to pursue any opportunity (including any expansion opportunities) of Apache to acquire or invest, directly or indirectly (including equity interests), in any midstream assets or participate in any midstream opportunities located, in whole or part, within an area covering approximately 1.7 million acres in Reeves, Pecos, Brewster, Culberson, and Jeff Davis Counties in Texas, and (ii) a right of first offer on certain retained midstream assets of Apache.
Amended and Restated Agreement of Limited Partnership of Altus Midstream
At the closing of the Altus Combination, the Company, Altus Midstream GP, and Apache entered into an amended and restated agreement of limited partnership of Altus Midstream LP, which was further amended in June 2019 pursuant to a second amended and restated agreement of limited partnership of Altus Midstream LP (the Amended LPA). Altus Midstream GP is the sole general partner of Altus Midstream LP and is ultimately responsible for all operational and administrative decisions of Altus Midstream including the day-to-day management of its business. Altus Midstream GP cannot be removed as the general partner of Altus Midstream LP except by its election and, subject to limited exceptions, may not transfer or assign its general partner interest. The Amended LPA contains certain provisions intended to ensure that a one-to-one ratio is maintained, at all times and subject only to limited exceptions, between (i) the number of outstanding shares of Class A Common Stock, and the number of Common Units held by Altus and (ii) the number of outstanding shares of Class C common stock $0.0001 par value (Class C Common Stock), and the number of Common Units held by any holder other than Altus.

On June 12, 2019, Altus Midstream LP issued and sold Series A Cumulative Redeemable Preferred Units (the Preferred Units) in a private offering. Concurrently, the Preferred Units were established as a new class of partnership unit representing limited partner interests in Altus Midstream LP pursuant to the terms of the Amended LPA, and the purchasers were admitted as limited partners of Altus Midstream LP. For further details on the terms of the Preferred Units and the rights of the holders thereof, refer to Note 11—Series A Cumulative Redeemable Preferred Units, within Part IV, Item 15 of this Annual Report on Form 10-K.
Lease Agreements
Concurrent with the closing of the Altus Combination, Altus Midstream entered into an operating lease agreement with Apache, relating to the use of certain office buildings, warehouse, and storage facilities located in Reeves County, Texas (the Lease Agreement). Under the terms of the Lease Agreement, Altus Midstream pays to Apache on a monthly basis the sum of (i) a base rental charge of $44,500 and (ii) an amount based on Apache’s estimate of the annual costs it shall incur in connection with the ownership, operation, repair, and/or maintenance of the facilities. Unpaid amounts accrue interest until settled. The initial term of the Lease Agreement is four years and may be extended by Altus Midstream for three additional, consecutive periods of twenty-four months. To accommodate Altus Midstream’s desire to vacate the leased premises, the Lease Agreement was amended in July 2020 to provide for its termination with respect to all or any portion of the leased premises which Apache may sell, with a pro rata rent reduction if Apache sells less than all of the leased premises.
In 2020 and 2021, Altus Midstream entered into various operating lease agreements with Apache related to the use of certain of Altus Midstream’s compressors. Under the terms of the agreement, Apache pays Altus Midstream fixed monthly lease payments, which are recorded as “Other” in the Company’s consolidated statement of operations. The lease agreements have an initial term of thirty months and automatically extend on a month-to-month basis unless either party cancels the agreement. The Company recorded income related to these agreements of $1.6 million and $0.4 million for the years ended December 31, 2021 and 2020, respectively. Altus also earns a monthly fee to operate and maintain the compressors under lease. Refer to Note 3—Revenue Recognition for further discussion.
Title to Properties
The Company’s interest in the property on which its assets are located derives from leases, easements, rights-of-way, permits, or licenses from landowners or governmental authorities, permitting the use of such land for its operations. The Company has leased or acquired easements, rights-of-way, permits, or licenses in these lands without any material challenge known to the Company relating to the title to the land upon which its assets are located, and Altus believes that it has satisfactory interests in such lands. In certain situations, the Company elected to allow Apache to acquire easements, rights-of-way, permits, and licenses from landowners to expedite the build-out of midstream infrastructure. Other than the aforementioned Apache real property, the Company has no knowledge of any challenge to the underlying fee title of any material lease, easement, right-of-way, permit, or license held by it or to its title to any material lease, easement, right-of-way, permit, or lease, and the Company believes that it has satisfactory title to all of its material leases, easements, rights-of-way, permits, and licenses.
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Seasonality
While the results of gathering, processing, and transmission are not materially affected by seasonality, from time to time the Company’s operations and construction of assets can be impacted by inclement weather.
Competition
The business of providing gathering, compression, processing, and transmission services for natural gas and NGLs is highly competitive. Altus faces strong competition in obtaining natural gas and NGL volumes, including from major integrated and independent exploration and production companies, interstate and intrastate pipelines, and other companies that gather, compress, treat, process, transmit, or market natural gas and NGLs. Competition for supplies is primarily based on geographic location of facilities in relation to production or markets, the reputation, efficiency, and reliability of the midstream company, and the pricing arrangements offered by the midstream company. For areas where acreage is not dedicated to Altus, the Company will compete with similar enterprises in providing additional gathering, compression, processing, and transmission services in the same area of operation.
Regulation
Natural Gas Pipeline Regulation
Under the Natural Gas Act (NGA), the Federal Energy Regulatory Commission (FERC) regulates the transportation of natural gas in interstate commerce. Intrastate transportation of natural gas is largely regulated by the state in which such transportation takes place. To the extent that the Company’s intrastate natural gas transportation system transports natural gas in interstate commerce, the rates, terms, and conditions of such services are subject to FERC jurisdiction under Section 311 of the Natural Gas Policy Act of 1978 (NGPA). The NGPA regulates, among other things, the provision of transportation services by an intrastate natural gas pipeline on behalf of a local distribution company or an interstate natural gas pipeline. Under Section 311 of the NGPA, rates charged for interstate transportation must be fair and equitable, and amounts collected in excess of fair and equitable rates are subject to refund with interest. The terms and conditions of service set forth in the Company’s statement of operating conditions for transportation service under Section 311 of the NGPA are also subject to FERC review and approval. Failure to observe the service limitations applicable to transportation services under Section 311, failure to comply with the rates approved by the FERC for Section 311 service, or failure to comply with the terms and conditions of service established in the pipeline’s FERC-approved statement of operating conditions could result in a change of jurisdictional status and/or the imposition of administrative, civil, and criminal remedies.
The Company’s intrastate natural gas operations are also subject to regulation by various agencies in Texas, principally the Railroad Commission of Texas (TRRC). Altus intrastate pipeline operations are also subject to the Texas Utilities Code and the Texas Natural Resources Code, as implemented by the TRRC. Generally, the TRRC is vested with authority to ensure that rates, operations, and services of gas utilities, including intrastate pipelines, are just and reasonable and not discriminatory. The rates the Company charges for transportation services are deemed just and reasonable under Texas law unless challenged in a customer or TRRC complaint. Failure to comply with the Texas Utilities Code or the Texas Natural Resources Code can result in the imposition of administrative, civil, and criminal remedies.
Natural Gas Gathering Regulation
Section 1(b) of the NGA exempts natural gas gathering facilities from the jurisdiction of the FERC. The Company believes that its natural gas gathering pipelines meet the traditional tests the FERC has used to establish whether a pipeline is a gathering pipeline that is not subject to FERC jurisdiction. However, the distinction between FERC-regulated transmission services and federally unregulated gathering services has been the subject of substantial litigation and varying interpretations. In addition, the FERC’s determinations as to whether a pipeline is a gathering pipeline are made on a case-by-case basis, so the classification and regulation of the Company’s natural gas pipeline system could be subject to change based on future determinations by the FERC and the courts. State regulation of gathering facilities generally includes various safety, environmental and, in some circumstances, nondiscriminatory take requirements and complaint-based rate regulation.
The Company’s natural gas pipeline system is subject to regulation by the TRRC under the Texas Utilities Code and the Texas Natural Resources Code in the same manner as described above for intrastate pipeline transportation facilities. The Company’s natural gas gathering pipeline system is also subject to ratable take and common purchaser statutes in Texas. The ratable take statute generally requires gatherers to take, without undue discrimination, natural gas production that may be tendered to the gatherer for handling. Similarly, the common purchaser statute generally requires gatherers to purchase without undue discrimination as to source of supply or producer. These statutes are designed to prohibit discrimination in favor of one producer over another producer or one source of supply over another source of supply.
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Natural Gas Liquids Pipeline Regulation
Transmission services rendered by Altus are subject to the regulation of the TRRC. The TRRC has the authority to regulate rates, though it generally has not investigated the rates or practices of intrastate pipelines in the absence of shipper complaints.
Employee Safety
Altus complies with the requirements of the Occupational Safety and Health Administration (OSHA) and comparable state laws that regulate the protection of the health and safety of workers. In addition, with respect to OSHA hazard communication standards, the Company believes that its operations are in substantial compliance with OSHA requirements, including general industry standards, hazard communication, record keeping requirements, and monitoring of occupational exposure to regulated substances.
Pipeline Safety Regulations
Some of Altus’ pipelines are subject to regulation by the U.S. Department of Transportation’s (DOT) Pipeline and Hazardous Materials Safety Administration (PHMSA) pursuant to the Natural Gas Pipeline Safety Act of 1968 (NGPSA), with respect to natural gas, and the Hazardous Liquids Pipeline Safety Act of 1979 (HLPSA), with respect to NGLs. The NGPSA and HLPSA regulate safety requirements in the design, construction, operation, and maintenance of natural gas, crude oil, and NGL pipeline facilities, while the Pipeline Safety Improvement Act of 2002 (PSIA) establishes mandatory inspections for all U.S. crude oil, NGL, and natural gas transmission pipelines in high consequence areas (HCAs), the violation of which can result in administrative, civil, and criminal penalties, including civil fines, injunctions, or both.
PHMSA regularly revises its pipeline safety regulations. Recently, the TRRC adopted rules that require operators of natural gas and hazardous liquid gathering lines in rural areas to report accidents, conduct investigations, and perform necessary corrective action.
States are largely preempted by federal law from regulating pipeline safety for interstate lines but most are certified by the DOT to assume responsibility for enforcing federal intrastate pipeline regulations and inspection of intrastate pipelines. States may adopt stricter standards for intrastate pipelines than those imposed by the federal government for interstate lines; however, states vary considerably in their authority and capacity to address pipeline safety. State standards may include requirements for facility design and management in addition to requirements for pipelines. The Company believes that its pipeline operations are in substantial compliance with applicable PHMSA and state requirements; however, due to the possibility of new or amended laws and regulations or reinterpretation of existing laws and regulations, there can be no assurance that future compliance with PHMSA or state requirements will not have a material adverse effect on the Company’s financial condition, results of operations, or cash flows.
Environmental Matters
Many of the operations and activities of Altus’ pipelines, gathering systems, processing plants, and other facilities are subject to significant federal, state, and local environmental laws and regulations, the violation of which can result in administrative, civil, and criminal penalties, including civil fines, injunctions, or both. Compliance with existing and anticipated environmental laws and regulations increases the Company’s overall costs of doing business, including costs of planning, constructing, and operating plants, pipelines, and other facilities, as well as capital expenditures necessary to maintain or upgrade equipment and facilities. Similar costs are likely upon changes in laws or regulations and upon any future acquisition of operating assets.
The Company believes that its operations are in substantial compliance with applicable environmental regulations and attempts to anticipate future regulatory requirements that might be imposed and plan accordingly. While any new or amended laws and regulations or reinterpretation of existing laws and regulations would not be expected to be any more burdensome to Altus than to other, similarly situated operators, there can be no assurance that future compliance with any new environmental requirements will not have an adverse effect on the Company’s financial condition, results of operations, or cash flows.
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Climate Change
Federal or state legislative or regulatory initiatives that regulate or restrict emissions of greenhouse gasses (GHGs) in areas in which Altus conducts business could adversely affect the availability of, or demand for, the products the Company stores, transmits, and processes and, depending on the particular program adopted, could increase the costs of Altus’ operations, including costs to operate and maintain facilities, install new emission controls on facilities, acquire allowances to authorize GHG emissions, pay any taxes related to GHG emissions, and/or administer and manage a GHG emissions program. The Company may be unable to recover any such lost revenues or increased costs in the rates charged to customers, and any such recovery may depend on events beyond its control, including the provisions of any final legislation or regulations. Reductions in the Company’s revenues or increases in expenses as a result of climate change initiatives could have adverse effects on the Company’s business, financial condition, results of operations, or cash flows.
Finally, some scientific studies have concluded that increasing concentrations of GHGs in the atmosphere could lead to climate change, which could result in the increased frequency and severity of climate events, including storms, floods, and fires. If any such effects were to occur, there may be an increased potential for adverse effects on the Company’s assets and operations.
Emerging Growth Company Status
Altus is an “emerging growth company,” as defined in Section 2(a)(19) of the Securities Act, as modified by the Jumpstart Our Business Startups Act of 2012 (JOBS Act). As such, the Company is eligible to take advantage of certain exemptions from various reporting requirements that are applicable to other public companies that are not “emerging growth companies” including, but not limited to, not being required to comply with the independent registered public accounting firm attestation requirements of Section 404 of the Sarbanes-Oxley Act, exemptions from the requirements of holding a non-binding advisory vote on executive compensation and stockholder approval of any golden parachute payments not previously approved, and reduced disclosure obligations regarding executive compensation in periodic reports and proxy statements. If some investors find Altus securities less attractive as a result, there may be a less active trading market for Altus’ securities and the prices of Altus’ securities may be more volatile.
In addition, Section 107 of the JOBS Act provides that an “emerging growth company” can take advantage of the extended transition period provided in Section 7(a)(2)(B) of the Securities Act for complying with new or revised accounting standards. In other words, an “emerging growth company” can delay the adoption of certain accounting standards until those standards would otherwise apply to private companies. While Altus has not opted out of the extended transition period provided in Section 7(a)(2)(B) of the Securities Act, the Company does not intend to take advantage of the benefits of this extended transition period.
Altus will remain an emerging growth company until the earlier of (1) the last day of the fiscal year (a) following April 4, 2022, the fifth anniversary of the completion of its initial public offering, (b) in which Altus has total annual gross revenue of at least $1.07 billion, or (c) in which Altus is deemed to be a large accelerated filer, which means the market value of Class A Common Stock that is held by non-affiliates exceeds $700.0 million as of the last business day of Altus’ prior second fiscal quarter (typically June 30th), and (2) the date on which Altus has issued more than $1.0 billion in non-convertible debt during the prior three-year period.
Employees
The Company has no employees. All individuals who conduct business for Altus are employed by Apache. Per the terms of the COMA, Apache operates, maintains and administers the Company’s operations and also provides management services.
Offices
Altus does not own any real estate or other physical properties materially important to its operation. The Company’s executive office is located at One Post Oak Central, 2000 Post Oak Boulevard, Suite 100, Houston, Texas 77056-4400. Refer to the “Agreements with Apache—Lease Agreement” section above for further discussion.

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ITEM 1A. RISK FACTORS 
The Company’s business activities and the value of its securities are subject to significant hazards and risks, including those described below. If any of such events should occur, Altus’ business, financial condition, liquidity, and/or results of operations could be materially harmed, and holders and purchasers of Altus’ securities could lose part or all of their investments. Additional risks relating to Altus’ securities may be included in the prospectuses for securities the Company may issue in the future.
RISKS RELATED TO THE BCP BUSINESS COMBINATION
Failure to complete, or significant delays in completing, the BCP Business Combination could negatively affect the trading price of the Class A Common Stock and Altus’ future business and financial results.

Completion of the BCP Business Combination is not assured and is subject to risks, including the risks that approval of the issuance of the equity consideration by Altus’ stockholders or approval of the transaction by governmental agencies is not obtained or that other closing conditions are not satisfied. If the transaction is not completed, or if there are significant delays in completing the transaction, the trading price of the Class A Common Stock and Altus’ future business and financial results could be negatively affected, and the Company will be subject to several risks, including the following:

•Altus may be liable for damages to Contributor under the terms of the BCP Contribution Agreement;
•negative reactions from the financial markets, including a decline in the trading price of the Class A Common Stock due to the fact that current prices may reflect a market assumption that the transaction will be completed;
•having to pay certain significant costs relating to the transaction, including, in certain circumstances, a termination fee to Contributor; and
•the attention of Altus’ management will have been diverted to the transaction rather than Altus’ own operations and pursuit of other opportunities that could have been beneficial to it.

The pendency of the BCP Business Combination could materially adversely affect the Company’s future business and operations or result in a loss of personnel.

Uncertainty about the effect of the BCP Business Combination on personnel, customers, and suppliers may have an adverse effect on the Company’s business. These uncertainties may impair the ability to attract, retain, and motivate key personnel of Apache providing services to Altus pursuant to the COMA until the transactions are consummated and for a period of time thereafter, and could cause customers, suppliers, and others who deal with the Company to change their existing business relationships, which could negatively affect the Company’s revenues, earnings, and cash flows, as well as the market price of the Company’s Class A Common Stock, regardless of whether the transactions are completed. Retention of personnel may be particularly challenging during the pendency of the transactions because personnel may experience uncertainty about their future roles with the combined company. If, despite retention efforts, key personnel depart because of issues relating to the uncertainty and difficulty of integration or a desire not to remain with or join the combined company, the Company’s business could be seriously harmed. Similar risks could affect BCP and, therefore, the combined company if the transactions are completed.

The BCP Contribution Agreement includes restrictions relating to the conduct of the Company’s business while the transactions are pending, which could adversely affect the Company’s business and operations.

Under the terms of the BCP Contribution Agreement, the Company is subject to certain restrictions on the conduct of its business prior to completing the transactions, which may adversely affect its ability to execute certain of its business strategies, including, subject to certain exceptions, restrictions on the acquisition or disposition of assets, the incurrence of capital expenditures, the entry into contracts, the incurrence of indebtedness, or the settlement of claims and lawsuits, unless the Company obtains the prior written consent of Contributor. Such limitations could negatively affect the Company’s business and operations prior to the completion of the transactions.

The failure to successfully integrate the business and operations of the Contributed Entities in the expected time frame may adversely affect Altus’ future results.

Altus believes that the acquisition of the Contributed Entities will result in certain benefits, including certain cost synergies and operational efficiencies. However, to realize these anticipated benefits, the businesses of Altus and the Contributed Entities must be successfully combined. The success of the BCP Business Combination will depend on Altus’
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ability to realize these anticipated benefits from combining the businesses of Altus and the Contributed Entities. Due to legal restrictions, Altus and Contributor have conducted, and until the completion of the transactions will conduct, only limited planning regarding the integration of the businesses following the transactions and will not determine the exact nature in which the businesses will be combined until after the transactions have been completed. The actual integration may result in additional and unforeseen expenses or delays. If the post-BCP Business Combination company is not able to successfully integrate the Contributed Entities’ businesses and operations, or if there are delays in combining the businesses, the anticipated benefits of the transaction may not be realized fully or at all or may take longer to realize than expected.

Additional risks related to the BCP Business Combination are described in the Company’s definitive proxy statement filed with the SEC on January 12, 2022.

RISKS RELATED TO THE COMPANY’S PRIMARY CUSTOMER AND MAJORITY OWNER
Altus derives a substantial portion of its revenue from Apache, and if Apache changes its business strategy, alters its current drilling and development plan on acreage dedicated to Altus, or otherwise significantly reduces the volumes of natural gas or NGLs with respect to which Altus performs midstream services, Altus’ revenue would decline and its business, financial condition, results of operations, and cash flows would be materially and adversely affected.
Substantially all of the Company’s current commercial agreements are with Apache, and as a result, Altus derives substantially all of its midstream services revenue from Apache. Accordingly, Altus will be subject to the operational and business risks of Apache, the most significant of which include the following:
•a failure to recommence or any further or subsequent reduction in or slowing of Apache’s drilling and development plans for or deferrals of production from the acreage dedicated to the Company, including as a result of volatility in the price of crude oil, natural gas, and NGLs or the availability of capital to fund Apache’s activities, which would directly and adversely impact demand for Altus’ midstream services;
•drilling and operating risks, including potential environmental liabilities, associated with Apache’s operations on the acreage dedicated to the Company;
•downstream processing and transportation capacity constraints and interruptions, including the failure of Apache to have sufficient contracted transportation capacity;
•adverse effects of increased or changed governmental and environmental regulation or enforcement of existing regulation, including legislative, regulatory, policy changes, or initiatives addressing the impact of global climate change, hydraulic fracturing, methane emissions, flaring, or water disposal; and
•Apache’s financial condition, credit ratings, leverage, market reputation, responses to ESG initiatives, liquidity, and cash flows.
Further, Altus does not have control over Apache’s business decisions and operations, and Apache is under no obligation to adopt a business strategy that is favorable to the Company. Thus, Altus will be subject to the risk of cancellation of planned development, nonperformance of commitments with respect to future dedications, and other nonpayment or nonperformance by Apache, including with respect to its commercial agreements, which do not contain minimum volume commitments. Furthermore, there is no guarantee that Apache will extend any agreements with the Company beyond their initial terms or that Altus will be able to renew or replace these agreements on equal or better terms, or at all, upon their expiration. Any material nonpayment or nonperformance by Apache under its commercial agreements with the Company would have a significant adverse impact on Altus’ business, financial condition, results of operations, and cash flows.
Altus does not have any employees and relies entirely on services provided by Apache’s employees.
The Company does not have any employees. Instead, Altus relies entirely on Apache’s employees to conduct the Company’s business and activities pursuant to the COMA. There could be material competition for the time and effort of the Apache officers and employees who provide services to both Altus and Apache. If Apache’s employees who provide services to the Company do not devote sufficient attention to the management and operation of Altus’ business and activities, Altus’ business, financial condition, results of operations, and cash flows could be materially and adversely affected.
Although the COMA provides for certain fixed annual limits on the support services fee payable to Apache through 2022, there is no limit on such fees thereafter. As a result, after 2022, Altus may be required to pay Apache higher fees than would be available from third parties. The COMA is subject to termination by Altus or Apache under certain circumstances, including if Apache and its affiliates no longer own a direct or indirect interest in at least 50 percent of the voting or other equity securities of the Company. Should the COMA be terminated by Altus or Apache, Altus will be required to attract and hire employees to
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perform the services currently performed by Apache’s employees under the COMA or otherwise contract with third parties for the provision of such services, which, in either case, could subject Altus to substantial additional costs, could cause significant disruptions to Altus’ business, may be on terms less favorable than the terms of the COMA, and as a result, Altus’ financial condition, results of operations, and cash flows could be adversely affected.
Altus’ executive officers and directors may face potential conflicts of interest in managing the Company’s business.
Altus’ executive officers and certain directors are also officers or employees of Apache. These relationships may create conflicts of interest regarding corporate opportunities and other matters. The resolution of any such conflicts may not always be in the Company’s or its stockholders’ best interests. In addition, these overlapping executive officers and directors allocate their time among Altus and Apache. These officers and directors face potential conflicts regarding the allocation of their time, which may adversely affect the Company’s business, results of operations, and financial condition.
Substantially all of Altus’ gathering and processing operations are located within the Southern Delaware Basin of West Texas, making it vulnerable to risks associated with having revenue-producing operations concentrated in one geographic area.
Altus’ revenue-producing operations are geographically concentrated primarily within the Southern Delaware Basin of West Texas, which disproportionately exposes the Company to risks associated with regional factors and increases its exposure to unexpected events that may occur in this region, such as natural disasters or localized pandemic outbreaks. Furthermore, the Company may be exposed to increases in costs as a result of regional economic conditions and the availability of goods and services, such as a skilled labor force, which could become more expensive (or at certain times, unavailable) if the labor market in the Permian Basin were to tighten. Any of these risks could adversely affect the Company’s financial condition, results of operations, or cash flows.
Apache may suspend, reduce, or terminate its obligations under its commercial agreements with Altus in certain circumstances, which could have a material adverse effect on Altus’ financial condition, results of operations, and cash flow.
Altus is party to certain commercial agreements with Apache that permit Apache to suspend, reduce, or terminate its obligations under the agreement if certain events occur. These events include force majeure events that would prevent the Company from performing some or all of the required services under the applicable agreement. Apache, as the counterparty under these commercial agreements, has the discretion to make such decisions, which may significantly and adversely affect the Company. Any such reduction, suspension, or termination of Apache’s obligations under these agreements would have a material adverse effect on the Company’s financial condition, results of operations, and cash flow.
While Apache has granted Altus a right of first offer to provide additional midstream services and acquire Apache’s retained midstream assets in Alpine High, Apache does not have to accept the Company’s offer.
Apache has granted Altus a right of first offer to provide additional midstream services and acquire Apache’s retained midstream assets in Alpine High. Although Apache granted Altus this right of first offer, the Company can make no assurances that the economic terms that it offers Apache will be acceptable to Apache, and another midstream services provider or a third party may be willing to make an offer to Apache on economic terms that Altus is unwilling or unable to offer. Altus’ inability to take advantage of the opportunities with respect to the right of first offer could adversely affect its growth strategy.
A significant amount of the revenue currently generated by Altus is from contracts with Apache that contain most favored nations rights and other consent rights, limiting flexibility to offer certain rates or capacity to new shippers.
Certain of the Company’s commercial agreements with Apache contain most favored nations rights (MFNs), which require that certain terms (including the rates charged thereunder) are no less favorable to Apache than those provided to any similarly situated counterparty. Without Apache’s consent, the MFNs effectively limit the Company’s flexibility in negotiating rates for some of Altus’ services with other shippers, because triggering the MFNs would lead to a reduction in the rates that the Company charges to Apache, which would adversely affect Altus’ financial condition, results of operations, or cash flows. Additionally, certain of the commercial agreements may require Apache’s consent to offer third-party customers priority of service in the Company’s facilities that is at least equal to Apache’s priority of service. If Apache refuses to grant such consent, the Company’s ability to attract third-party customers to its midstream facilities could be negatively impacted.

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If Apache elects to sell acreage that is dedicated to Altus to a third party, then the third party’s financial condition could be materially worse than Apache’s, and Altus could be subject to the nonpayment or nonperformance by the third party.
If Apache elects to sell acreage that is dedicated to the Company to a third party, then the third party’s financial condition could be materially worse than Apache’s. In such a case, the Company may be subject to risks of loss resulting from nonpayment or nonperformance by the third party, which risks may increase during periods of economic uncertainty. Furthermore, the third party may be subject to their own operating and regulatory risks, which increases the risk that they may default on their obligations to the Company. Any material nonpayment or nonperformance by the third party could adversely impact the business, financial condition, results of operations, and cash flows of the Company.
Apache owns a majority of Altus’ outstanding voting shares and thus strongly influences all of Altus’ corporate actions.
Apache and its affiliates beneficially own approximately 79 percent of Altus’ outstanding voting common stock. Under the Stockholders Agreement, Apache is entitled to nominate up to seven directors to Altus’ board of directors depending on its and its affiliates’ ownership of Altus’ outstanding voting common stock. As long as Apache and its affiliates own or control a significant percentage of Altus’ outstanding voting power, it will have the ability to strongly influence all corporate actions, including those requiring stockholder approval, the election and removal of directors, the size of Altus’ board of directors, any amendment of Altus’ charter or bylaws, any action impacting the Equity Method Interest Pipelines or the ownership of such interests, or the approval of any merger or other significant corporate transaction, including a sale of substantially all of Altus’ assets, and will be able to cause or prevent a change in the composition of Altus’ board of directors or a change in control of the Company that could deprive stockholders of an opportunity to receive a premium for their common stock as part of a sale of the Company. The interests of Apache may not align with the interests of Altus’ other stockholders.
RISKS RELATED TO CONSTRUCTING OR MAINTAINING ASSETS AND OPERATING THE BUSINESS
The COVID-19 pandemic has and may continue to adversely impact the Company’s business, financial condition, and results of operations, the global economy, and the demand for and prices of oil, natural gas, and NGLs. The unprecedented nature of the current situation makes it impossible for the Company to identify all potential risks related to the pandemic or estimate the ultimate adverse impact that the pandemic may have on its business.
The COVID-19 pandemic and the actions taken by third parties, including, but not limited to, governmental authorities, businesses, and consumers, in response to the pandemic have adversely impacted the global economy and created significant volatility in the global financial markets. Business closures, restrictions on travel, “stay-at-home” or “shelter-in-place” orders, and other restrictions on movement within and among communities have significantly reduced demand for and the prices of oil, natural gas, and NGLs. As of the date of this report, efforts to contain COVID-19 have not been successful in many regions, vaccination distribution programs have encountered delays, new variants have emerged, and the global pandemic remains ongoing. While some geographic regions have lifted, relaxed, or otherwise modified their pandemic response measures to lessen the impact of such measures on business operations and commerce, these regions may reinstitute restrictions as circumstances change. A continued, prolonged period or a renewed period of reduced demand, the failure to timely distribute or the ineffectiveness of or reluctance or refusal of individuals to take any vaccines, the failure to develop adequate treatments, and other adverse impacts from the pandemic may materially adversely affect the Company’s business, financial condition, cash flows, and results of operations.
The Company’s operations rely on Apache and its workforce being able to access the Company’s various facilities. Additionally, because Apache has previously implemented, and may elect to or be required in the future to reimplement, remote working procedures for a significant portion of its workforce for health and safety reasons and/or to comply with applicable national, state, and/or local government requirements, the Company relies on such persons having sufficient access to applicable information technology systems, including through telecommunication hardware, software, and networks. If a significant portion of Apache’s workforce cannot effectively perform their responsibilities, whether resulting from a lack of physical or virtual access, quarantines, illnesses, governmental actions or restrictions, including vaccine mandates and the reactions thereto, information technology or telecommunication failures, or other restrictions or adverse impacts resulting from the pandemic, the Company’s business, financial condition, cash flows, and results of operations may be materially adversely affected.
The unprecedented nature of the current situation resulting from the COVID-19 pandemic makes it impossible for the Company to identify all potential risks related to the pandemic or estimate the ultimate adverse impact that the pandemic may have on its business, financial condition, cash flows, or results of operations. Such results will depend on future events, which the Company cannot predict, including the scope, duration, and potential reoccurrence of the COVID-19 pandemic, the emergence and impact of additional variants, or any other localized epidemic or global pandemic, the distribution and effectiveness of vaccines, therapeutics and treatments, the demand for and the prices of oil, natural gas, and NGLs, and the
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actions taken by third parties, including, but not limited to, governmental authorities, customers, contractors, and suppliers, in response to the COVID-19 pandemic or any other epidemics or pandemics. The COVID-19 pandemic and its unprecedented consequences have amplified, and may continue to amplify, the other risks identified in this report.
Construction and maintenance of Altus’ assets (including the Equity Method Interest Pipelines) subjects the Company to risks of construction delays, cost over-runs, and negative effects on its financial condition, results of operations, or cash flows.
The construction and maintenance of Altus’ assets (including the Equity Method Interest Pipelines) and any additions or modifications to any such assets are complex projects that are subject to a number of factors beyond the Company’s control, including numerous regulatory, environmental, political, and legal uncertainties, delays from third-party landowners or their refusal to provide necessary consents, the permitting process, complying with laws, unavailability or increased cost of or tariffs on materials, labor disruptions, labor availability, environmental hazards, protests, third-party legal actions, financing, accidents, weather, and other factors. If the Company undertakes these projects, it may not be able to complete them on schedule, at the budgeted cost, or at all. Any delay in the completion or continued maintenance of such assets or any increase in or change in the timing of capital expenditures necessary to fund such construction or maintenance may require the expenditure of significant amounts of capital and could adversely affect the Company’s financial condition, results of operations, liquidity, or cash flows.
If the Company seeks to acquire assets or businesses but is unable to do so on economically acceptable terms or is unable to successfully integrate any acquired assets or operations, its future growth will be limited.
From time to time, the Company may evaluate and seek to acquire assets or businesses that it believes complement its existing business and related assets. The Company may acquire assets or businesses that it plans to use in a manner materially different from their prior owners’ uses. Any acquisition involves potential risks, including the inability to integrate the operations of recently acquired businesses or assets, especially if the assets acquired are in a new business segment or geographic area, the failure to realize expected volumes, revenues, profitability, or growth, the failure to realize any expected synergies and cost savings, the assumption of unknown liabilities, the loss of customers or key employees from the acquired businesses, and potential environmental or regulatory liabilities and title problems.
Any assessment of these risks will be inexact and may not reveal or resolve all existing or potential problems associated with an acquisition. Realization of any of these risks could adversely affect the Company’s financial condition, results of operations, and cash flows. If Altus consummates any future acquisition, its capitalization and results of operations may change significantly.
If third-party pipelines or other midstream facilities interconnected to the Company’s gathering, processing, or transmission systems become partially or fully unavailable or if the volumes Altus gathers, processes, or transmits do not meet the quality requirements of the pipelines or facilities to which Altus connects, its cash flows could be adversely affected.
The Company’s gathering, processing, and transmission assets connect to other pipelines or facilities owned and operated by unaffiliated third parties, and continuing access to such third-party pipelines, processing facilities, and other midstream facilities are not within the Company’s control. These pipelines, plants, and other midstream facilities may become unavailable because of testing, turnarounds, maintenance, reduced capacity, regulatory requirements, and other curtailments of receipt or deliveries. If the Company’s costs to access and transmit on these third-party pipelines significantly increase, if any of these pipelines or other facilities become unable to receive, transmit, or process product, or if the volumes the Company gathers or transmits do not meet the product quality requirements, then Altus’ cash flows could be adversely affected.
Increased competitive pressure could adversely affect Altus’ financial condition, results of operations, or cash flows.
Altus competes with similar enterprises in its industry, including large midstream companies that have greater financial resources and access to supplies than the Company. The principal elements of competition are rates, terms of service, and flexibility and reliability of service. Expansion or construction of competing gathering, processing, transmission, and storage systems and excess pipeline capacity would create additional competition for the services the Company provides to its customers.
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Further, natural gas utilized as a fuel competes with other forms of energy available to end-users. Increased demand for such other forms of energy at the expense of natural gas could lead to a reduction in demand for Altus’ midstream services and could intensify the negative impact of factors that decrease demand for natural gas in the markets served by the Company’s systems, such as adverse economic conditions, weather, higher fuel costs, and taxes or other governmental or regulatory actions. All of these competitive pressures could adversely affect the Company’s financial condition, results of operations, or cash flows.
Altus may not be able to retain or acquire new customers, which would reduce Altus’ revenues and limit its future profitability.
The renewal or replacement of the Company’s existing contracts with its customers at rates sufficient to maintain or increase current revenues and cash flows depends on a number of factors, some of which are beyond the Company’s control, including competition and the price of, and demand for, commodities in the markets Altus serves. The inability of the Company to renew or replace its current or future contracts as they expire could have a negative effect on its profitability.
Altus does not own in fee the land on which its assets are located, which could result in disruptions to its operations.
The Company does not own in fee any of the land on which its midstream assets have been constructed. Altus’ only interests in these properties are rights granted under surface use agreements, rights-of-way, surface leases, or other easement rights (collectively, Rights-of-Way), of which Apache and certain of its affiliates are a party, and such Rights-of-Way may limit or restrict Altus’ access to or use of the surface estates, which may adversely affect Altus’ operations. The Company is also subject to the possibility of more onerous terms or increased costs to retain necessary land use if Altus does not have valid Rights-of-Way or if such usage rights lapse or terminate. The loss of these rights could have a material adverse effect on the business, financial condition, results of operations, and cash flows of the Company.
A failure in Altus’ computer systems or a terrorist or cyberattack on Altus or third parties with whom Altus does business may adversely affect the Company’s ability to operate its business.
The Company is reliant on technology to conduct its business. The Company depends upon its operational and financial computer systems to process the data necessary to conduct almost all aspects of its business, including operating its pipelines and gathering and processing facilities, recording and reporting commercial and financial transactions, and receiving and making payments. Any failure of the Company’s computer systems or those of its customers, suppliers, or others with whom it does business, including Apache, could materially disrupt the Company’s ability to operate its business.
Cyberattacks against the Company may disrupt computer systems and operations and result in the theft of funds or data. In addition, the Company’s pipeline systems may be targets of terrorist attacks or environmental activist group activities that could disrupt Altus’ ability to conduct its business. Protecting against such threats may require the Company to expend significant additional resources, and any such attack or disruption could have a material adverse effect on Altus’ business and results of operations.
Altus’ business involves many hazards and operational risks, some of which may not be fully covered by insurance. The occurrence of a significant event that is not fully insured could adversely affect Altus’ operations and financial condition.
The Company’s operations are subject to the many hazards inherent in the gathering, compressing, processing, and transmission of natural gas and NGLs, including damage to pipelines, related equipment, and surrounding properties caused by hurricanes, floods, fires, explosions, freezes, other natural or anthropogenic disasters, acts of terrorism, and cyberattacks, leaks of natural gas, NGLs, and other hydrocarbons, and induced seismicity.
These risks could result in substantial losses due to personal injury and/or loss of life, severe damage to and destruction of property and equipment, including information technology systems, and pollution or other environmental damage and may result in curtailment or suspension of the Company’s related operations. In accordance with typical industry practice, Altus has appropriate levels of business interruption, property, and other insurance, but the Company is not fully insured against all risks incident to its business. If a significant accident or event occurs that is not fully insured, it could adversely affect Altus’ financial condition, results of operations, or cash flows.
RISKS RELATED TO THE EQUITY METHOD INTEREST PIPELINES AND OTHER NON-OPERATED ASSETS
Altus owns or operates a portion of its business with one or more equity interest partners or in circumstances where Altus is not the operator, including the Equity Method Interest Pipelines, which may restrict its operational and corporate flexibility; actions taken by other partners or third-party operators may materially impact the Company’s financial position and results of operations, and Altus may not realize the benefits it expects to realize from an equity interest.
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As is common in the midstream industry, Altus owns or operates one or more of its properties with one or more equity interest partners, including the Equity Method Interest Pipelines, or contracts with a third-party to control operations. These relationships require the Company to share operational and other control or to defer to another party’s control, such that it does not have the flexibility to control the development of these properties. If Altus does not timely meet its financial commitments in such circumstances, its rights to participate may be adversely affected. If an equity interest partner is unable or fails to pay its portion of development costs or if a third-party operator does not operate in accordance with the Company’s expectations, the Company’s costs of operations could be increased. Altus could also incur liability or not realize expected benefits as a result of actions taken by an equity interest partner or third-party operator. Actions taken by Apache may also negatively impact Altus’ ownership in or the expected benefits from such assets. Disputes between Altus and the other party or parties in an equity interest may result in litigation or arbitration that would increase the Company’s expenses, delay or terminate projects, and distract the Company’s officers and directors from focusing their time and effort on Altus’ business.
If any of the Equity Method Interest Pipelines experience cost overruns or do not generate the cash flows Altus expects, the Company’s plans for growth and dividends will be impaired.
The Company’s strategy to grow its business depends in part on the Equity Method Interest Pipelines. Altus can offer no assurance that the Equity Method Interest Pipelines will perform as expected. If applicable pipelines do not perform as expected, Altus may experience losses in relation to its equity interests. In addition, each of the Equity Method Interest Pipelines is subject to risks associated with cost over-runs, operational hazards, environmental matters, regulatory matters, creditworthiness of counterparties, and legal matters, as well as other risks and uncertainties, many of which are beyond the control of the operator of the pipeline. If any of these risks were to materialize, Altus’ financial condition, results of operations, and cash flows could be adversely affected.
RISKS RELATED TO THE VOLUME AND PROCESSING OF PRODUCTS THE COMPANY SERVICES
Altus is dependent on the supply of commodities to its system, and any decrease in such supply or the volumes that Altus gathers, processes, or transmits or any decrease in Altus’ processing efficiency would adversely affect its financial condition, results of operations, or cash flows.
The Company’s financial performance depends to a large extent on the volumes of natural gas and NGLs gathered, processed, and transmitted on its assets, and decreases in such volumes would directly and adversely affect its financial condition, results of operations, or cash flows. These volumes can be influenced by factors beyond Altus’ control, including regulations, weather, storage levels, increased use of alternative energy sources, decreased demand, and changes in production. The Company’s financial condition, results of operations, or cash flows may also be adversely affected if the reserves or estimates thereof reported by the Company’s customers, for which the Company does not obtain independent evaluations, is less than anticipated or if the infrastructure to gather and process supply into and out of the Company’s systems are unavailable or inadequate. If the Company is unable to maintain or increase the volumes on its system or if its processing efficiency falls below contractually required levels, the Company’s business, financial conditions, results of operations, or cash flows could be adversely affected.
The Company’s exposure to commodity price risk may change over time.
The Company currently generates substantially all of its midstream services revenue pursuant to fee-based contracts under which the Company is paid based on the volumes that it gathers, processes, and transmits, rather than the underlying value of the commodity, and only has an immaterial portion of its revenues that are based on the underlying value of a commodity. However, Altus may enter into contracts or may acquire or develop additional midstream assets in a manner that increases its exposure to commodity price risk, which could adversely affect Altus’ financial condition, results of operations, or cash flows.
RISKS RELATED TO CAPITAL EXPENDITURES
To maintain and grow its business, Altus is, and will be, required to make substantial capital expenditures.
To maintain and grow its business, Altus will need to make substantial capital expenditures to fund growth capital expenditures as well as its share of capital expenditures associated with the Equity Method Interest Pipelines. If the Company does not make sufficient or effective capital expenditures, it will be unable to maintain and grow its business, and, as a result, it may be unable to increase its cash flow over the long term. To fund Altus’ capital expenditures, it will be required to use cash from its operations, incur debt, engage in structured financial transactions, or sell additional shares of Class A Common Stock or other equity securities.
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Additionally, the Company’s ability to obtain bank financing or its ability to access the capital markets for future equity or debt offerings may be limited by its then-current financial condition and the covenants in its then-current debt agreements, as well as by general economic conditions and uncertainties that are beyond its control. Also, due to Altus’ relationship with Apache, material adverse changes affecting Apache could negatively impact the Company’s ability to access the capital markets, including the pricing or other terms of any capital markets transactions, or engage in certain transactions that might otherwise be considered beneficial to the Company.

The capital and global credit markets have experienced volatility and disruption in the past, and further volatility and disruption may have an adverse effect on Altus’s ability to access the credit markets to finance its operations or expansions.
The capital and global credit markets have experienced volatility and disruption in the past. In many cases during these periods, the capital markets have exerted downward pressure on equity values and reduced the credit capacity for certain companies. Similar or more severe levels of global market disruption and volatility may have an adverse effect on Altus resulting from, but not limited to, disruption of Altus’ access to capital and credit markets, difficulty in obtaining financing necessary to expand facilities or acquire assets, increased financing costs, and increasingly restrictive covenants.
If Altus is unable to access capital at competitive rates, the Company’s strategy of enhancing the earnings potential of its existing assets, including through capital-growth projects and acquisitions of complementary assets or businesses, may be affected adversely.
RISKS RELATED TO THE COMPANY’S FINANCIAL CONDITION AND OBLIGATIONS
Debt Altus incurs may limit its flexibility to obtain financing and to pursue other business opportunities.
The Company’s current and future level of debt could have important consequences to it, and the Company’s ability to obtain additional financing, if necessary, for working capital, capital expenditures, or other purposes may be impaired or such financing may not be available on favorable terms. The funds available for operations, future business opportunities, and the payment of dividends, if any, to the Company’s stockholders will be reduced by that portion of its cash flows required to make interest payments on its debt, and the Company may be more vulnerable to competitive pressures or a downturn in its business or the economy generally.
Altus’ ability to service any debt will depend upon, among other things, its future financial and operating performance, which will be affected by prevailing economic conditions and other factors, some of which are beyond its control. If the Company’s operating results are not sufficient to service any future indebtedness, it will be forced to take actions such as reducing or eliminating dividends, reducing or delaying its business activities, investments, or capital expenditures, selling assets, or issuing equity. Altus may not be able to effect any of these actions on satisfactory terms or at all.
The discontinuation and uncertain cessation date of LIBOR, and the adoption of an alternative reference rate, may have a material adverse impact on Altus Midstream’s floating rate indebtedness and financing costs.
Pursuant to the terms of Altus Midstream’s revolving credit facility, Altus Midstream may elect to use the London Interbank Offering Rate (LIBOR) as a benchmark for establishing the interest rate on floating interest rate borrowings under its revolving credit facility. On November 30, 2020, the ICE Benchmark Administration (IBA) announced that it intends to continue publishing LIBOR until the end of June 2023, beyond the previously announced 2021 cessation date. The IBA announcement was supported by announcements from the United Kingdom’s Financial Conduct Authority (FCA), which regulates LIBOR, and the Board of Governors of the Federal Reserve System, Federal Deposit Insurance Corporation, and Office of the Comptroller of the Currency (U.S. Regulators). However, both the FCA and U.S. Regulators in their announcements also advised banks to cease entering into new contracts referencing LIBOR after December 2021. These announcements indicate that the continuation of LIBOR in existing contracts may not be assured after 2021 and will not be assured beyond 2023. In light of these recent announcements, the future of LIBOR at this time is uncertain, and any changes in the methods by which LIBOR is determined or regulatory activity related to LIBOR’s phase-out could cause LIBOR to perform differently than in the past or cease to exist.
In the United States, the Alternative Reference Rates Committee (the working group formed to recommend an alternative rate to LIBOR) has identified the Secured Overnight Financing Rate (SOFR) as its preferred alternative rate for LIBOR. There can be no guarantee that SOFR will become a widely-accepted benchmark in place of LIBOR. Although the full impact of the transition away from LIBOR, including the discontinuance of LIBOR publication and the adoption of SOFR as the replacement rate for LIBOR, remains unclear, these changes may have an adverse impact on Altus Midstream’s floating rate indebtedness and financing costs under its revolving credit facility.
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Altus is exposed to the credit risk of its customers and counterparties, including Apache, and their nonpayment or nonperformance could have an adverse effect on the Company’s financial condition, results of operations, or cash flows.
The Company is subject to risks of loss resulting from nonpayment or nonperformance by its customers or other counterparties, including Apache. Any increase in the nonpayment or nonperformance by such parties could adversely affect Altus’ financial condition, results of operations, or cash flows. Additionally, the combination of a reduction of cash flow resulting from lower commodity prices, a reduction in borrowing bases under reserve-based credit facilities, and the lack of availability of debt or equity financing may result in a significant reduction in the liquidity of such parties and their ability to make payment or perform on their obligations to the Company. Furthermore, some of the Company’s customers or other counterparties may be leveraged and subject to their own operating and regulatory risks, which increases the risk that they may default.
Altus may be required to take write-downs, write-offs, or restructuring and impairment or other charges that could have a significant negative effect on its financial condition, results of operations, and stock price.
Altus cannot assure its stockholders that its due diligence will reveal all material issues that may be present in the businesses that it may acquire, that it would be possible to uncover all material issues through a customary amount of due diligence, or that factors outside of its control will not later arise. As a result, Altus may be forced to later write down or write off assets, restructure its operations, or incur impairment or other charges that could result in losses. Even though these charges may be non-cash items and may not have an immediate impact on the Company’s liquidity, the fact that it reports charges of this nature could contribute to negative market perceptions about the Company or its securities.
The Company’s ability to utilize net operating losses and other tax attributes to reduce future taxable income may be limited if the Company experiences an ownership change.
As described in Note 12—Income Taxes within Part II, Item 8 of this Annual Report on Form 10-K, the Company has substantial net operating loss carryforwards (NOLs) and other tax attributes available to potentially offset future taxable income. If the Company were to experience an “ownership change” under Section 382 of the Internal Revenue Code of 1986, as amended, which is generally defined as a greater than 50 percentage point change, by value, in the Company’s equity ownership by five-percent shareholders over a three-year period, the Company’s ability to utilize its pre-change NOLs and other pre-change tax attributes to potentially offset its post-change income or taxes may be limited. Such a limitation could materially adversely affect the Company’s operating results or cash flows by effectively increasing its future tax obligations.
Altus’ ability to pay dividends depends on its ability to generate sufficient cash flow, which it may not be able to accomplish.
The Company’s ability to pay dividends principally depends upon the amount of cash it generates from its operations, which will fluctuate from quarter to quarter based on, among other things, income from the Equity Method Interest Pipelines, the volumes of natural gas and NGLs it gathers and processes, commodity prices, and other factors impacting Altus’ financial condition, some of which are beyond its control. In addition, under Delaware law, dividends on Altus’ capital stock may only be paid from “surplus,” which is the amount by which the fair value of Altus’ total assets exceeds the sum of its total liabilities, including contingent liabilities, and the amount of its capital; if there is no surplus, cash dividends on capital stock may only be paid from Altus’ net profits for the then-current and/or the preceding fiscal year.
Altus’ only significant assets are ownership of the non-economic general partner interest and an approximate 23.1 percent limited partner interest in Altus Midstream LP, and such ownership may not be sufficient for Altus Midstream LP to make distributions or loans to Altus to enable it to pay any dividends or satisfy its other financial obligations.
Altus has no direct operations and no significant assets other than the ownership of the non-economic general partner interest and an approximate 23.1 percent limited partner interest in Altus Midstream LP. The Company depends on Altus Midstream LP for distributions, loans, and other payments to generate the funds necessary to meet its financial obligations and to pay dividends with respect to its Class A Common Stock. Subject to certain restrictions, Altus Midstream LP generally will be required to (i) make pro rata distributions to its partners, including the Company, on a quarterly basis in an amount at least sufficient to allow the Company to pay the Company’s taxes and make tax advances to Altus Midstream LP’s limited partners, other than the Company, in certain circumstances, and (ii) reimburse the Company for certain corporate and other overhead expenses. However, legal and contractual restrictions in agreements governing existing and future indebtedness of Altus Midstream LP, as well as the financial condition and operating requirements of Altus Midstream LP, may limit the Company’s ability to obtain cash from Altus Midstream LP. In addition, Altus Midstream LP is required to pay specified quarterly distributions on its Series A Cumulative Redeemable Preferred Units before paying distributions on Common Units. The earnings from, or other available assets of, Altus Midstream LP may not be sufficient to make distributions or loans to the Company, to enable it to pay dividends on its Class A Common Stock, or to satisfy its other financial obligations. The Delaware
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Revised Uniform Limited Partnership Act generally restricts distributions to the extent that the liabilities of the limited partnership exceed the fair value of its assets.
Holders of Altus Midstream’s Series A Cumulative Redeemable Preferred Units have rights, preferences, and privileges that are not held by, and are preferential to the rights of, holders of Common Units, and could dilute or otherwise adversely affect the holders of Common Units.
Altus Midstream is required to pay specified quarterly distributions on the Series A Cumulative Redeemable Preferred Units (the Preferred Units) before paying distributions on its Common Units. If Altus Midstream fails to pay the Preferred Unit distribution in respect of any quarter in full in cash, then Altus Midstream will not be permitted to declare or make any distributions on its Common Units until all accrued and accumulated but unpaid Preferred Unit distributions have been paid in full. In addition, Altus Midstream’s cash payment of distributions on, and for redemption of, its Common Units is limited in amount and subject to satisfaction of leverage ratios.
The Preferred Units are redeemable at any time at the option of Altus Midstream and under certain circumstances, the Preferred Units are redeemable at the holders’ option, in each case, at a price which incorporates an agreed return on the holders’ investment. The Preferred Units also rank senior to the Common Units in distribution and liquidation rights, and holders of Preferred Units will be entitled to receive a liquidation preference that incorporates an agreed return on the holders’ investment.
The Company depends on Altus Midstream for distributions, loans, and other payments to generate the funds necessary to meet the Company’s financial obligations or to pay any dividends with respect to its Class A Common Stock. Obligations of Altus Midstream in respect of the Preferred Units may restrict, reduce, or render unavailable funds that otherwise may be available to be distributed, loaned, or paid to the Company by Altus Midstream or loaned to, or invested in, Altus Midstream by third parties.
For additional information regarding the Preferred Units, refer to Note 11—Series A Cumulative Redeemable Preferred Units within Part IV, Item 15 of this Annual Report on Form 10-K.
RISKS RELATED TO PERMITTING, REGULATIONS, AND OTHER LEGAL CHANGES
Altus may be unable to obtain or renew permits necessary for its operations, which could inhibit its ability to do business.
Performance of the Company’s operations require that it obtain and maintain a number of federal, state, and local permits, licenses, and approvals, which is an expensive and lengthy process, with terms and conditions containing a significant number of prescriptive limits and performance standards in order to operate. All of these permits, licenses, approvals, limits, and standards require a significant amount of monitoring, record keeping, and reporting. Noncompliance or incomplete documentation may result in the imposition of fines, penalties, and injunctive relief. Moreover, the public may engage in the permitting process, including through intervention in the courts. Negative public perception could cause the permits Altus requires to conduct its operations to be withheld, delayed, or burdened by restrictive requirements. A decision by a government agency to deny or delay the issuance of a new or existing material permit or other approval or to revoke or substantially modify an existing permit or other approval could adversely affect the Company’s financial condition, results of operations, or cash flows.
Altus is subject to regulation by multiple governmental agencies, which could adversely impact its business, results of operations, and financial condition.
The Company is subject to regulation by multiple federal, state, and local governmental agencies, including those related to pipeline and environmental safety, and regulation by the stock exchange on which its common stock is listed. Proposals and proceedings that could affect the Company or its industry are regularly considered by Congress, as well as by state legislatures and federal and state regulatory commissions, agencies, and courts and stock exchanges. The Company cannot predict when or whether any such proposals or proceedings may become effective or the magnitude of the impact changes in or interpretations of laws, regulations, and exemptions may have on its business. However, additions to the regulatory burden on the Company and the midstream industry can increase the Company’s cost of doing business and affect its profitability.

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Altus may become subject to the requirements of the Investment Company Act of 1940, which would limit its business operations and require it to spend significant resources to comply with such act.
The Investment Company Act of 1940 (the Investment Company Act) defines an “investment company” as an issuer that is engaged in the business of investing, reinvesting, owning, holding, or trading in securities and owns investment securities having a value exceeding 40 percent of the issuer’s unconsolidated assets, excluding cash items and securities issued by the federal government. It is possible that some or all of the interests in the Equity Method Interest Pipelines may be investment securities and that the value of those interests that are investment securities over time may exceed 40 percent of the applicable subsidiaries’ unconsolidated assets, excluding cash and government securities, in which case such subsidiaries may meet this threshold definition of an investment company. However, the Investment Company Act provides certain exclusions from this definition and other alternative relief from the application of the Investment Company Act.
The ramifications of becoming an investment company, both in terms of the restrictions it would have on such subsidiary and the cost of compliance, would be significant. For example, in addition to expenses related to initially registering as an investment company, the Investment Company Act also would impose various restrictions with regard to the subsidiary’s ability to enter into affiliated transactions, the diversification of its assets, and its ability to borrow money. If any of Altus’ subsidiaries became subject to the Investment Company Act at some point in the future, then the subsidiary’s ability to continue pursuing its business plan would be severely limited.
Unanticipated changes in effective tax rates or adverse outcomes resulting from examination of Altus’ income or other tax returns could adversely affect its financial condition and results of operations.
Altus is subject to income taxes in the United States, and its domestic tax liabilities may be subject to the allocation of expenses in differing jurisdictions. Altus’ future effective tax rates could be subject to volatility or adversely affected by a number of factors, including changes in the valuation of Altus’ deferred tax assets and liabilities, expected timing and amount of the release of any tax valuation allowances, tax effects of stock-based compensation, costs related to intercompany restructurings, changes in tax laws, regulations, or interpretations thereof, or lower than anticipated future earnings in jurisdictions where Altus has lower statutory tax rates and higher than anticipated future earnings in jurisdictions where Altus has higher statutory tax rates.
In addition, Altus may be subject to audits of its income, franchise, sales, and other transaction taxes by U.S. federal and state authorities. Outcomes from these audits could have an adverse effect on the Company’s financial condition and results of operations.
RISKS RELATED TO CLIMATE CHANGE

Climate change legislation, and regulatory initiatives could result in increased operating costs and reduced demand for the natural gas and NGLs services the Company provides.

Legislative bodies and governmental agencies have from time to time considered or adopted legislation or regulations to reduce emissions of GHGs. Wide-ranging policy debates regarding the impact of these gases and possible means for their regulation, along with efforts toward the adoption of international treaties or protocols that would address global climate change issues, are ongoing. Numerous proposals have been made and could continue to be made at the national, regional, and state levels of government to monitor and limit existing emissions of GHGs as well as to restrict or eliminate such future emissions. Moreover, on January 27, 2021, the President issued an executive order that commits to substantial action on climate change, calling for, among other things, the increased use of zero-emissions vehicles by the federal government, the elimination of subsidies provided to the fossil fuel industry, and increased emphasis on climate-related risk across governmental agencies and economic sectors. Any such legislation or regulation, if enacted, could either tax or assess some form of GHG-related fees on the Company’s operations and could lead to increased operating expenses or result in the Company making significant capital investments for infrastructure modifications.

Additionally, various states and groups of states have adopted or are considering adopting legislation, regulations or other regulatory initiatives that are focused on such areas as GHG cap-and-trade programs, carbon taxes, reporting and tracking programs, restriction of emissions, electric vehicle mandates, and combustion engine phaseouts. Any such legislation or regulatory programs could also increase the cost of consuming, and thereby reduce demand for, oil, natural gas, and NGLs. Additionally, political, litigation, and financial risks related to climate change may result in curtailed refinery activity, increased regulation, or other adverse direct and indirect effects on the Company’s business, financial condition and results of operations. For example, there is a risk that financial institutions will be required to adopt policies that have the effect of reducing the funding provided to the fossil fuel sector. Recently, the Federal Reserve announced that it has joined the Network for Greening the Financial System, a consortium of financial regulators focused on addressing climate-related risks in the financial sector.
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Although it is not possible at this time to predict whether legislation or regulations may be adopted to address GHG emissions or how such measures would impact the Company’s business, the imposition of reporting or permitting obligations on, or limiting emissions of GHGs from, Altus’ equipment and operations could require the Company to incur additional costs, adversely affect its performance of operations, or adversely affect demand for the Company’s services.

Altus’ customers, including Apache, and suppliers are subject to the risk of increased federal, state, and local legislation and regulatory initiatives, which could adversely affect Altus’ financial condition, results of operations, or cash flows.

The production of crude oil, natural gas, and NGLs by the Company’s customers, including Apache, and the Company’s suppliers are subject to regulation by multiple federal, state, and local governmental agencies, which may enact additional or more restrictive or onerous regulations, including those that may further regulate, restrict, or prohibit certain drilling methods, including hydraulic fracturing, or impose additional permit requirements and operational restrictions, such as a reduction or prohibition of venting or flaring, in certain jurisdictions or in environmentally sensitive areas. If additional levels of regulation and permits are required, that could lead to delays, increased operating costs, and process prohibitions for the Company’s suppliers and customers that could reduce the volumes of natural gas and NGLs that move through the Company’s systems, which could materially adversely affect its revenue and results of operations.
RISKS RELATED TO THE COMPANY’S OWNERSHIP AND FILING STATUS
Altus is a “controlled company” within the meaning of the Nasdaq listing rules and, as a result, qualifies for, and intends to rely on, exemptions from certain corporate governance requirements.
Because Apache and its affiliates control a majority of Altus’ outstanding voting common stock, Altus is a controlled company within the meaning of the Nasdaq corporate governance standards. Under the Nasdaq listing rules, a controlled company may elect not to comply with certain Nasdaq corporate governance requirements, including the requirements that a majority of the board of directors consist of independent directors, the nominating and governance committee be composed entirely of independent directors, and the compensation committee be composed entirely of independent directors. These requirements will not apply to Altus as long as it remains a controlled company, and Altus currently utilizes and intends to continue to utilize some, if not all, of these exemptions. Accordingly, Altus’ stockholders may not have the same protections afforded to stockholders of companies that are subject to all of the corporate governance requirements of the Nasdaq listing rules.
The JOBS Act permits “emerging growth companies” like Altus to take advantage of certain exemptions from various reporting requirements applicable to other public companies that are not emerging growth companies.
Altus qualifies as an “emerging growth company” as defined in Section 2(a)(19) of the Securities Act, as modified by the Jumpstart Our Business Startups Act of 2012 (the JOBS Act). As such, Altus is eligible to take advantage of certain exemptions from various reporting requirements that are applicable to other public companies that are not emerging growth companies and of extended transition periods for as long as Altus continues to be an emerging growth company, including:

•the exemption from the independent registered public accounting firm attestation requirements with respect to internal control over financial reporting under Section 404 of the Sarbanes-Oxley Act;
•the exemptions from say-on-pay, say-on-frequency, and say-on-golden parachute voting requirements;
•an extended transition period for complying with new or revised accounting standards; and
•reduced disclosure obligations regarding executive compensation in Altus’ periodic reports and proxy statements.
As a result, Altus’ stockholders may not have access to certain information they deem important and may not be able to directly compare the Company’s financial statements with another public company that is neither an emerging growth company nor an emerging growth company that has opted out of using the extended transition period, because of the potential differences in accounting standards used. Altus cannot predict if investors will find its Class A Common Stock less attractive if it relies on these exemptions. If some investors find Altus’ Class A Common Stock less attractive as a result, there may be a less active trading market for its Class A Common Stock, and its stock price may be more volatile.
RISKS RELATED TO THE COMPANY’S WARRANTS
Although Altus has registered the shares of Class A Common Stock issuable upon exercise of the warrants under the Securities Act, such registration may not be in place when an investor desires to exercise warrants, thus precluding such
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investor from being able to exercise its warrants except on a cashless basis and potentially causing such warrants to expire worthless.
Although Altus has registered the shares of Class A Common Stock issuable upon exercise of the warrants under the Securities Act, it may not be able to maintain a current prospectus relating to the Class A Common Stock issuable upon exercise of the warrants until the expiration of the warrants in accordance with the provisions of the warrant agreement. Altus cannot assure holders that it will be able to do so if, for example, any facts or events arise which represent a fundamental change in the information set forth in such registration statement or prospectus, the financial statements contained or incorporated by reference therein are not current or correct, or the SEC issues a stop order. If the shares issuable upon exercise of the warrants are not registered under the Securities Act, Altus will be required to permit holders to exercise their warrants on a cashless basis.
However, no warrant will be exercisable for cash or on a cashless basis, and Altus will not be obligated to issue any shares to holders seeking to exercise their warrants, unless the issuance of the shares upon such exercise is registered or qualified under the securities laws of the state of the exercising holder or an exemption is available.
Notwithstanding the above, if Altus’ Class A Common Stock is at the time of any exercise of a warrant not listed on a national securities exchange such that it satisfies the definition of a “covered security” under Section 18(b)(1) of the Securities Act, Altus may, at its option, require holders of warrants who exercise their warrants to do so on a “cashless basis” in accordance with Section 3(a)(9) of the Securities Act, and, in the event Altus so elects, it will not be required to file or maintain in effect a registration statement, but it will use its best efforts to register or qualify the shares under applicable blue sky laws to the extent an exemption is not available. In no event will Altus be required to net cash settle any warrant or issue securities or other compensation in exchange for the warrants in the event that it is unable to register or qualify the shares underlying the warrants under applicable state securities laws. If the issuance of the shares upon exercise of the warrants is not so registered or qualified or exempt from registration or qualification, the holder of such warrant shall not be entitled to exercise such warrant, and such warrant may have no value and expire worthless. If and when the warrants become redeemable by Altus, it may exercise its redemption right even if it is unable to register or qualify the underlying shares of Class A Common Stock for sale under all applicable state securities laws.
Altus may amend the terms of the warrants in a manner that may be adverse to holders with the approval by the holders of at least 50 percent of the then-outstanding public warrants. As a result, the exercise price of your public warrants could be increased, the exercise period could be shortened, and the number of shares of Altus’ Class A Common Stock purchasable upon exercise of a public warrant could be decreased, all without your approval.
Altus’ public warrants were issued in connection with its initial public offering in registered form under a warrant agreement between American Stock Transfer & Trust Company, as warrant agent, and Altus. The warrant agreement provides that the terms of the warrants may be amended without the consent of any holder to cure any ambiguity or correct any defective provision, but requires the approval by the holders of at least 50 percent of the then-outstanding public warrants to make any change that adversely affects the interests of the registered holders. Accordingly, Altus may amend the terms of the public warrants in a manner adverse to a holder if holders of at least 50 percent of the then-outstanding public warrants approve of such amendment. Although Altus’ ability to amend the terms of the public warrants with the consent of at least 50 percent of the then-outstanding public warrants is unlimited, examples of such amendments could be amendments to, among other things, increase the exercise price of the public warrants, shorten the exercise period, or decrease the number of shares of Altus’ Class A Common Stock purchasable upon exercise of a public warrant.
There is no guarantee that Altus’s warrants will ever be in the money prior to their expiration, and Altus may redeem unexpired warrants prior to their exercise at a time that is disadvantageous to warrant holders, thereby making the warrants worthless.
The exercise price for Altus’ warrants is $230.00 per share of Class A Common Stock. There is no guarantee that the public warrants will ever be in the money prior to their expiration, and, as such, the warrants may expire worthless.
Additionally, Altus has the ability to redeem outstanding warrants at any time prior to their expiration, at a price of $0.01 per warrant, provided that the last reported sales price of its Class A Common Stock equals or exceeds $360.00 per share for any 20 trading days within a 30 trading-day period ending on the third trading day prior to the date Altus sends the notice of redemption to the warrant holders. If and when the warrants become redeemable by Altus, it may exercise its redemption right even if it is unable to register or qualify the underlying securities for sale under all applicable state securities laws.
Redemption of the outstanding warrants could force the warrant holders to exercise their warrants and pay the exercise price therefor at a time when it may be disadvantageous for them to do so, sell their warrants at the then-current market price
21

when they might otherwise wish to hold their warrants, or accept the nominal redemption price which, at the time the outstanding warrants are called for redemption, is likely to be substantially less than the market value of their warrants.
RISKS RELATED TO STOCK OWNERSHIP DILUTION
The warrants are exercisable for Altus’ Class A Common Stock, which will, upon exercise, increase the number of shares eligible for future resale in the public market and result in dilution to Altus’ stockholders.
Altus has outstanding public and private placement warrants to purchase shares of Class A Common Stock. To the extent such warrants are exercised, additional shares of Class A Common Stock will be issued, which will result in dilution to the then-existing holders of Altus’ Class A Common Stock and increase the number of shares eligible for resale in the public market, which could adversely affect the market price of Altus’ Class A Common Stock.
In the future, Apache may receive earn-out consideration in the form of shares of Class A Common Stock upon the achievement of certain stock price and operational goals, which would increase the number of shares eligible for future resale in the public market and result in dilution to Altus’ stockholders.
Pursuant to the Altus Contribution Agreement, Apache will have the right to receive earn-out consideration in the form of additional shares of Class A Common Stock if certain stock price and operational goals are achieved. To the extent such stock price or operational goals are achieved and Apache becomes entitled to receive a portion or all of the earn-out consideration, additional shares of Class A Common Stock will be issued, which will result in dilution to the then-existing holders of Class A Common Stock and increase the number of shares eligible for resale in the public market. The shares of Class A Common Stock issuable to Apache as earn-out consideration have been registered for resale with the SEC. Sales of substantial numbers of such shares by Apache in the public market could adversely affect the market price of Class A Common Stock.
The Preferred Units may be exchanged for shares of Altus’ Class A Common Stock at a discount under certain circumstances, which could be dilutive to existing holders of its Class A Common Stock.
The Preferred Units may be exchanged for shares of Altus’ Class A Common Stock at a discount under certain circumstances, which could be dilutive to existing holders of its Class A Common Stock. The number of shares of Class A Common Stock issued in any exchange would be based on its then-current trading price. Accordingly, the lower the trading price of Altus’ Class A Common Stock at the time of any exchange, the greater the number of shares of Class A Common Stock that would be issued upon exchange of the Preferred Units, increasing potential dilution to existing holders of Altus’ Class A Common Stock. Further, if the former holders of Preferred Units dispose of a substantial portion of their newly-exchanged Class A Common Stock in the public market, particularly over a short time period, it could adversely affect the market price for Altus’ Class A Common Stock and possibly make it more difficult for Altus to issue additional Class A Common Stock in the future at an attractive price.
A significant portion of Altus’ total outstanding shares may be sold into the market in the near future. This could cause the market price of its Class A Common Stock to drop significantly, even if its business is doing well.
Sales of a substantial number of shares of Class A Common Stock in the public market could occur at any time. These sales, or the perception in the market that the holders of a large number of shares intend to sell shares, could reduce the market price of Altus’ Class A Common Stock. Additionally, Apache’s Common Units have been exchanged for shares of Class A Common Stock on a one-for-one basis. The shares of Class A Common Stock issued to Apache upon such exchange have been registered for resale with the SEC. Sales of substantial numbers of such shares by Apache in the public market could adversely affect the market price of Altus’ Class A Common Stock.
RISKS RELATED TO RESTRICTIONS ON STOCKHOLDER ACTIONS
Altus’ charter designates the Court of Chancery of the State of Delaware as the sole and exclusive forum for certain types of actions and proceedings that may be initiated by its stockholders, which could limit its stockholders’ ability to obtain a favorable judicial forum for disputes with Altus or its directors, officers, employees, or agents.
The charter provides that, unless Altus consents in writing to the selection of an alternative forum, the Court of Chancery of the State of Delaware (Court of Chancery) will, to the fullest extent permitted by applicable law, be the sole and exclusive forum for any derivative action or proceeding brought on the Company’s behalf; any action asserting a claim of breach of a fiduciary duty owed by any of the Company’s directors, officers, or other employees to it or its stockholders; any action asserting a claim against the Company or any of its directors, officers, or employees arising pursuant to any provision of the DGCL, the charter, or the Company’s bylaws; or any action asserting a claim against the Company or any of its directors, officers, or other employees that is governed by the internal affairs doctrine.
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The above does not apply for such claims as to which the Court of Chancery determines that it does not have personal jurisdiction over an indispensable party, exclusive jurisdiction is vested in a court or forum other than the Court of Chancery, or the Court of Chancery does not have subject matter jurisdiction.
Any person or entity purchasing or otherwise acquiring any interest in shares of the Company’s capital stock will be deemed to have notice of, and consented to, the provisions of Altus’ charter described in the preceding sentence. This exclusive forum provision may limit a stockholder’s ability to bring a claim in a judicial forum that the stockholder finds favorable for disputes with the Company or its directors, officers, or other employees, which may discourage such lawsuits against the Company and such persons. Alternatively, if a court were to find these provisions of Altus’ charter inapplicable to, or unenforceable in respect of, one or more of the specified types of actions or proceedings, the Company may incur additional costs associated with resolving such matters in other jurisdictions, which could adversely affect its business, financial condition, or results of operations.
Altus’ charter provides that the exclusive forum provision will be applicable to the fullest extent permitted by applicable law. Section 27 of the Exchange Act creates exclusive federal jurisdiction over all suits brought to enforce any duty or liability created by the Exchange Act or the rules and regulations thereunder. Accordingly, the charter provides that the exclusive forum provision will not apply to suits brought to enforce any liability or duty created by the Exchange Act, the Securities Act, or any other claim for which the federal courts have exclusive jurisdiction.
GENERAL RISK FACTORS
If Altus fails to maintain an effective system of internal controls, it may not be able to report accurately its financial results or prevent fraud. As a result, current and potential holders of the Company’s equity could lose confidence in its financial reporting, which would harm its business and cost of capital.
Effective internal controls are necessary for Altus to provide reliable financial reports, prevent fraud, and operate successfully as a public company. The Company cannot be certain that its efforts to maintain its internal controls will be successful, that it will be able to maintain adequate controls over its financial processes and reporting in the future, or that it will be able to continue to comply with its obligations under Section 404 of the Sarbanes-Oxley Act of 2002. Any failure to maintain effective internal controls or to implement or improve the Company’s internal controls could harm its operating results or cause it to fail to meet its reporting obligations. Ineffective internal controls could also cause investors to lose confidence in the Company’s reported financial information, which would likely have a negative effect on the trading price of its equity interests.
If the performance of the Company does not meet the expectations of investors, stockholders, or financial analysts, the market price of Altus’ securities may decline.
The price of the Company’s securities could be volatile and subject to wide fluctuations in response to various factors, some of which are beyond the Company’s control, and such fluctuations could contribute to the loss of all or part of a stockholder’s investment. Fluctuations or changes in the Company’s quarterly financial results, changes in or failure to meet market or financial analysts’ expectations about the Company, changes in laws and regulations, commencement of or involvement in litigation, changes in the Company’s capital structure, and general economic and political conditions could have a material adverse effect on a stockholder’s investment in the Company’s securities, and its securities may trade at prices significantly below the price paid for them. In such circumstances, the trading price of the Company’s securities may not recover and may experience a further decline.
Broad market and industry factors may materially harm the market price of the Company’s securities irrespective of Altus’ operating performance. The stock market in general and Nasdaq have experienced price and volume fluctuations that have often been unrelated or disproportionate to the operating performance of the particular companies affected. The trading prices and valuations of these stocks and of the Company’s securities may not be predictable. A loss of investor confidence in the market for retail stocks or the stocks of other companies which investors perceive to be similar to the Company could depress the Company’s stock price regardless of its business, prospects, financial conditions, or results of operations.

ITEM 1B. UNRESOLVED STAFF COMMENTS

None.

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ITEM 3. LEGAL PROCEEDINGS
For further information regarding legal proceedings, see Note 8—Commitments and Contingencies in the Notes to Consolidated Financial Statements set forth in Part IV, Item 15 of this Annual Report on Form 10-K.

ITEM 4. MINE SAFETY DISCLOSURES
None.
24

PART II

ITEM 5. MARKET FOR THE REGISTRANT’S COMMON EQUITY, RELATED STOCKHOLDER MATTERS, AND ISSUER PURCHASES OF EQUITY SECURITIES
Market Information
The Company’s common units (Units), Class A Common Stock, and warrants were each traded on the Nasdaq under the symbols “KAACU,” “KAAC,” and “KAACW,” respectively, prior to the closing of the Altus Combination. In connection with the closing of the Altus Combination, the Units ceased trading, and the Class A Common Stock and warrants began trading on the Nasdaq under the symbols “ALTM” and “ALTMW,” respectively. The Company’s Units commenced public trading on March 30, 2017, and the Class A Common Stock and warrants commenced public trading on April 27, 2017.
The Company’s warrants ceased trading on the Nasdaq at the opening of business on December 20, 2018 and since that time have been quoted on the over-the-counter markets operated by OTC Markets Group under the symbol “ALTMW.” The warrants may still be exercised in accordance with their terms to purchase shares of the Company’s Class A Common Stock. The table below sets forth the high and low prices of the warrants, as reported on the OTC Marketplace, for each of the quarterly periods presented. Such quotations reflect inter-dealer prices, without retail mark-up, mark-down, or commission and may not necessarily represent actual transactions.

	Year Ended December 31,	
	2021		2020	
	High		Low		High		Low	
First Quarter	$	0.10 			$	0.03 			$	0.15 			$	0.01 		
Second Quarter	$	0.07 			$	0.03 			$	0.04 			$	— 		
Third Quarter	$	0.06 			$	0.02 			$	0.05 			$	0.01 		
Fourth Quarter	$	0.07 			$	0.01 			$	0.12 			$	0.01 		
On January 31, 2022, the Class A Common Stock had a closing price of $63.03, and the warrants had a closing price of $0.01.
Holders
On January 31, 2022, there were 121 holders of record of the Company’s Class A Common Stock and there was no Class C Common Stock outstanding.
Dividends
Altus has paid cash dividends on its Class A Common Stock each quarter in 2021 at a rate of $1.50 per share. When, and if, declared by the Company’s board of directors, future dividend payments will depend upon our level of earnings, financial requirements, and other relevant factors.
Securities Authorized for Issuance Under Equity Compensation Plans
Information about the Company’s equity compensation plans is incorporated herein by reference to Altus’ definitive proxy statement for its 2022 Annual Meeting of Stockholders.
Recent Sales of Unregistered Securities
None.
Purchase of Equity Securities by the Issuer and Affiliated Purchasers
None.
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Performance Graph
The following stock price performance graph is intended to allow review of stockholder returns, expressed in terms of the performance of the Company’s common stock relative to both a broad equity market index and a published industry index. The information is included for historical comparative purposes only and should not be considered indicative of future stock performance. The graph compares the yearly percentage change in the cumulative total stockholder return on the Company’s Class A Common Stock with the cumulative total return of both the Nasdaq Composite Index and the Alerian US Midstream Energy Index from April 30, 2017 through December 31, 2021. The stock performance graph and related information shall not be deemed “soliciting material” or to be “filed” with the SEC, nor shall information be incorporated by reference into any future filing under the Securities Act or Exchange Act, each as amended, except to the extent that the Company specifically incorporates it by reference into such filing.

COMPARISON OF 56 MONTH CUMULATIVE TOTAL RETURN*
Among Altus Midstream Company, the Nasdaq Composite Index,
and the Alerian US Midstream Energy Index

* $100 invested on 5/2/17 in stock or 4/30/17 in index, including reinvestment of dividends.
Fiscal year ending December 31.

	5/2/2017		2017		2018		2019		2020		2021	
Altus Midstream Company	$	100.00 			$	100.10 			$	79.69 			$	29.48 			$	24.46 			$	34.82 		
Nasdaq Composite Index	100.00 			114.59 			110.42 			152.76 			221.37 			270.47 		
Alerian US Midstream Energy Index	100.00 			93.29 			83.11 			96.05 			72.08 			104.52 		

ITEM 6. SELECTED FINANCIAL DATA
Omitted.
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ITEM 7. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS
The following discussion and analysis should be read together with the Consolidated Financial Statements and the Notes to Consolidated Financial Statements set forth in Part IV, Item 15 of this Annual Report on Form 10-K, and the risk factors and related information set forth in Part I, Item 1A and Part II, Item 7A of this Annual Report on Form 10-K. This section of this Annual Report on Form 10-K generally discusses 2021 and 2020 items and year-to-year comparisons between 2021 and 2020. Discussions of 2019 items and year-to-year comparisons between 2020 and 2019 that are omitted in this Annual Report on Form 10-K are incorporated by reference to “Management’s Discussion and Analysis of Financial Condition and Results of Operations” in Exhibit 99.1 of the Company’s Current Report on Form 8-K, filed on December 14, 2021.
Overview
Altus Midstream Company (the Company or Altus), through its ownership interest in Altus Midstream LP (Altus Midstream), owns gas gathering, processing, and transmission assets in the Permian Basin of West Texas, anchored by midstream service agreements to service Apache Corporation’s (Apache) production from its Alpine High resource play and surrounding areas (Alpine High). Additionally, the Company owns equity interests in four intrastate Permian Basin pipelines (the Equity Method Interest Pipelines) that have access to various points along the Texas Gulf Coast. The Company’s operations consist of one reportable segment.
The Company has no independent operations or material assets outside its ownership interest in Altus Midstream, which is reported on a consolidated basis. As of December 31, 2021, Altus Midstream’s assets included approximately 182 miles of in-service natural gas gathering pipelines, approximately 46 miles of residue gas pipelines with four market connections, and approximately 38 miles of NGL pipelines. Three cryogenic processing trains, each with nameplate capacity of 200 MMcf/d, were placed into service during 2019. Other assets include an NGL truck loading terminal with six Lease Automatic Custody Transfer units and eight NGL bullet tanks with 90,000 gallon capacity per tank. The Company’s existing gathering, processing, and transmission infrastructure is expected to provide capacity levels capable of fulfilling its midstream contracts to service Apache’s production from Alpine High and potential third-party customers.
As of December 31, 2021, the Company owns the following Equity Method Interest Pipelines:
•A 16 percent equity interest in the Gulf Coast Express Pipeline Project (GCX), which is owned and operated by Kinder Morgan Texas Pipeline, LLC (Kinder Morgan). GCX transports natural gas from the Waha area in West Texas to Agua Dulce near the Texas Gulf Coast. GCX was placed in service during 2019, with the total capacity of 2.0 Bcf/d fully subscribed under long-term contracts.
•A 15 percent equity interest in the EPIC crude oil pipeline (EPIC), which is operated by EPIC Consolidated Operations, LLC. EPIC transports crude oil from Orla, Texas in Northern Reeves County to the Port of Corpus Christi, Texas. EPIC was placed in service in early 2020, with initial throughput capacity of approximately 600 MBbl/d.
•An approximate 26.7 percent equity interest in the Permian Highway Pipeline (PHP), which is also owned and operated by Kinder Morgan. PHP transports natural gas from the Waha area in northern Pecos County, Texas to the Katy, Texas area with connections to Texas Gulf Coast and Mexico markets. PHP was placed in service in January 2021, with the total capacity of 2.1 Bcf/d fully subscribed under long-term contracts.
•A 33 percent equity interest in the Shin Oak NGL Pipeline (Shin Oak), which is owned by Breviloba, LLC, and operated by Enterprise Products Operating LLC. Shin Oak transports NGLs from the Permian Basin to Mont Belvieu, Texas. Shin Oak was placed in service during 2019, with total capacity of up to 550 MBbl/d.
On October 21, 2021, the Company announced that it will combine with privately-owned BCP Raptor Holdco LP (BCP) in an all-stock transaction (the BCP Business Combination). BCP is the parent company of EagleClaw Midstream, which includes EagleClaw Midstream Ventures, the Caprock Midstream and Pinnacle Midstream businesses, and a 26.7 percent interest in the Permian Highway Pipeline.
As consideration for the transaction, the Company will issue 50 million shares of Class C Common Stock (and Altus Midstream will issue a corresponding number of Common Units) to BCP’s unitholders, which are principally funds affiliated with Blackstone and I Squared Capital. The transaction is expected to close during the first quarter of 2022 following completion of customary closing conditions.
The global economy and the energy industry have been deeply impacted by the effects of the coronavirus disease 2019 (COVID-19) pandemic and related governmental actions. Uncertainty in the oil markets and the negative demand implications
27

of the COVID-19 pandemic continue to impact oil supply and demand. Altus management continues to monitor natural gas throughput volumes from Apache and capacity utilization of the Equity Method Interest Pipelines.
The current crisis, however, is still evolving and may become more severe and complex. The ultimate impact and the extent to which the COVID-19 pandemic will continue to affect the Company’s business, results of operation, and financial condition is difficult to predict and depends on numerous evolving factors outside of Altus’ control, including the duration and scope of the pandemic, new and continuing government, social, business, and other actions taken in response to the pandemic, any additional waves of the virus, the mandate, availability, and ultimate efficacy of the vaccines on new variants of the virus, and the effect of the pandemic on short- and long-term general economic conditions. As a result, the COVID-19 pandemic may still materially and adversely affect Altus’ results in a manner that is either not currently known or that the Company does not currently consider to be a significant risk to its business. For additional information about the business risks relating to the COVID-19 pandemic, please refer to Part II, Item 1A—Risk Factors of this Annual Report on Form 10-K.
Altus Midstream Operational Metrics
The Company uses a variety of financial and operational metrics to assess the performance of its operations and growth compared to expected plan estimates. These metrics include:
•Throughput volumes and associated revenues;
•Costs and expenses; and
•Adjusted EBITDA (as defined below).
Throughput Volumes and Associated Revenues
The Company’s operating results are driven primarily by the volume of natural gas gathered, processed, compressed, and/or transmitted. For the periods presented, substantially all revenues were generated through fee-based agreements with Apache, a related party. The volumes of natural gas that Altus gathers or processes in future periods will depend on the production level of Apache’s assets in areas Altus services and any additional third-party service contracts or incremental use of Altus Midstream infrastructure resulting from the potential close of the BCP Business Combination discussed above. The Company’s assets were initially constructed to serve Apache’s anticipated development of Alpine High and its surrounding areas. As such, the amount and pace of upstream development activity by Apache could directly impact Altus’ aggregate gathering and processing volumes because the production rate of natural gas wells declines over time.
The Company entered into a new Gas Processing Agreement with Apache in October 2021, which superseded the prior agreement. The updated processing agreement contains modified gas processing fees for new volumes from future Apache drilling activities at Alpine High that are more consistent with current market practices. Part of the modified fee structure in the new Gas Processing Agreement establishes fixed processing rates. Any monthly difference between actual recovery rates and fixed recovery rates will create either excess recovery volumes for ALTM to sell or processing volume deficiencies which ALTM would owe Apache. Commodity price fluctuations and oil and gas industry dynamics that existed when the original agreement was signed have changed dramatically, and the updated terms of the new Gas Processing Agreement were established to potentially attract new business from both Apache and other third-party producers and midstream companies.
The Company remains focused on increasing third-party processing opportunities in addition to Alpine High, and other producers are developing oil and gas plays in surrounding areas that may provide Altus opportunities to enter into third-party processing and gathering agreements. Producers’ willingness to engage in new drilling is determined by a number of factors, all of which are affected by the COVID-19 pandemic, the most important of which are the prevailing and projected prices of oil, natural gas, and NGLs, the cost to drill and operate a well, the availability and cost of capital, and environmental and government regulations. Company management believes that its midstream assets are positioned in one of the most active regions for oil and gas exploration and development activities in the United States. The Company has actively pursued strategic alternatives for future growth, which culminated in the recently announced BCP Business Combination, a combination with a midstream company that has existing commitments with various third-party customers.
For more information about the Company’s relationship with Apache, please see the section entitled Altus’ Relationship with Apache in Part I, Items 1 and 2 of this Annual Report on Form 10-K.

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Costs and Expenses
Costs of product sales — affiliate
Costs of product sales — affiliate represent the cost of excess recovery volumes of residue gas the Company receives from Apache under the terms of the new Gas Processing Agreement, which the Company then owns and controls prior to ultimate sale to Apache. The costs related to excess recovery volumes are directly associated with volumes of excess recoveries under the new Gas Processing Agreement, if any.
Costs of product sales — third parties
Costs of product sales — third parties represent purchases of NGLs from a third party and the cost of excess recovery volumes of condensate the Company receives from Apache under the terms of the new Gas Processing Agreement. The Company owns and controls such volumes prior to ultimate sale to customers. The costs related to third party purchases of NGLs are directly associated with the volume and amount of third-party contracts entered into and could fluctuate depending on market conditions and product prices.
Operations and maintenance
Operations and maintenance expenses primarily comprise those costs that are directly associated with the operations of the Company’s assets. The most significant of these costs are associated with direct labor and supervision, power, repair and maintenance expenses, and equipment rentals. Fluctuations in commodity prices impact operating cost elements both directly and indirectly. For example, commodity prices directly impact costs such as power and fuel, which are expenses that increase (or decrease) in line with changes in commodity prices. Commodity prices also affect industry activity and demand, thus indirectly impacting the cost of items such as labor and equipment rentals.
Depreciation and accretion
Depreciation on the capitalized costs incurred to acquire and develop the Company’s midstream assets is computed based on estimated useful lives and estimated salvage values. Also included within this expense is the accretion associated with estimated asset retirement obligations (ARO). Depreciation and accretion expense would be expected to increase during future periods in-line with additional infrastructure costs incurred; however, any future asset sales or long-lived asset impairments would decrease expected depreciation expense to commensurate levels.
General and administrative
General and administrative (G&A) expense represents indirect costs and overhead expenditures incurred by the Company associated with managing the midstream assets. These expenses primarily comprise fixed fees set forth in the Construction, Operations and Maintenance Agreement (COMA) entered into with Apache. Refer to Note 2—Transactions with Affiliates in the Notes to Consolidated Financial Statements set forth in Part IV of this Annual Report on Form 10-K for further information.
Taxes other than income
Taxes other than income are primarily related to ad valorem taxes on the Company’s midstream assets.
Adjusted EBITDA
The Company defines Adjusted EBITDA as net income (loss) including noncontrolling interests before financing costs (net of capitalized interest), interest income, income taxes, depreciation, and accretion and adjusts such items, as applicable, from income from the Equity Method Interest Pipelines. Altus also excludes (when applicable) impairments, unrealized gains or losses on derivative instruments, and other items affecting comparability of results to peers. Company management believes Adjusted EBITDA is useful for evaluating operating performance and comparing results of operations from period-to-period and against peers without regard to financing or capital structure. Adjusted EBITDA should not be considered as an alternative to, or more meaningful than, net income (loss) including noncontrolling interests or any other measure determined in accordance with accounting principles generally accepted in the United States (GAAP) or as an indicator of the Company’s operating performance or liquidity. Certain items excluded from Adjusted EBITDA are significant components in understanding and assessing Altus’ financial performance, such as cost of capital and tax structure, as well as the historic costs of depreciable assets, none of which are components of Adjusted EBITDA. The presentation of Adjusted EBITDA should not be construed as an inference that the Company’s results will be unaffected by unusual or non-recurring items. Additionally, the Company’s computation of Adjusted EBITDA may not be comparable to other similarly titled measures of other companies.
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Adjusted EBITDA is not defined in GAAP
The GAAP measure used by the Company that is most directly comparable to Adjusted EBITDA is net income (loss) including noncontrolling interests. Adjusted EBITDA should not be considered as an alternative to the GAAP measure of net income (loss) including noncontrolling interests or any other measure of financial performance presented in accordance with GAAP. Adjusted EBITDA has important limitations as an analytical tool because it excludes some, but not all, items that affect net income (loss) including noncontrolling interests. Adjusted EBITDA should not be considered in isolation or as a substitute for analysis of the Company’s results as reported under GAAP. The Company’s definition of Adjusted EBITDA may not be comparable to similarly titled measures of other companies in the industry, thereby diminishing its utility.
Reconciliation of non-GAAP financial measure
Company management compensates for the limitations of Adjusted EBITDA as an analytical tool by reviewing the comparable GAAP measure, understanding the differences between Adjusted EBITDA as compared to net income (loss) including noncontrolling interests, and incorporating this knowledge into its decision-making processes. Management believes that investors benefit from having access to the same financial measure that the Company uses in evaluating operating results.
The following table presents a reconciliation of the GAAP financial measure of net income (loss) including noncontrolling interests to the non-GAAP financial measure of Adjusted EBITDA.

		Year Ended December 31,	
		2021		2020	
					
		(In thousands)	
Reconciliation of net income including noncontrolling interests to Adjusted EBITDA					
Net income including noncontrolling interests		$	99,221 			$	81,684 		
Add:					
Financing costs, net of capitalized interest		10,598 			2,190 		
	
Depreciation and accretion		16,201 			15,945 		
Impairments		441 			1,643 		
Impairment on equity method interests		160,441 			— 		
Unrealized derivative instrument loss		— 			36,080 		
Equity method interests Adjusted EBITDA		188,959 			111,675 		
Transaction costs		4,472 			— 		
Loss on sale of assets, net		— 			2,234 		
Other		1,258 			348 		
Less:					
Gain on sale of assets, net		1,243 			— 		
Unrealized derivative instrument gain		82,114 			— 		
Interest income		4 			9 		
Income from equity method interests, net		113,764 			58,739 		
Warrants valuation adjustment		664 			1,200 		
Income tax benefit		— 			696 		
	
Adjusted EBITDA		$	283,802 			$	191,155 		

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Results of Operations

The following table presents the Company’s results of operations for the periods presented:

		Year Ended December 31,	
		2021		2020	
					
		(In thousands)	
REVENUES:					
Midstream services revenue — affiliate		$	142,727 			$	144,714 		
Product sales — affiliate		9,754 			— 		
Product sales — third parties		8,136 			3,695 		
Total revenues		160,617 			148,409 		
COSTS AND EXPENSES:					
Costs of product sales — affiliate		9,754 			— 		
Costs of product sales — third parties		7,793 			2,988 		
Operations and maintenance		32,748 			37,993 		
General and administrative		14,182 			13,155 		
Depreciation and accretion		16,201 			15,945 		
Impairments		441 			1,643 		
Taxes other than income		13,886 			15,069 		
Total costs and expenses		95,005 			86,793 		
OPERATING INCOME		65,612 			61,616 		
Unrealized derivative instrument gain (loss)		82,114 			(36,080)		
Interest income		4 			9 		
Income from equity method interests, net		113,764 			58,739 		
Impairment on equity method interests		(160,441)			— 		
Warrants valuation adjustment		664 			1,200 		
Transaction costs		(4,472)			— 		
Other		12,574 			(2,306)		
Total other income		44,207 			21,562 		
Financing costs, net of capitalized interest		10,598 			2,190 		
NET INCOME BEFORE INCOME TAXES		99,221 			80,988 		
Current income tax benefit		— 			(696)		
	
NET INCOME INCLUDING NONCONTROLLING INTERESTS		99,221 			81,684 		
Net income attributable to Preferred Unit limited partners		161,906 			75,906 		
NET INCOME (LOSS) ATTRIBUTABLE TO COMMON SHAREHOLDERS		(62,685)			5,778 		
Net income (loss) attributable to Apache limited partner		(48,741)			2,987 		
NET INCOME (LOSS) ATTRIBUTABLE TO CLASS A COMMON SHAREHOLDERS		$	(13,944)			$	2,791 		
KEY PERFORMANCE METRICS:					
Adjusted EBITDA(1)		$	283,802 			$	191,155 		
OPERATING DATA:					
Average throughput volumes of natural gas (MMcf/d)		440 			499 		
	
(1)Adjusted EBITDA is not defined by GAAP and should not be considered an alternative to, or more meaningful than, net income (loss), operating income (loss), net cash provided by (used in) operating activities, or any other measures prepared under GAAP. For the definition and reconciliation of Adjusted EBITDA to its most directly comparable GAAP measure, see the section titled Altus Midstream Operational Metrics—Adjusted EBITDA above.

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Since the Company commenced operations in the second quarter of 2017, its most significant customer has been Apache. Altus Midstream is pursuing similar long-term commercial service contracts with third-parties that could be accommodated by existing capacity. Altus’ midstream service agreements with Apache contain no minimum volume commitments and as such, future results of operations may be materially impacted by Apache’s production volumes from Alpine High and Altus’ ability to contract third-party business. Refer to Part I, Item 1A—Risk Factors of this Annual Report on Form 10-K for further discussion.
Revenues
The following table summarizes the Company’s revenues for the periods presented:

		Year Ended December 31,	
		2021		2020	
					
		(In thousands)	
REVENUES:					
Midstream services revenue — affiliate		$	142,727 			$	144,714 		
Product sales — affiliate		9,754 			— 		
Product sales — third parties		8,136 			3,695 		
Total revenues		$	160,617 			$	148,409 		

Midstream services revenue was primarily generated from fee-based midstream services provided under the terms of separate commercial midstream service agreements with Apache for the gas gathering, processing, and transmission of volumes from the dedicated area in the Alpine High field. Altus receives a per-unit fee based on the quantity of natural gas and NGL volumes that flow through its systems. The Company entered into a new Gas Processing Agreement with Apache in October 2021, which superseded the prior agreement. In addition to per unit service fees described above, the new Gas Processing Agreement contains terms for Apache to provide the Company with excess recovery volumes as consideration under the contract. Excess recovery volumes represent the net difference between the actual recovery rate of processed volumes and contractually fixed volumetric recovery rates.
For excess recovery volumes the Company obtains control and takes title, if any, on a monthly basis, the related non-cash consideration of these volumes is included in “midstream services revenue — affiliate” at market value. Subsequent sales of excess recovery volumes are recognized as product sales and, simultaneously, cost of product sales are recognized at the value attributed to the excess recovery volumes when they were earned.
Additionally, during 2020 the Company began providing compressor operations, maintenance, and related services to Apache in exchange for a fixed monthly fee per compressor unit serviced. For more details, please refer to Note 3—Revenue Recognition in the Notes to Consolidated Financial Statements included within Part IV, Item 15 of this Annual Report on Form 10-K.
Midstream services revenue — affiliate
Midstream services revenue — affiliate decreased by $2.0 million to $142.7 million for the year ended December 31, 2021, as compared to $144.7 million for the year ended December 31, 2020. The decrease was primarily driven by lower throughput of natural gas volumes from Apache, which reduced revenues, offset by approximately $13.4 million of revenues related to excess recovery volumes earned under the new Gas Processing Agreement in the fourth quarter of 2021.
Product sales — affiliate
The $9.8 million increase in product sales — affiliate during the year ended December 31, 2021, was solely due to the sale of excess recovery volumes of residue gas received as consideration under the new Gas Processing Agreement, which were subsequently sold to Apache. Refer to Costs of product sales – affiliate under Costs and Expenses below.
Product sales — third parties
The $4.4 million increase in product sales — third parties during the year ended December 31, 2021, as compared to the year ended December 31, 2020, was driven by higher volumes of NGLs and condensates purchased and processed by Altus from a third party and subsequently sold to non-affiliated customers. Additionally, nearly $2.4 million of the increase reflects the sale of excess recovery volumes of condensates received as a consideration under the new Gas Processing Agreement,
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which was subsequently sold to non-affiliated customers. Refer to Costs of product sales – third parties under Costs and Expenses below.
Costs and Expenses
The following table summarizes the Company’s costs and expenses for the periods presented:

		Year Ended December 31,	
		2021		2020	
					
		(In thousands)	
Costs of product sales — affiliate		$	9,754 			$	— 		
Costs of product sales — third parties		7,793 			2,988 		
Operations and maintenance		32,748 			37,993 		
General and administrative		14,182 			13,155 		
Depreciation and accretion		16,201 			15,945 		
Impairments		441 			1,643 		
Taxes other than income		13,886 			15,069 		
Total costs and expenses		$	95,005 			$	86,793 		
Costs of product sales — affiliate
The $9.8 million increase in cost of product sales — affiliate during the year ended December 31, 2021, as compared to the year ended December 31, 2020, was solely due to the cost of excess recovery volumes of gas received as consideration under the new Gas Processing Agreement subsequently sold to Apache.
Costs of product sales — third parties

The $4.8 million increase in costs of product sales — third parties during the year ended December 31, 2021, as compared to the year ended December 31, 2020, was driven by higher volumes of purchases of NGLs from a third-party and the cost of excess recovery condensate volumes under the new Gas Processing Agreement.
Operations and maintenance
Operations and maintenance expenses decreased by approximately $5.2 million to $32.7 million for the year ended December 31, 2021, as compared to $38.0 million for the year ended December 31, 2020. This decrease was primarily driven by increased operational efficiency as a result of transitioning from mechanical refrigeration units to the Company’s centralized Diamond cryogenic complex. Work related to this transition was still being completed in the first half of 2020. The transition resulted in decreases in various costs, the most significant being contract labor, equipment rentals, and chemical expenses. These savings were partially offset by higher power costs and higher repair and maintenance expenses.
General and administrative and Depreciation and accretion

General and administrative expenses were approximately $1.0 million higher in 2021 compared to 2020 primarily due to the escalating price terms under the COMA. Depreciation and accretion expense in 2021 was consistent with 2020, as the Company’s carrying value of its property, plant, and equipment assets did not meaningfully change during the comparative periods.
Impairments
During the fourth quarter of 2020, the Company sold certain of its power generators to a third party and, as a result, the remaining power generators owned by the Company were remeasured at fair value calculated based on the proceeds of such sale. This remeasurement resulted in an impairment of $1.6 million on these assets. Impairments in 2021 were insignificant.
For further discussion of these impairments, please see Note 1—Summary of Significant Accounting Policies and Note 4—Property, Plant and Equipment in the Notes to Consolidated Financial Statements included within Part IV, Item 15 of this Annual Report on Form 10-K.
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Taxes other than income
The decrease in taxes other than income was driven by changes related to ad valorem taxes, which decreased by $1.2 million to $13.5 million for the year ended December 31, 2021, as compared to $14.7 million for the year ended December 31, 2020. The $1.2 million decrease is primarily related to a decrease in tax assessed value for the Company’s property, plant, and equipment.
Other Income (Loss) and Financing Costs, Net of Capitalized Interest
The components of other income, other loss, and financing costs, net of capitalized interest are presented below:

		Year Ended December 31,	
		2021		2020	
					
		(In thousands)	
Unrealized derivative instrument gain (loss)		$	82,114 			$	(36,080)		
Interest income		4 			9 		
Income from equity method interests, net		113,764 			58,739 		
Impairment on equity method interests		(160,441)			— 		
Warrants valuation adjustment		664 			1,200 		
Transaction costs		(4,472)			— 		
Other		12,574 			(2,306)		
Total other income		$	44,207 			$	21,562 		
					
Interest expense		$	9,431 			$	9,775 		
Amortization of deferred facility fees		1,167 			1,148 		
Capitalized interest		— 			(8,733)		
Total Financing costs, net of capitalized interest		$	10,598 			$	2,190 		
Unrealized derivative instrument gain (loss)
During the year ending December 31, 2021, the Company recognized an unrealized derivative instrument gain of $82.1 million in relation to an embedded exchange option identified upon the issuance and sale of Series A Cumulative Redeemable Preferred Units (the Preferred Units). The recognized unrealized loss related to this embedded feature was $36.1 million for the year ended December 31, 2020. The associated derivative liability is recorded on the consolidated balance sheet at fair value. The fair value of the embedded derivative is determined (using an income approach) by a range of factors, including expected future interest rates using the Black-Karasinski model, interest rate volatility, the Company’s imputed interest rate, the expected timing of periodic cash distributions, the expected timing of any partial redemption of the Preferred Units, the estimated timing for the potential exercise of the exchange option, and anticipated dividend yields of the Preferred Units. The value of the derivative during the year ending December 31, 2021 was primarily impacted by the expected mandatory redemption of certain of the Preferred Units on, and after, the closing of the BCP Business Combination. Refer to Note 11—Series A Cumulative Redeemable Preferred Units within Part IV, Item 15 of this Annual Report on Form 10-K for further discussion.
Income from equity method interests, net
Income from equity method interests increased by $55.0 million to $113.8 million for the year ended December 31, 2021, as compared to $58.7 million for the year ended December 31, 2020. The increase was primarily due to the Company’s 26.7 percent share of net income from the Permian Highway Pipeline, which commenced service in January 2021.
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Impairment on equity method interests
The $160.4 million increase in impairment on equity method interests for the year ended December 31, 2021, as compared to December 31, 2020, was a result of the Company’s impairment of its interest in the EPIC Crude Oil Pipeline in the fourth quarter of 2021. Refer to Note 1—Summary of Significant Accounting Policies and Note 9—Equity Method Interests within Part IV, Item 15 of this Annual Report on Form 10-K for further discussion.
Other income
In 2020, the Company entered into a contract with a provider to supply the Company with electrical power. If the Company does not utilize all of its fixed purchase volumes under this contract, then it will receive a credit based on a market rate for the related underutilization. In February 2021, in conjunction with increased power pricing due to the Texas freeze event and underutilization of contractual electricity volumes, the Company recognized an estimated credit of approximately $9.7 million for the year ended December 31, 2021. No credits were recognized for the year ended December 31, 2020.
The remainder of the increase to other income primarily relates to the Company recording a gain on the sale of certain non-core assets of $1.2 million for the year ended December 31, 2021 compared to a loss on the sale of certain non-core assets of $2.2 million for the year ended December 31, 2020.
Financing costs, net of capitalized interest
Financing costs incurred, net of capitalized interest, includes increases in interest expense not eligible to have interest capitalized related to balances drawn on Altus Midstream’s credit facility throughout the current year. The changes to gross interest expense for the years presented is insignificant.
Provisions for income taxes
Current income tax benefit for the years ended December 31, 2021 and 2020 were a benefit of nil and $0.7 million, respectively. On March 27, 2020, the President signed into law the Coronavirus Aid, Relief and Economic Security Act (CARES Act) in response to the COVID-19 pandemic. Under the CARES Act, 100 percent of net operating losses arising in tax years beginning after December 31, 2017, and before January 1, 2021 may be carried back to each of the five preceding tax years of such loss. For the year ended December 31, 2020, the Company recorded a current income tax benefit of $0.7 million associated with a net operating loss carryback claim.
The Company recorded no deferred income tax expense for the years ended December 31, 2021 and 2020.
Please refer to Note 12—Income Taxes set forth in Part IV, Item 15 of this Annual Report on Form 10-K for further discussion.
Key Performance Metric—EBITDA
Net income before income taxes was $99.2 million for the year ended December 31, 2021, an increase of $18.2 million from a net income before income taxes of $81.0 million for the year ended December 31, 2020. The increase in net income before income taxes was primarily driven by a $118.2 million decrease to expense related to the fair value measurement of an embedded derivative at December 31, 2021, a $55.0 million increase due to higher income from the Equity Method Interest Pipelines, an increase of $12.2 million in total revenues, a $5.2 million decrease in operations and maintenance expenses, a $1.2 million decrease in impairment expense and an increase of $14.9 million in other income compared to the prior year period (as discussed above). The increases to net income were offset by a $160.4 million impairment of an equity method interest at December 31, 2021, a $14.6 million increase in costs of product sales, an $8.4 million increase in interest expense from lower capitalized interest, and a net increase of $5.1 million in transaction and various other costs of the Company.
Adjusted EBITDA increased by $92.6 million for the year ended December 31, 2021 compared to the prior year period. Adjusted EBITDA, which excludes the impacts of depreciation, accretion, impairments, and the changes to the embedded derivative, benefited from an incremental $22.3 million increase related to excluding depreciation, and interest in the Company’s proportionate share of EBITDA from the Equity Method Interest Pipelines. This amount was further benefited by a decrease of $2.4 million, in the aggregate, of various other insignificant costs of the Company.
For additional information, see the section titled Altus Midstream Operational Metrics—Adjusted EBITDA above.
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Capital Resources and Liquidity
The Company’s primary use of capital since inception has been for the initial construction of gathering and processing assets, as well as the acquisition of the Equity Method Interest Pipelines and associated subsequent construction costs. For 2022, the Company’s primary spending requirements are anticipated to be related to the Company’s payment of a quarterly cash dividend on its Class A Common Stock as may be declared by its board of directors and payment of the Company’s quarterly distribution to the Preferred Unit limited partners.
During 2021, the Company’s primary sources of cash were distributions from the Equity Method Interest Pipelines, borrowings under the revolving credit facility, and cash generated from operations. Based on Altus’ current financial plan and related assumptions, the Company believes that cash from operations, a reduced capital program for its midstream infrastructure, and distributions from the Equity Method Interest Pipelines will generate cash flows in excess of capital expenditures and the amount required to fund the Company’s planned quarterly dividend and quarterly payments to the Preferred Unit limited partners during 2022.
Given recent crude oil price volatility and uncertain economic activity resulting from the COVID-19 pandemic and related governmental actions, the Company continues to monitor expected natural gas throughput volumes from Apache and capacity utilization of the Equity Method Interest Pipelines. Further, given the pending BCP Business Combination noted above, together with the recent price volatility and continuing economic uncertainty related to COVID-19, future projections remain dynamic. Altus’ results, including projections related to capital resources and liquidity, could be materially affected by the continuing COVID-19 pandemic and the effects of the BCP Business Combination if closed.
Altus Midstream Capital Requirements
During 2021 and 2020, capital spending for midstream infrastructure assets totaled $4.6 million and $30.0 million, respectively. Management believes its existing gathering, processing, and transmission infrastructure capacity is capable of fulfilling its midstream contracts to service Apache’s production from Alpine High and any potential third-party customers. As such, the Company expects remaining capital requirements for its existing infrastructure assets during 2022 to be minimal.
Additionally, during the years ended December 31, 2021 and 2020, the Company made cash contributions totaling $28.4 million and $327.3 million, respectively, for the Equity Method Interest Pipelines, which includes the following equity interest ownership stakes:
•a 16.0 percent interest in GCX;
•a 15.0 percent interest in EPIC;
•an approximate 26.7 percent interest in PHP; and
•a 33.0 percent interest in Shin Oak.
The Company estimates it will incur minimal capital contributions during 2022 for its equity interest in these joint venture pipelines. The Company anticipates its existing capital resources will be sufficient to fund the Company’s future capital expenditures for the Equity Method Interest Pipelines and the Company’s existing infrastructure assets. For further information on the Equity Method Interest Pipelines, refer to Note 9—Equity Method Interests in the Notes to Consolidated Financial Statements set forth in Part IV, Item 15 of this Annual Report on Form 10-K.
Altus Midstream Class A Common Stock Dividend and Common Units Distributions
During 2021, the Company paid an aggregate $22.5 million in dividends on the Company’s Class A Common Stock, of which $5.6 million, or $1.50 per share, was paid in each quarter of 2021. Each quarterly Class A Common Stock dividend was funded by a distribution from Altus Midstream to its common unitholders of $1.50 per Common Unit, with each quarterly distribution totaling $24.4 million, of which $5.6 million was paid to the Company and the balance was paid to Apache. For more information please refer to Note 2—Transactions with Affiliates and Note 10—Equity and Warrants in the Notes to the Consolidated Financial Statements set forth in Part IV, Item 15 of this Annual Report on Form 10-K.

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Sources and Uses of Cash
The following table presents the sources and uses of the Company’s cash and cash equivalents for the periods presented.

 		For the Year Ended December 31,	
 		2021		2020	
					
 		(In thousands)	
Sources of cash and cash equivalents:					
Proceeds from revolving credit facility		$	33,000 			$	228,000 		
Proceeds from sale of assets		3,037 			10,240 		
Capital distributions from equity method interests		38,755 			17,419 		
Net cash provided by operating activities		209,719 			164,294 		
		284,511 			419,953 		
Uses of cash and cash equivalents:					
Capital expenditures(1)		(4,588)			(29,981)		
Distributions paid to Preferred Unit limited partners		(46,249)			(23,124)		
Contributions to equity method interests		(28,420)			(327,305)		
Distributions paid to Apache limited partner		(75,000)			— 		
Dividends paid		(22,479)			— 		
Finance lease payments		— 			(11,789)		
Deferred facility fees		— 			(816)		
Capitalized interest paid		— 			(8,733)		
		(176,736)			(401,748)		
Increase in cash and cash equivalents		$	107,775 			$	18,205 		
(1)The table presents capital expenditures on a cash basis; therefore, the amounts may differ from those discussed elsewhere in this document, which include accruals.
Liquidity
The following table presents a summary of the Company’s key financial indicators at the dates presented:

		December 31, 2021		December 31, 2020	
					
 		(In thousands)	
Cash and cash equivalents		$	131,963 			$	24,188 		
Total debt		657,000 			624,000 		
Available committed borrowing capacity		141,000 			176,000 		
Cash and cash equivalents
At December 31, 2021 and December 31, 2020, the Company had $132.0 million and $24.2 million, respectively, in cash and cash equivalents. The majority of the cash is invested in highly liquid, investment-grade instruments with maturities of three months or less at the time of purchase.
Debt
As of December 31, 2021 and December 31, 2020, the Company had debt outstanding totaling $657.0 million and $624.0 million, respectively.

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Available credit facilities
In November 2018, Altus Midstream entered into a revolving credit facility for general corporate purposes that matures in November 2023 (subject to Altus Midstream’s two, one year extension options). The agreement for this revolving credit facility, as amended (the Amended Credit Agreement), provides aggregate commitments from a syndicate of banks of $800.0 million. The aggregate commitments include a letter of credit subfacility of up to $100.0 million and a swingline loan subfacility of up to $100.0 million. Altus Midstream may increase commitments up to an aggregate $1.5 billion by adding new lenders or obtaining the consent of any increasing existing lenders. As of December 31, 2021 there were $657.0 million of borrowings and a $2.0 million letter of credit outstanding under this facility. As of December 31, 2020, there were $624.0 million of borrowings and no letters of credit outstanding under this facility.
Altus Midstream’s revolving credit facility is unsecured and is not guaranteed by the Company, Apache, APA Corporation or any of their respective subsidiaries.
At Altus Midstream’s option, the interest rate per annum for borrowings under this amended credit facility is either a base rate, as defined, plus a margin, or the London Interbank Offered Rate (LIBOR), plus a margin. Altus Midstream also pays quarterly a facility fee at a rate per annum on total commitments. The margins and the facility fee vary based upon (i) the Leverage Ratio (as defined below) until Altus Midstream has a senior long-term debt rating and (ii) such senior long-term debt rating once it exists. The Leverage Ratio is the ratio of (1) the consolidated indebtedness of Altus Midstream and its restricted subsidiaries to (2) EBITDA (as defined in the Amended Credit Agreement) of Altus Midstream and its restricted subsidiaries for the 12-month period ending immediately before the determination date. At December 31, 2021, the base rate margin was 0.05 percent, the LIBOR margin was 1.05 percent, and the facility fee was 0.20 percent. In addition, a commission is payable quarterly to the lenders on the face amount of each outstanding letter of credit at a per annum rate equal to the LIBOR margin then in effect. Customary letter of credit fronting fees and other charges are payable to issuing banks.
The Amended Credit Agreement contains restrictive covenants that may limit the ability of Altus Midstream and its restricted subsidiaries to, among other things, incur additional indebtedness or guaranty indebtedness, sell assets, make investments in unrestricted subsidiaries, enter into mergers, make certain payments and distributions, incur liens on certain property securing indebtedness, and engage in certain other transactions without the prior consent of the lenders. Altus Midstream also is subject to a financial covenant under the Amended Credit Agreement, which requires it to maintain a Leverage Ratio not exceeding 5.00:1.00 at the end of any fiscal quarter, starting with the quarter ended December 31, 2019, except that during the period of up to one year following a qualified acquisition, the Leverage Ratio cannot exceed 5.50:1.00 at the end of any fiscal quarter. Unless the Leverage Ratio is less than or equal to 4.00:1.00, the Amended Credit Agreement limits distributions in respect of Altus Midstream LP’s capital to $30 million per calendar year until either (i) the consolidated net income of Altus Midstream LP and its restricted subsidiaries, as adjusted pursuant to the Amended Credit Agreement, for three consecutive calendar months equals or exceeds $350.0 million on an annualized basis or (ii) Altus Midstream LP has a specified senior long-term debt rating; in addition, before the occurrence of one of those two events, the Leverage Ratio must be less than or equal to 5.00:1.00. In no event can any distribution be made that would, after giving effect to it on a pro forma basis, result in a Leverage Ratio greater than (i) 5.00:1.00 or (ii) for a specified period after a qualifying acquisition, 5.50:1.00. The Leverage Ratio as of December 31, 2021 was less than 4.00:1.00.
The terms of Altus Midstream’s Preferred Units also contain certain restrictions on distributions on Altus Midstream LP’s Common Units, including the Common Units held by the Company, and any other units that rank junior to the Preferred Units with respect to distributions or distributions upon liquidation. Refer to Note 11—Series A Cumulative Redeemable Preferred Units in the Notes to Consolidated Financial Statements set forth in Part IV, Item 15 of this Annual Report on Form 10-K for further information. In addition, the amount of any cash distributions to Altus Midstream LP by any entity in which it has an interest accounted for by the equity method is subject to such entity’s compliance with the terms of any debt or other agreements by which it may be bound, which in turn may impact the amount of funds available for distribution by Altus Midstream LP to its partners.
There are no clauses in the Amended Credit Agreement that permit the lenders to accelerate payments or refuse to lend based on unspecified material adverse changes. The Amended Credit Agreement has no drawdown restrictions or prepayment obligations in the event of a decline in credit ratings. However, the agreement allows the lenders to accelerate payment maturity and terminate lending and issuance commitments for nonpayment and other breaches, and if Altus Midstream or any of its restricted subsidiaries defaults on other indebtedness in excess of the stated threshold, is insolvent, or has any unpaid, non-appealable judgment against it for payment of money in excess of the stated threshold. Lenders may also accelerate payment maturity and terminate lending and issuance commitments if Altus Midstream undergoes a specified change in control or has specified pension plan liabilities in excess of the stated threshold. Altus Midstream was in compliance with the terms of the Amended Credit Agreement as of December 31, 2021.
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There is no assurance that the financial condition of banks with lending commitments to Altus Midstream will not deteriorate. Altus closely monitors the ratings of the banks in the Company’s bank group. Having a large bank group allows the Company to mitigate the potential impact of any bank’s failure to honor its lending commitment.
Series A Cumulative Redeemable Preferred Units
On June 12, 2019, Altus Midstream issued and sold the Preferred Units in a private offering exempt from the registration requirements of the Securities Act (the Closing). The Closing occurred pursuant to a Preferred Unit Purchase Agreement among Altus Midstream, the Company, and the purchasers party thereto, dated as of May 8, 2019. A total of 625,000 Preferred Units were sold at a price of $1,000 per Preferred Unit, for an aggregate issue price of $625.0 million. Altus Midstream received approximately $611.2 million in cash proceeds from the sale after deducting transaction costs and discounts to certain purchasers. These proceeds were used to fund ongoing capital contributions related to Altus’ Equity Method Interest Pipelines and repayment of outstanding principal on the revolving credit facility (discussed above).
At the Closing, the partners of Altus Midstream entered into a second amended and restated agreement of limited partnership of Altus Midstream LP (the Amended LPA). The Amended LPA provides the terms of the Preferred Units, including the distribution rate, redemption rights, and rights to exchange the Preferred Units for shares of the Company’s Class A Common Stock, as well as rights of holders of the Preferred Units to approve certain partnership business, financial, and governance-related matters. The Preferred Units have a perpetual term, unless redeemed or exchanged as described below. Pursuant to the Amended LPA:
•The Preferred Units entitle the holders thereof to receive quarterly distributions at a rate of 7 percent per annum, commencing with the quarter ended June 30, 2019. The rate increases to 10 percent per annum after the fifth anniversary of Closing and upon the occurrence of specified events. For any quarter ending on or prior to December 31, 2020, Altus Midstream could elect to pay distributions on the Preferred Units in-kind and did so in respect of quarters ended on and before March 31, 2020.
•The Preferred Units are redeemable at Altus Midstream’s option at any time in cash at a redemption price (the Redemption Price) equal to (a) the greater of (i) an 11.5 percent internal rate of return (increasing to 13.75 percent after the fifth anniversary of Closing), and (ii) a 1.3x multiple of invested capital plus (b) if applicable, the value of any accrued and unpaid distributions. The Preferred Units will be redeemable at the holder’s option upon a change of control or liquidation of Altus Midstream and certain other events, including certain asset dispositions. The Company and Altus Midstream remained subsidiaries of Apache upon consummation of the January 2022 direct exchange by the Company and Apache under the Amended LPA, pursuant to which the Company succeeded to Apache’s 12.5 million Common Units, issued an additional 12.5 million shares of Class A Common Stock to Apache, and cancelled Apache’s 12.5 million shares of Class C Common Stock (as further discussed in Note 10—Equity and Warrants in the Notes to Consolidated Financial Statements set forth in Part IV, Item 15 of this Annual Report on Form 10-K).
•The Preferred Units will be exchangeable for shares of the Company’s Class A Common Stock at the option of the Preferred Unit holders after the seventh anniversary of Closing or upon the occurrence of specified events. Each Preferred Unit will be exchangeable for a number of shares of Class A Common Stock equal to the Redemption Price divided by the volume-weighted average trading price of the Class A Common Stock on the Nasdaq Global Select Market for the 20 trading days immediately preceding the second trading day prior to the applicable exchange date, less a 6 percent discount.
•Each outstanding Preferred Unit has a liquidation preference equal to the Redemption Price payable before any amounts are paid in respect of Altus Midstream’s Common Units and any other units that rank junior to the Preferred Units with respect to distributions or distributions upon liquidation. 
•Altus Midstream is restricted from declaring or making cash distributions on its Common Units until all required distributions on the Preferred Units have been paid. In addition, before the fifth anniversary of Closing, aggregate cash distributions on, and redemptions of, Common Units are limited to $650.0 million of cash from ordinary course of operations if permitted under Altus Midstream’s Amended Credit Agreement. Cash distributions on, and redemptions of, Common Units also are subject to satisfaction of leverage ratio requirements specified in the Amended LPA.
Distributions not paid in accordance with the terms of the Amended LPA attract an additional percentage per annum, cumulative to the distribution rates noted above. Altus Midstream’s ability to exercise or satisfy redemption options in cash or pay quarterly distributions is predicated upon Altus Midstream’s ability to generate sufficient cash from operations in addition to the availability of borrowing capacity under its existing revolving credit facility.
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Since the Preferred Units could be exchangeable for a number of shares of Class A Common Stock equal to 20 percent or more of the Company’s outstanding voting power, the Company submitted the potential issuance of such shares for approval of its stockholders (the Stockholder Approval) at its annual stockholder meeting in 2020 and obtained Stockholder Approval.

Off-Balance Sheet Arrangements
Other than the arrangements described herein, the Company has not entered into any transactions, agreements, or other contractual arrangements with unconsolidated entities that are reasonably likely to materially affect its liquidity or capital resource positions.
At the close of the Altus Combination, Apache was granted the right to receive contingent consideration of up to 1,250,000 shares of Class A Common Stock as follows:
•625,000 shares if the per share closing price of the Class A Common Stock as reported by Nasdaq during any 30-day-trading period ending prior to the fifth anniversary of the Closing Date is equal to or greater than $280.00 for any 20 trading days within such 30-trading-day period.
•625,000 shares if the per share closing price of the Class A Common Stock as reported by Nasdaq during any 30-trading-day period ending prior to the fifth anniversary of the Closing Date is equal to or greater than $320.00 for any 20 trading days within such 30-trading-day period.
All share amounts referenced above have been retrospectively restated to reflect the Company’s reverse stock split, which was effected June 30, 2020. For additional information regarding these arrangements, please see Note 10—Equity and Warrants in the Notes to the Consolidated Financial Statements set forth in Part IV, Item 15 of this Annual Report on Form 10-K.

Contractual Obligations
Altus Midstream exercised four of the Company’s five Pipeline Options acquired from Apache at the closing of the Altus Combination. The fifth option to acquire interest in the Salt Creek NGL pipeline was not exercised, and expired during 2020. The Company may be required to fund its proportionate share of future capital expenditures for its equity interest share in the development of the pipelines as referenced. The Company estimates it will incur minimal capital contributions during 2022 for its equity interests.
The Company’s midstream assets service Altus Midstream’s revenue agreements, which are underpinned by acreage dedications covering Alpine High. There are no minimum volume or firm transportation commitments. Pursuant to these agreements, Altus Midstream is obligated to perform low and high pressure gathering, processing, dehydration, compression, treating, conditioning, and transmission on all volumes produced from the dedicated acreage, so long as Apache has the right to market such gas. Although Altus believes its existing gathering, processing, and transmission infrastructure is expected to provide capacity levels capable of fulfilling its midstream contracts to service Apache’s production and additional third-party customers, current capital spending may be increased in future periods if additional cryogenic processing capacity is needed, commensurate with any forecasted throughput increases.
During the fourth quarter of 2020, the Company entered into a three year fixed-rate power contract with a third-party. The Company estimates its minimum obligation will be $4.7 million and $3.6 million for 2022 and 2023, respectively. The actual amount incurred will vary based on usage.
Altus Midstream may also be subject to various contingent obligations that become payable only if certain events or rulings were to occur. The inherent uncertainty surrounding the timing of and monetary impact associated with these events or rulings prevents any meaningful accurate measurement, which is necessary to assess settlements resulting from litigation, regulatory, or environmental matters. As of December 31, 2021, there were no accruals or loss contingencies related to such matters. For a detailed discussion of the Company’s environmental and legal contingencies, please see Note 8—Commitments and Contingencies in the Notes to Consolidated Financial Statements set forth in Part IV, Item 15 of this Annual Report on Form 10-K.
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For additional information regarding the Company’s obligations, please see Note 2—Transactions with Affiliates, Note 5—Debt and Financing Costs, and Note 8—Commitments and Contingencies in the Notes to the Consolidated Financial Statements set forth in Part IV, Item 15 of this Annual Report on Form 10-K.
Insurance Program
The Company has the benefit of insurance policies that include coverage for physical damage to assets, general liabilities, business interruption insurance, sudden and accidental pollution, and other risks. Altus’ insurance coverage is subject to deductibles or retentions that Altus must satisfy prior to recovering on insurance. Additionally, the insurance coverage is subject to policy exclusions and limitations. There is no assurance that insurance coverage will adequately protect the Company against liability from all potential consequences and damages.
Future insurance coverage for the industry could increase in cost and may include higher deductibles or retentions. In addition, some forms of insurance may become unavailable.

Critical Accounting Estimates
Altus prepares its financial statements and the accompanying notes in conformity with GAAP, which require management to make estimates and assumptions about future events that affect the reported amounts in the financial statements and the accompanying notes. Altus identifies certain accounting policies involving estimation as critical based on, among other things, their impact on the portrayal of Altus’ financial condition, results of operations, or liquidity and the degree of difficulty, subjectivity, and complexity in their deployment. Critical accounting estimates cover accounting matters that are inherently uncertain because the future resolution of such matters is unknown. Management routinely discusses the development, selection, and disclosure of each of the critical accounting policies. The following is a discussion of Altus’ most critical accounting estimates.
Property, Plant, and Equipment 
When assets are placed into service, management makes estimates with respect to useful lives and salvage values that management believes are reasonable. However, subsequent events could cause a change in estimates, thereby impacting future depreciation amounts. Uncertainties that may impact these estimates include, among others, changes in laws and regulations relating to environmental matters, including air and water quality, restoration and abandonment requirements, economic conditions, and supply and demand in the area. Depreciation is computed over the asset’s estimated useful life using the straight-line method based on estimated useful lives and asset salvage values.
Impairment of Long-lived Assets
Long-lived assets used in operations, including gathering, processing, and transmission facilities, are evaluated for potential impairment when events or changes in circumstances indicate a possible significant deterioration in future cash flows expected to be generated by an asset group. Individual assets are grouped for impairment purposes based on a judgmental assessment of the lowest level for which there are identifiable cash flows that are largely independent of the cash flows of other groups of assets. If there is an indication that the carrying amount of an asset may not be recovered, the asset is assessed for impairment through an established process in which changes to significant assumptions such as service prices, throughput volumes, and future development plans are reviewed. If, upon review, the sum of the undiscounted pre-tax cash flows is less than the carrying value of the asset group, the carrying value is written down to estimated fair value. Because there is usually a lack of quoted market prices for long-lived assets, the fair value of the impaired assets is assessed by management using the income approach.
Under the income approach, the fair value of each asset group is estimated based on the present value of expected future cash flows. The income approach is dependent on a number of key factors and assumptions including estimates of forecasted throughput volumes, operating expenses, commercial development and capital costs, inflation expectations, discount rates, and other variables. Management also evaluates changes in Altus’ business and economic conditions and their implications on future development plans and ultimate disposition of the assets. Global and regional economic conditions, including commodity prices and drilling activity by third party customers, may also affect estimated future cash flows.
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The final measure of impairment to be recognized, if any, depends upon management’s calculation using the income approach; however, management does consider other factors in determining the asset’s fair value including indicative values at which similar assets were transferred in recent market transactions, if such data is available. Although the Company bases its fair value measurement of each asset group on assumptions it believes to be reasonable, those assumptions are inherently unpredictable and uncertain, and actual results could differ from the estimates. Negative revisions in throughput estimates, increases in future operating and capital costs, divestitures of significant components of an asset group, or sustained market deterioration in the oil and gas industry could lead to further reductions in expected future cash flows and possibly additional impairments in future periods.
Altus recorded impairments on its gathering, processing, and transmission assets and other fixed assets during 2021, 2020 and 2019. For discussion of these impairments, see Note 1—Summary of Significant Accounting Policies and Note 4—Property, Plant, and Equipment in the Notes to Consolidated Financial Statements included in within Part IV, Item 15 of this Annual Report on Form 10-K.
Impairment of Equity Method Interests
Equity method interests are assessed for impairment whenever changes in the facts and circumstances indicate a loss in value has occurred, if the loss is deemed to be other than temporary. When the loss is deemed to be other than temporary, the carrying value of the equity method investment is written down to fair value, and the amount of the write-down is included in income.
Altus recorded an impairment charge on its equity method interest in EPIC during the fourth quarter of 2021. The fair value of the impaired interest was determined using the income approach. The income approach first considered Altus’ estimates of future throughput volumes, tariff rates, and costs. These assumptions were applied to develop future operating cash flow projections that were then discounted using a discount rate believed to be consistent with that which would be applied by market participants. The amount arrived at using this approach was then considered against EPIC’s debt and the carrying value of Altus’ investment in EPIC as of December 31, 2021, resulting in the fourth quarter impairment charge. Altus has classified this nonrecurring fair value measurement as Level 3 in the fair value hierarchy. Please refer to Note 9—Equity Method Interests, within Part IV, Item 15 of this Annual Report on Form 10-K for further details of the Company’s equity method interests. Negative revisions in future estimates of throughput volumes, revenue assumptions or costs related to the Company’s equity method interests could lead to further impairments of such interests in future periods.
Income Taxes
Altus’ operations are subject to U.S. federal and state taxation on income. The Company records deferred tax assets and liabilities to account for the expected future tax consequences of events that have been recognized in the Company’s financial statements and tax returns. Altus routinely assesses the ability to realize its deferred tax assets. If Altus concludes that it is more likely than not that some portion or all of the deferred tax assets will not be realized under accounting standards, the tax asset would be reduced by a valuation allowance. The Company recorded a full valuation allowance against its deferred tax asset as of December 31, 2021 and December 31, 2020.

The Company regularly assesses and, if required, establishes accruals for uncertain tax positions that could result from assessments of additional tax by taxing jurisdictions where the Company operates. The Company recognizes a tax benefit from an uncertain tax position when it is more likely than not that the position will be sustained upon examination, based on the technical merits of the position. These accruals for uncertain tax positions are subject to a significant amount of judgment and are reviewed and adjusted on a periodic basis in light of changing facts and circumstances considering the progress of ongoing tax audits, case law, and any new legislation. There was no material change in the Company’s uncertain tax positions in the period.
Fair Value Measurements — Preferred Units Embedded Derivative
As noted in the discussion related to the Preferred Units above, the fair value of the embedded derivative is determined by a range of factors, including expected future interest rates using the Black-Karasinski model, the Company’s imputed interest rate, interest rate volatility, the expected timing of periodic cash distributions, the estimated timing for the potential exercise of the exchange option, any anticipated early redemptions of the Preferred Units, and anticipated dividend yields of the Preferred Units. The value of the unrealized derivative liability during the year ended December 31, 2021 decreased by $82.1 million, primarily driven by a current year assumption that a portion of the Preferred Units will be redeemed before the holders of the Preferred Units could theoretically exercise their exchange option. Absent any changes to assumptions regarding the timing of redemptions in general, a one percent increase in the expected imputed interest rate assumption would significantly increase the
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value of the embedded derivative liability at any period end, while a one percent decrease would lead a similar decrease in value.
A summary of key assumptions used to value this instrument at December 31, 2021 and 2020 is included below:

		December 31, 2021		December 31, 2020	
Range of Altus Midstream Company's Imputed Interest Rate		5.54-11.21%		7.32-11.73%	
Interest Rate Volatility(1)		40.08%		37.08%	
Expected Time to Exercise of the Exchange Option		4.45 years		5.45 Years	
Assumed Number of Units Exchanged		375,000		625,000	
(1)A 1% change in either direction of the interest rate volatility assumption in any period would not have a significant effect on the valuation of the embedded feature.

Refer to Note 11—Series A Cumulative Redeemable Preferred Units within Part IV, Item 15 of this Annual Report on Form 10-K for further discussion.

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ITEM 7A. QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK
Quantitative and Qualitative Disclosure About Market Risk
The Company is exposed to various market risks, including the effects of adverse changes in commodity prices and credit risk as described below. The Company continually monitors its market risk exposure, including the impact and developments related to the COVID-19 pandemic, which introduced significant volatility and uncertainties in the financial markets during 2020 and 2021.
Commodity Price Risk
Currently, a majority of the Company’s midstream service agreements are fee-based, with no direct commodity price exposure to oil, natural gas, or NGLs, and only an immaterial portion of the agreements are based on the underlying value of a commodity. However, the Company is indirectly exposed to adverse changes in commodity prices through Apache and potential third-party customers’ economic decisions to develop and produce oil and natural gas from which Altus receives revenues for providing gathering, processing, and transmission services.
Fluctuations in commodity prices also impact operating cost elements both directly and indirectly. For example, commodity prices directly impact costs such as power and fuel, which are expenses that increase or decrease in line with changes in commodity prices. Commodity prices also affect industry activity and demand, thus indirectly impacting the cost of items such as labor and equipment rentals. Management regularly reviews the Company’s potential exposure to commodity price risk, and may periodically enter into financial or physical arrangements intended to mitigate potential volatility.
Interest Rate Risk
At December 31, 2021, Altus Midstream had $657.0 million of proceeds drawn on its revolving credit facility. The interest rate for the facility is variable, which exposes the Company to the risk of increased interest expense in the event of increases to short-term interest rates. If interest rates increased by 1.0 percent, the Company’s annual consolidated interest expense would have increased by approximately $6.7 million. Accordingly, results of operations, cash flows, financial condition, and the ability to make cash distributions could be adversely affected by significant increases in interest rates. Altus currently has no interest rate derivative instruments outstanding, but the Company continues to monitor its interest rate exposure and may enter into interest rate derivative instruments in the future if it determines that it is necessary to invest in such instruments in order to mitigate its interest rate risk.
Credit Risk
The Company is subject to credit risk resulting from nonpayment or nonperformance by, or the insolvency or liquidation of, Apache or third-party customers. Any increase in the nonpayment and nonperformance by, or the insolvency or liquidation of, the Company’s customers could adversely affect the Company’s results of operations.

ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA
The financial statements and supplementary financial information required to be filed under this Item 8 are presented on pages F-1 through F-37 in Part IV, Item 15 of this Annual Report on Form 10-K and are incorporated herein by reference.

ITEM 9. CHANGES IN AND DISAGREEMENTS WITH ACCOUNTANTS ON ACCOUNTING AND FINANCIAL DISCLOSURE
Not applicable.
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ITEM 9A. CONTROLS AND PROCEDURES
Disclosure Controls and Procedures
The Company’s Chief Executive Officer and President, in his capacity as principal executive officer, and the Company’s Chief Financial Officer and Treasurer, in his capacity as principal financial officer, evaluated the effectiveness of the Company’s disclosure controls and procedures as of December 31, 2021, the end of the period covered by this Annual Report on Form 10-K. Based on that evaluation and as of the date of that evaluation, these officers concluded that the Company’s disclosure controls and procedures were effective, providing effective means to ensure that the information the Company is required to disclose under applicable laws and regulations is recorded, processed, summarized, and reported within the time periods specified in the Commission’s rules and forms and accumulated and communicated to the Company’s management, including its principal executive officer and principal financial officer, to allow timely decisions regarding required disclosure.
The Company periodically reviews the design and effectiveness of its disclosure controls, including compliance with various laws and regulations that apply to operations. The Company makes modifications to improve the design and effectiveness of its disclosure controls, and may take other corrective action, if the Company’s reviews identify deficiencies or weaknesses in its controls.
Management’s Annual Report on Internal Control Over Financial Reporting
The management report called for by Item 308(a) of Regulation S-K is incorporated herein by reference to the “Report of Management on Internal Control Over Financial Reporting,” included on page F-1 in Part IV, Item 15 of this Annual Report on Form 10-K.
The Company is an “emerging growth company,” as defined in Section 2(a) of the Securities Act, as modified by the JOBS Act and is not required to comply with the independent registered public accounting firm attestation requirements of Section 404 of the Sarbanes-Oxley Act. As such, this Annual Report on Form 10-K does not include an attestation report of the Company’s independent registered public accounting firm regarding internal control over financial reporting.
Changes in Internal Control Over Financial Reporting
There were no changes in the Company’s internal controls over financial reporting during the quarter ended December 31, 2021 that have materially affected, or are reasonably likely to materially affect, the Company’s internal controls over financial reporting.

ITEM 9B. OTHER INFORMATION
None.

ITEM 9C. DISCLOSURE REGARDING FOREIGN JURISDICTIONS THAT PREVENT INSPECTIONS
Not applicable.

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PART III
ITEM 10. DIRECTORS, EXECUTIVE OFFICERS AND CORPORATE GOVERNANCE
The information set forth under the captions “Election of Directors” and “Information About Our Executive Officers” in the proxy statement relating to the Company’s 2022 Annual Meeting of Stockholders, which will be filed no later than 120 days after December 31, 2021 (the Proxy Statement), is incorporated herein by reference.
Code of Ethics
Pursuant to Rule 5610 of the Nasdaq Listing Rules, the Company is required to adopt a code of conduct for its directors, officers, and employees. The Company’s board of directors has adopted the Code of Business Conduct (Code of Conduct), which was most recently revised in December 2020. The Code of Conduct also meets the requirements of a code of ethics under Item 406 of Regulation S-K. You can access the Company’s Code of Conduct on the About - Governance page of the Company’s website at www.altusmidstream.com. Any stockholder who so requests may obtain a printed copy of the Code of Conduct without charge by submitting a request to the Company’s corporate secretary at the address on the cover of this Annual Report on Form 10-K. Changes in and waivers to the Code of Conduct for the Company’s directors, chief executive officer, and certain senior financial officers will be posted on the Company’s website within four business days and maintained for at least 12 months. Information on the Company’s website or any other website is not incorporated by reference into, and does not constitute a part of, this Annual Report on Form 10-K.

ITEM 11. EXECUTIVE COMPENSATION
The information set forth under the caption “Executive Compensation” in the Proxy Statement is incorporated herein by reference.

ITEM 12. SECURITY OWNERSHIP OF CERTAIN BENEFICIAL OWNERS AND MANAGEMENT AND RELATED STOCKHOLDER MATTERS
The information set forth under the captions “Securities Ownership and Principal Holders,” “Securities Authorized for Issuance Under Equity Compensation Plans,” and “Delinquent Section 16(a) Reports” (if such a caption is included) in the Proxy Statement is incorporated herein by reference.

ITEM 13. CERTAIN RELATIONSHIPS AND RELATED TRANSACTIONS, AND DIRECTOR INDEPENDENCE
See Note 2—Transactions with Affiliates of the Company’s financial statements, under Item 8 above, for information regarding payments to or from Apache Corporation. The information set forth under the captions “Certain Business Relationships and Transactions” and “Director Independence” in the Proxy Statement is incorporated herein by reference.

ITEM 14. PRINCIPAL ACCOUNTING FEES AND SERVICES
The information set forth under the caption “Ratification of Appointment of Independent Auditor” in the Proxy Statement is incorporated herein by reference.

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PART IV

ITEM 15. EXHIBITS, FINANCIAL STATEMENT SCHEDULES

(a)Documents included in this Annual Report on Form 10-K:

1.	Financial Statements	

Report of Management on Internal Control Over Financial Reporting	F-1	
		
Report of Independent Registered Public Accounting Firm (PCAOB ID: 42)	F-2	
		
Report of Independent Registered Public Accounting Firm (PCAOB ID: 243)	F-3	
		
Report of Independent Registered Public Accounting Firm (PCAOB ID: 185)	F-4	
		
Report of Independent Registered Public Accounting Firm (PCAOB ID: 243)	F-5	
		
Consolidated Statements of Operations for the Years Ended December 31, 2021, 2020, and 2019	F-6	
		
Statement of Consolidated Comprehensive Income (Loss) for the Years Ended December 31, 2021, 2020, and 2019	F-7	
		
Consolidated Balance Sheet at December 31, 2021 and December 31, 2020	F-8	
		
Consolidated Statements of Cash Flows for the Years Ended December 31, 2021, 2020, and 2019	F-9	
		
Statements of Consolidated Changes in Equity and Noncontrolling Interests for the Years Ended December 31, 2021, 2020, and 2019	F-10	
		
Notes to Consolidated Financial Statements	F-11	

2.	Financial Statement Schedules	
	Financial statement schedules have been omitted because they are either not required, not applicable or the information required to be presented is included in the Company’s financial statements and related notes.	
	Pursuant to Rule 3-09 of Regulation S-X, the audited financial statements of Gulf Coast Express Pipeline LLC, Breviloba, LLC, Permian Highway Pipeline LLC, and EPIC Crude Holdings, LP, which are equity method interests of the Company, are included in the Annual Report on Form 10-K as Exhibits 99.1, 99.2, 99.3, and 99.4, respectively.	

3.	Exhibits	
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INDEX TO EXHIBITS

EXHIBIT NO.		DESCRIPTION	
2.1***	–	Contribution Agreement, dated as of August 8, 2018, by and among Kayne Anderson Acquisition Corp., Altus Midstream LP, Apache Midstream LLC, Altus Midstream Gathering LP, Altus Midstream Pipeline LP, Altus Midstream Processing LP, Altus Midstream NGL Pipeline LP and Altus Midstream Subsidiary GP LLC (incorporated by reference to Exhibit 2.1 to the Company’s Current Report on Form 8-K filed on August 8, 2018, SEC File No. 001-38048).	
2.2***	–	Contribution Agreement, dated as of October 21, 2021, by and among Altus Midstream Company, Altus Midstream LP, New BCP Raptor Holdco, LLC and BCP Raptor Holdco, LP (incorporated by reference to Exhibit 2.1 to the Company’s Current Report on Form 8-K filed on October 21, 2021, SEC File No. 001-38048).	
3.1	–	Second Amended and Restated Certificate of Incorporation (incorporated by reference to Exhibit 3.1 to the Company’s Current Report on Form 8-K filed on November 13, 2018, SEC File No. 001-38048).	
3.2	–	First Amendment to Second Amended and Restated Certificate of Incorporation (incorporated by reference to Exhibit 3.1 to the Company's Current Report on Form 8-K filed on July 1, 2020, SEC File No. 001-38048).	
3.3	–	Bylaws (incorporated by reference to Exhibit 3.3 to the Company’s Registration Statement on Form S-1 filed on March 7, 2017, SEC File No. 333-216514).	
4.1	–	Description of Securities of the Registrant (incorporated by reference to Exhibit 4.1 to the Company’s Annual Report on Form 10-K for the year ended December 31, 2019, SEC File No. 001-38048).	
4.2	–	Specimen Common Stock Certificate (incorporated by reference to Exhibit 4.2 to the Company’s Amendment No. 1 to Registration Statement on Form S-1/A filed on March 16, 2017, SEC File No. 333-216514).	
4.3	–	Specimen Warrant Certificate (incorporated by reference to Exhibit 4.3 to the Company’s Amendment No. 1 to Registration Statement on Form S-1/A filed on March 16, 2017, SEC File No. 333-216514).	
4.4	–	Warrant Agreement, dated March 29, 2017, by and between American Stock Transfer & Trust Company, LLC and the Company (incorporated by reference to Exhibit 4.1 to the Company’s Current Report on Form 8-K filed on April 4, 2017, SEC File No. 001-38048).	
4.5	–	Warrant Agreement, dated as of November 9, 2018, by and between American Stock Transfer & Trust Company, LLC and the Company (incorporated by reference to Exhibit 4.3 to the Company’s Current Report on Form 8-K filed on November 13, 2018, SEC File No. 001-38048).	
4.6	–	Stockholders Agreement, dated as of November 9, 2018, by and among Altus Midstream Company, Kayne Anderson Sponsor, LLC and Apache Midstream LLC (incorporated by reference to Exhibit 4.1 to the Company’s Current Report on Form 8-K filed on November 13, 2018, SEC File No. 001-38048).	
4.7	–	Amended and Restated Registration Rights Agreement, dated as of November 9, 2018, by and among Altus Midstream Company, Kayne Anderson Sponsor, LLC, the other holders party thereto and Apache Midstream LLC (incorporated by reference to Exhibit 4.2 to the Company’s Current Report on Form 8-K filed on November 13, 2018, SEC File No. 001-38048).	
4.8	–	Registration Rights Agreement, dated as of June 12, 2019, by and among Altus Midstream Company and the security holders party thereto (incorporated by reference to Exhibit 4.1 to the Company’s Current Report on Form 8-K filed on June 14, 2019, SEC File No. 001-38048).	
10.1	–	Credit Agreement, dated as of November 9, 2018, among Altus Midstream, LP, the lenders party thereto, the issuing banks party thereto, JPMorgan Chase Bank, N.A., as Administrative Agent, Wells Fargo Bank, National Association, as Syndication Agent, Citibank, N.A., Bank of America, N.A., The Toronto-Dominion Bank, New York Branch, MUFG Bank Ltd., and The Bank of Nova Scotia, Houston Branch, as Co-Documentation Agents (incorporated by reference to Exhibit 10.1 to the Company’s Current Report on Form 8-K filed on November 13, 2018, SEC File No. 001-38048).	
10.2	–	First Amendment to Credit Agreement, dated as of April 17, 2019 but effective May 8, 2019, among Altus Midstream LP, the lenders party thereto, the swingline lender party thereto, the issuing banks party thereto, JPMorgan Chase Bank, N.A., as Administrative Agent, and the other agents party thereto (incorporated by reference to Exhibit 10.2 to the Company’s Current Report on Form 8-K filed on May 13, 2019, SEC File No. 001-38048).	
10.3	–	Second Amendment to Credit Agreement, dated as of February 7, 2020, among Altus Midstream LP, the lenders party thereto, the swingline lender party thereto, the issuing banks party thereto, JPMorgan Chase Bank, N.A., as Administrative Agent, and the other agents party thereto (incorporated by reference to Exhibit 10.1 to the Company’s Current Report on Form 8-K filed on February 11, 2020, SEC File No. 001-38048).	
10.4	–	Construction, Operations and Maintenance Agreement, dated as of November 9, 2018, by and between Altus Midstream Company and Apache Corporation (incorporated by reference to Exhibit 10.3 to the Company’s Current Report on Form 8-K filed on November 13, 2018, SEC File No. 001-38048).	
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10.5	–	Side Letter re: Waiver of Direct G&A Costs, dated as of April 23, 2019, by and between Altus Midstream Company and Apache Corporation (incorporated by reference to Exhibit 10.1 to the Company’s Quarterly Report on Form 10-Q filed May 2, 2019, SEC File No. 001-38048).	
10.6	–	Purchase Rights and Restrictive Covenants Agreement, dated as of November 9, 2018, by and between Altus Midstream Company and Apache Corporation (incorporated by reference to Exhibit 10.4 to the Company’s Current Report on Form 8-K filed on November 13, 2018, SEC File No. 001-38048).	
10.7	–	Lease Agreement, dated as of November 9, 2018, by and between Apache Corporation and Altus Midstream LP (incorporated by reference to Exhibit 10.5 to the Company’s Current Report on Form 8-K filed on November 13, 2018, SEC File No. 001-38048).	
10.8	–	First Amendment to Lease Agreement, dated effective July 27, 2020, by and between Apache Corporation and Altus Midstream LP (incorporated by reference to Exhibit 10.2 to the Company’s Quarterly Report on Form 10-Q for the quarterly period ended June 30, 2020, SEC File No. 001-38048)	
10.9	–	Trademark License Agreement, dated as of November 9, 2018, by and between Apache Corporation and Altus Midstream LP (incorporated by reference to Exhibit 10.6 to the Company’s Current Report on Form 8-K filed on November 13, 2018, SEC File No. 001-38048).	
10.10	–	Trademark License Agreement, dated as of November 9, 2018, by and between Apache Corporation and Kayne Anderson Acquisition Corp. (n/k/a Altus Midstream Company) (incorporated by reference to Exhibit 10.7 to the Company’s Current Report on Form 8-K filed on November 13, 2018, SEC File No. 001-38048).	
10.11‡	–	Intrastate Firm Natural Gas Transportation Service Agreement, dated April 1, 2017, by and between Apache Corporation and Altus Midstream Pipeline LP (incorporated by reference to Exhibit 10.15 of the Company’s Annual Report on Form 10-K for year ended December 31, 2018, SEC File No. 001-38048).	
10.12‡	–	Gas Gathering Agreement, dated July 1, 2018, by and between Apache Corporation and Altus Midstream Gathering LP (incorporated by reference to Exhibit 10.17 of the Company’s Annual Report on Form 10-K for year ended December 31, 2018, SEC File No. 001-38048).	
10.13‡	–	Transportation Services Agreement, dated July 1, 2018, by and between Apache Corporation and Altus Midstream NGL Pipeline LP (incorporated by reference to Exhibit 10.18 of the Company’s Annual Report on Form 10-K for year ended December 31, 2018, SEC File No. 001-38048).	
10.14‡	–	Gas Processing Agreement, dated effective September 1, 2021, by and between Apache Corporation and Altus Midstream Processing LP (incorporated by reference to Exhibit 10.1 to the Company’s Current Report on Form 8-K filed on October 14, 2021, SEC File No. 001-38048).	
10.15†	–	Altus Midstream Company Restricted Stock Units Plan, dated December 17, 2018 (incorporated by reference to Exhibit 10.19 of the Company’s Annual Report on Form 10-K for year ended December 31, 2018, SEC File No. 001-38048).	
10.16†	–	Form of Director Grant Agreement, dated December 17, 2018 (incorporated by reference to Exhibit 10.20 of the Company’s Annual Report on Form 10-K for year ended December 31, 2018, SEC File No. 001-38048).	
10.17†	–	Altus Midstream Company 2019 Omnibus Compensation Plan, dated February 12, 2019, effective May 30, 2019 (incorporated by reference to Exhibit 10.1 to the Company’s Current Report on Form 8-K filed May 31, 2019, SEC File No. 001-38048).	
10.18†	–	Altus Midstream Company Deferred Delivery Plan, dated May 30, 2019 (incorporated by reference to Exhibit 10.2 to the Company’s Current Report on Form 8-K filed on May 31, 2019, SEC File No. 001-38048).	
10.19	–	Second Amended and Restated Agreement of Limited Partnership of Altus Midstream LP, dated as of June 12, 2019 (incorporated by reference to Exhibit 10.1 to the Company’s Current Report on Form 8-K filed on June 14, 2019, SEC File No. 001-38048).	
10.20	–	First Amendment to Second Amended and Restated Agreement of Limited Partnership of Altus Midstream LP, dated as of June 30, 2020 (incorporated by reference to Exhibit 10.1 to the Company’s Quarterly Report on Form 10-Q for the quarterly period ended June 30, 2020, SEC File No. 001-38048).	
10.21	–	Voting Agreement, dated as of June 12, 2019, by and among Apache Corporation, Altus Midstream Company, and the purchasers party thereto (incorporated by reference to Exhibit 10.2 to the Company’s Current Report on Form 8-K filed on June 14, 2019, SEC File No. 001-38048).	
21.1*	–	Subsidiaries of the Company.	
23.1*	–	Consent of Ernst & Young LLP.	
23.2*	–	Consent of Ernst & Young LLP.	
23.3*	–	Consent of BDO USA, LLP relating to the financial statements of Gulf Coast Express Pipeline LLC.	
23.4*	–	Consent of BDO USA, LLP relating to the financial statements of Permian Highway Pipeline LLC.	
23.5*	–	Consent of KPMG LLP.	
24.1*	–	Power of Attorney (included on signature page hereto).	
49

									
31.1*	–	Certification of the Principal Executive Officer required by Rule 13a-14(a) or Rule 15d-14(a).	
31.2*	–	Certification of the Principal Financial Officer required by Rule 13a-14(a) or Rule 15d-14(a).	
32.1**	–	Certification of the Principal Executive Officer and Principal Financial Officer required by Rule 13a-14(a) or Rule 15d-14(b) and 18 U.S.C. 1350.	
99.1*	–	Gulf Coast Express Pipeline LLC audited financial statements as of December 31, 2021.	
99.2*	–	Breviloba, LLC audited financial statements as of December 31, 2021.	
99.3*	–	Permian Highway Pipeline LLC audited financial statements as of December 31, 2021.	
99.4*	–	EPIC Crude Holdings, LP audited financial statements as of December 31, 2020.	
101.INS*	–	Inline XBRL Instance Document. (the instance document does not appear in the Interactive Data File because its XBRL tags are embedded within the Inline XBRL document).	
101.SCH*	–	Inline XBRL Taxonomy Schema Document.	
101.CAL*	–	Inline XBRL Calculation Linkbase Document.	
101.DEF*	–	Inline XBRL Definition Linkbase Document.	
101.LAB*	–	Inline XBRL Label Linkbase Document.	
101.PRE*	–	Inline XBRL Presentation Linkbase Document.	
104*	–	Cover Page Interactive Data File (formatted as Inline XBRL and contained in Exhibit 101).	

* Filed herewith.	
** Furnished herewith	
*** Schedules and exhibits to this Exhibit have been omitted pursuant to Regulation S-K Item 601(b)(2). The Company agrees to furnish supplementally a copy of any omitted schedule or exhibit to the SEC upon request.	
† Management contracts or compensatory plans or arrangements required to be filed herewith pursuant to Item 15 hereof.	
‡ Portions have been omitted pursuant to Regulation S-K Item 601(b)(10)(iv), because the omitted information is both not material and is the type that the Company treats as private or confidential.	

ITEM 16. FORM 10-K SUMMARY
None.

50

SIGNATURES

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

                                ALTUS MIDSTREAM COMPANY

/s/ Clay Bretches                    
Clay Bretches
Chief Executive Officer and President

Dated: February 22, 2022

POWER OF ATTORNEY
The officers and directors of Altus Midstream Company, whose signatures appear below, hereby constitute and appoint Clay Bretches and Ben C. Rodgers, and each of them (with full power to each of them to act alone), the true and lawful attorney-in-fact to sign and execute, on behalf of the undersigned, any amendment(s) to this report and each of the undersigned does hereby ratify and confirm all that said attorneys shall do or cause to be done by virtue thereof.

Pursuant to the requirements of the Securities Exchange Act of 1934, this report has been signed below by the following persons on behalf of the registrant and in the capacities and on the dates indicated.

															
Name	  	Title	  	Date	
/s/ Clay Bretches
Clay Bretches	  	Director, Chief Executive Officer, and President
(principal executive officer)	  	February 22, 2022	
/s/ Ben C. Rodgers
Ben C. Rodgers	  	Director, Chief Financial Officer, and Treasurer
 (principal financial officer)	  	February 22, 2022	
/s/ Rebecca A. Hoyt
Rebecca A. Hoyt		Senior Vice President, Chief Accounting Officer and Controller
(principal accounting officer)		February 22, 2022	
/s/ Mark Borer
Mark Borer	  	Director	  	February 22, 2022	
/s/ Staci L. Burns
Staci L. Burns	  	Director	  	February 22, 2022	
/s/ Joe C. Frana
Joe C. Frana	  	Director	  	February 22, 2022	
/s/ D. Mark Leland
D. Mark Leland	  	Director	  	February 22, 2022	
/s/ Kevin S. McCarthy
Kevin S. McCarthy	  	Director	  	February 22, 2022	
/s/ Christopher J. Monk
Christopher J. Monk		Director		February 22, 2022	
/s/ Stephen P. Noe
Stephen P. Noe		Director		February 22, 2022	
/s/ Robert S. Purgason
Robert S. Purgason	  	Director	  	February 22, 2022	
/s/ Jon W. Sauer
Jon W. Sauer	  	Director, Chairman of the Board, and Senior Vice President	  	February 22, 2022	

51

REPORT OF MANAGEMENT ON INTERNAL CONTROL OVER FINANCIAL REPORTING
Management of the Company is responsible for the preparation and integrity of the consolidated financial statements appearing in this annual report on Form 10-K. The financial statements were prepared in conformity with accounting principles generally accepted in the United States and include amounts that are based on management’s best estimates and judgments.
Management of the Company is responsible for establishing and maintaining effective internal control over financial reporting as such term is defined in Rule 13a-15(f) under the Securities Exchange Act of 1934. The Company’s internal control over financial reporting is designed to provide reasonable assurance regarding the reliability of financial reporting and the preparation of the consolidated financial statements. Our internal control over financial reporting is supported by a program of internal audits and appropriate reviews by management, written policies and guidelines, careful selection and training of qualified personnel and a written code of business conduct adopted by our Company’s board of directors, applicable to all Company directors and all officers of our Company.
Because of its inherent limitations, internal control over financial reporting may not prevent or detect misstatements and even when determined to be effective, can only provide reasonable assurance with respect to financial statement preparation and presentation. 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 December 31, 2021. In making this assessment, management used the criteria set forth by the Committee of Sponsoring Organizations of the Treadway Commission in Internal Control – Integrated Framework (2013). Based on our assessment, management believes that the Company maintained effective internal control over financial reporting as of December 31, 2021.
The Company’s independent auditors, Ernst & Young LLP, a registered public accounting firm, are appointed by the Audit Committee of the Company’s board of directors. Ernst & Young LLP have audited and reported on the consolidated financial statements of Altus Midstream Company and its subsidiaries. The report of the independent auditors follows this report on page F-2.
The Company is an “emerging growth company,” as defined in Section 2(a) of the Securities Act, as modified by the JOBS Act and is not required to comply with the independent registered public accounting firm attestation requirements of Section 404 of the Sarbanes-Oxley Act. As such, this annual report on Form 10-K does not include an attestation report of our independent registered public accounting firm regarding internal control over financial reporting.

			
/s/ Clay Bretches	
Chief Executive Officer and President	
(principal executive officer)	
	
/s/ Ben C. Rodgers	
Chief Financial Officer and Treasurer	
(principal financial officer)	
	
/s/ Rebecca A. Hoyt	
Senior Vice President, Chief Accounting Officer and Controller	
(principal accounting officer)	

Houston, Texas
February 22, 2022

F-1

REPORT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM
To the Shareholders and the Board of Directors of Altus Midstream Company:
Opinion on the Financial Statements

We have audited the accompanying consolidated balance sheet of Altus Midstream Company (the Company) as of December 31, 2021 and 2020, the related consolidated statements of operations, comprehensive income (loss), cash flows and changes in equity and noncontrolling interests for each of the three years in the period ended December 31, 2021, and the related notes (collectively referred to as the “consolidated financial statements”). In our opinion, based on our audits and the reports of other auditors, the consolidated financial statements present fairly, in all material respects, the financial position of the Company at December 31, 2021 and 2020, and the results of its operations and its cash flows for each of the three years in the period ended December 31, 2021, in conformity with U.S. generally accepted accounting principles.

We did not audit the financial statements of Gulf Coast Express Pipeline LLC (“GCX”), an entity in which the Company has a 16% interest, for the years ended December 31, 2021, 2020 and 2019; EPIC Crude Holdings, LP (“EPIC”), an entity in which the Company has a 15% interest, for the year ended December 31, 2020; or Permian Highway Pipeline LLC (“PHP”), an entity in which the Company has an approximately 26.7% interest, for the year ended December 31, 2019. In the consolidated financial statements, the Company’s equity method interest in GCX is stated at approximately $274 million and $284 million as of December 31, 2021 and 2020, respectively, and the Company’s income from equity method interest, net, of GCX is stated at approximately $40 million in 2021, $42 million in 2020, and $18 million in 2019. The Company’s equity method interest in EPIC is approximately $177 million as of December 31, 2020, and the Company’s loss from equity method interest, net, of EPIC is approximately $16 million for the year ended December 31, 2020. The Company’s equity method interest in PHP is approximately $310 million as of December 31, 2019, and the Company’s income from equity method interest, net, of PHP is approximately $0.4 million for the year ended December 31, 2019. Those statements were audited by other auditors whose reports have been furnished to us, and our opinion, insofar as it relates to the amounts included for GCX, EPIC and PHP, is based solely on the reports of the other auditors.

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 Public Company Accounting Oversight Board (United States) (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. The Company is not required to have, nor were we engaged to perform, an audit of its internal control over financial reporting. As part of our audits we are required to obtain an understanding of internal control over financial reporting but not for the purpose of expressing an opinion on the effectiveness of the Company’s internal control over financial reporting. Accordingly, we express no such opinion.

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 and the reports of other auditors provide a reasonable basis for our opinion.

/s/ Ernst & Young LLP

We have served as the Company’s auditor since 2018.

Houston, Texas
February 22, 2022

F-2

Report of Independent Registered Public Accounting Firm
Board of Directors and Members
Gulf Coast Express Pipeline LLC
Houston, Texas
Opinion on the Financial Statements
We have audited the accompanying balance sheets of Gulf Coast Express Pipeline LLC (the “Company”) as of December 31, 2021 and 2020, the related statements of income, members’ equity and cash flows for each of the three years ended December 31, 2021, and the related notes (collectively referred to as the “financial statements”). In our opinion, the financial statements present fairly, in all material respects, the financial position of the Company at December 31, 2021 and 2020, and the results of its operations and its cash flows for each of the three years ended December 31, 2021, in conformity with accounting principles generally accepted in the United States of America.
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 Public Company Accounting Oversight Board (United States) (“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 and in accordance with auditing standards generally accepted in the United States of America. 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. The Company is not required to have, nor were we engaged to perform, an audit of its internal control over financial reporting. As part of our audit we are required to obtain an understanding of internal control over financial reporting but not for the purpose of expressing an opinion on the effectiveness of the Company’s internal control over financial reporting. Accordingly, we express no such opinion.

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
Critical audit matters are matters arising from the current period audit of the financial statements that were communicated or required to be communicated to the audit committee and that: (1) relate to accounts or disclosures that are material to the financial statements and (2) involved our especially challenging, subjective, or complex judgments. We determined that there are no critical audit matters.

Emphasis of Matter — Significant Transactions with Related Parties
As discussed in Note 4 to the financial statements, the Company has entered into significant transactions with related parties.

/s/ BDO USA, LLP

We have served as the Company's auditor since 2020.

Houston, Texas
February 16, 2022
F-3

Report of Independent Registered Public Accounting Firm

To the Board of Directors and Owners
EPIC Crude Holdings, LP:

Opinion on the Consolidated Financial Statements

We have audited the accompanying consolidated balance sheet of EPIC Crude Holdings, LP and subsidiaries (the Partnership) as of December 31, 2020, the related consolidated statements of operations, changes in owners’ equity, and cash flows for the year then ended, and the related notes (collectively, the consolidated financial statements). In our opinion, the consolidated financial statements present fairly, in all material respects, the financial position of the Partnership as of December 31, 2020, and the results of its operations and its cash flows for the year then ended, in conformity with U.S. generally accepted accounting principles.

The consolidated financial statements of the Partnership as of December 31, 2019 and for the year then ended were audited by other auditors whose report dated March 11, 2020, expressed an unmodified opinion on those consolidated financial statements.

Basis for Opinion

These consolidated financial statements are the responsibility of the Partnership’s management. Our responsibility is to express an opinion on these consolidated financial statements based on our audit. We are a public accounting firm registered with the Public Company Accounting Oversight Board (United States) (PCAOB) and are required to be independent with respect to the Partnership 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 and in accordance with auditing standards generally accepted in the United States of America. Those standards require that we plan and perform the audit to obtain reasonable assurance about whether the consolidated financial statements are free of material misstatement, whether due to error or fraud. Our audit included performing procedures to assess the risks of material misstatement of the consolidated 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 consolidated financial statements. Our audit also included evaluating the accounting principles used and significant estimates made by management, as well as evaluating the overall presentation of the consolidated financial statements. We believe that our audit provides a reasonable basis for our opinion.

/s/ KPMG LLP

We have served as the Partnership’s auditor since 2020.

San Antonio, Texas
February 25, 2021

F-4

Report of Independent Registered Public Accounting Firm

Board of Directors and Members
Permian Highway Pipeline LLC
Houston, Texas
Opinion on the Financial Statements
We have audited the accompanying statements of operations, members’ equity, and cash flows of Permian Highway Pipeline LLC (the “Company”) for the year ended December 31, 2019, and the related notes (collectively referred to as the “financial statements”). In our opinion, the financial statements present fairly, in all material respects, the results of its operations and its cash flows for the year ended December 31, 2019, in conformity with accounting principles generally accepted in the United States of America.
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 audit. We are a public accounting firm registered with the Public Company Accounting Oversight Board (United States) (“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 and in accordance with auditing standards generally accepted in the United States of America. 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 audit 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 audit 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 audit provides a reasonable basis for our opinion.
Emphasis of Matter — Significant Transactions with Related Parties
As discussed in Note 3 to the financial statements, the Company has entered into significant transactions with related parties.

/s/ BDO USA, LLP
We have served as the Company's auditor since 2020.

Houston, Texas
March 16, 2020
F-5

ALTUS MIDSTREAM COMPANY
CONSOLIDATED STATEMENTS OF OPERATIONS

 		For the Year Ended December 31,	
 		2021		2020		2019	
							
		(In thousands, except per share data)	
REVENUES:							
Midstream services revenue — affiliate (Note 3)		$	142,727 			$	144,714 			$	135,798 		
Product sales — affiliate (Note 3)		9,754 			— 			— 		
Product sales — third parties		8,136 			3,695 			— 		
Total revenues		160,617 			148,409 			135,798 		
COSTS AND EXPENSES:							
Costs of product sales — affiliate (Note 3)		9,754 			— 			— 		
Costs of product sales — third parties		7,793 			2,988 			— 		
Operations and maintenance(1)		32,748 			37,993 			55,858 		
General and administrative(2)		14,182 			13,155 			10,301 		
Depreciation and accretion		16,201 			15,945 			41,480 		
Impairments		441 			1,643 			1,300,719 		
Taxes other than income		13,886 			15,069 			13,231 		
Total costs and expenses		95,005 			86,793 			1,421,589 		
OPERATING INCOME (LOSS)		65,612 			61,616 			(1,285,791)		
Unrealized derivative instrument gain (loss)		82,114 			(36,080)			(8,470)		
Interest income		4 			9 			3,606 		
Income from equity method interests, net		113,764 			58,739 			19,069 		
Impairment on equity method interests		(160,441)			— 			— 		
Warrants valuation adjustment		664 			1,200 			11,180 		
Transaction costs		(4,472)			— 			— 		
Other		12,574 			(2,306)			(622)		
Total other income		44,207 			21,562 			24,763 		
Financing costs, net of capitalized interest		10,598 			2,190 			1,792 		
NET INCOME (LOSS) BEFORE INCOME TAXES		99,221 			80,988 			(1,262,820)		
Current income tax benefit		— 			(696)			(15)		
Deferred income tax expense		— 			— 			64,915 		
NET INCOME (LOSS) INCLUDING NONCONTROLLING INTERESTS		99,221 			81,684 			(1,327,720)		
Net income attributable to Preferred Unit limited partners		161,906 			75,906 			38,809 		
NET INCOME (LOSS) ATTRIBUTABLE TO COMMON SHAREHOLDERS		(62,685)			5,778 			(1,366,529)		
Net income (loss) attributable to Apache limited partner		(48,741)			2,987 			(1,008,039)		
NET INCOME (LOSS) ATTRIBUTABLE TO CLASS A COMMON SHAREHOLDERS		$	(13,944)			$	2,791 			$	(358,490)		
							
NET INCOME (LOSS) ATTRIBUTABLE TO CLASS A COMMON SHAREHOLDERS, PER SHARE(3)							
Basic		$	(3.72)			$	0.75 			$	(95.70)		
Diluted		(3.86)			0.36 			(95.70)		
WEIGHTED AVERAGE SHARES(3)							
Basic		3,746		3,746		3,746	
Diluted		16,246		16,246		3,746	
(1)Includes amounts of $5.6 million, $5.4 million, and $8.8 million associated with related parties for the years ended December 31, 2021, 2020, and 2019, respectively. Refer to Note 2—Transactions with Affiliates.
(2)Includes amounts of $9.1 million, $7.0 million, and $5.4 million associated with related parties for the years ended December 31, 2021, 2020, and 2019, respectively. Refer to Note 2—Transactions with Affiliates.
(3)Share and per share amounts have been retroactively restated to reflect the Company’s reverse stock split, which was effected June 30, 2020. Refer to Note—10 Equity and Warrants for further information.
The accompanying notes to consolidated financial statements are an integral part of this statement.
F-6

ALTUS MIDSTREAM COMPANY
STATEMENT OF CONSOLIDATED COMPREHENSIVE INCOME (LOSS)

		For the Year Ended December 31,	
		2021		2020		2019	
							
		(In thousands)	
NET INCOME (LOSS) INCLUDING NONCONTROLLING INTERESTS		$	99,221 			$	81,684 			$	(1,327,720)		
OTHER COMPREHENSIVE INCOME (LOSS), NET OF TAX:							
Share of equity method interests other comprehensive income (loss)		630 			523 			(1,152)		
COMPREHENSIVE INCOME (LOSS) INCLUDING NONCONTROLLING INTERESTS		99,851 			82,207 			(1,328,872)		
Comprehensive income attributable to Preferred Unit limited partners		161,906 			75,906 			38,809 		
Comprehensive income (loss) attributable to Apache limited partner		(48,256)			3,389 			(1,008,925)		
COMPREHENSIVE INCOME (LOSS) ATTRIBUTABLE TO CLASS A COMMON SHAREHOLDERS		$	(13,799)			$	2,912 			$	(358,756)		

The accompanying notes to consolidated financial statements are an integral part of this statement.
F-7

ALTUS MIDSTREAM COMPANY
CONSOLIDATED BALANCE SHEET

		December 31,	
 		2021		2020	
					
		(In thousands, except per share data)	
ASSETS					
CURRENT ASSETS:					
Cash and cash equivalents		$	131,963 			$	24,188 		
Accounts receivable		2,249 			1,033 		
Accounts receivable from Apache Corporation (Note 1)		9,875 			446 		
Revenue receivables (Note 3)		13,717 			11,378 		
Inventories		2,958 			3,597 		
Prepaid assets and other		5,866 			2,127 		
		166,628 			42,769 		
	
PROPERTY, PLANT, AND EQUIPMENT:					
Property, plant, and equipment		211,700 			208,870 		
Less: Accumulated depreciation and accretion		(24,713)			(13,034)		
		186,987 			195,836 		
	
OTHER ASSETS:					
Equity method interests		1,364,826 			1,555,182 		
	
Deferred charges and other		6,229 			5,843 		
		1,371,055 			1,561,025 		
Total assets		$	1,724,670 			$	1,799,630 		
					
LIABILITIES, NONCONTROLLING INTERESTS, AND EQUITY					
CURRENT LIABILITIES:					
Distributions payable to Preferred Unit limited partners		$	11,562 			$	— 		
Dividends payable		— 			5,620 		
Distributions payable to Apache Corporation (Note 1)		— 			18,750 		
Other current liabilities (Note 6)		15,682 			5,613 		
		27,244 			29,983 		
LONG-TERM DEBT		657,000 			624,000 		
DEFERRED CREDITS AND OTHER NONCURRENT LIABILITIES:					
Asset retirement obligation		68,331 			64,062 		
	
Embedded derivative		56,895 			139,009 		
Other noncurrent liabilities		10,118 			6,424 		
		135,344 			209,495 		
Total liabilities		819,588 			863,478 		
					
COMMITMENTS AND CONTINGENCIES (Note 8)					
					
Redeemable noncontrolling interest — Apache limited partner		769,855 			575,125 		
Redeemable noncontrolling interest — Preferred Unit limited partners		712,476 			608,381 		
					
EQUITY:					
Class A Common Stock: $0.0001 par, 1,500,000,000 shares authorized, 3,746,460 shares issued and outstanding at December 31, 2021 and 2020(1)		1 			1 		
Class C Common Stock: $0.0001 par, 1,500,000,000 shares authorized, 12,500,000 shares issued and outstanding at December 31, 2021 and 2020(1)		1 			1 		
Additional paid-in capital		— 			122,222 		
Accumulated deficit		(577,251)			(369,433)		
Accumulated other comprehensive loss		— 			(145)		
		(577,249)			(247,354)		
Total liabilities, noncontrolling interests, and equity		$	1,724,670 			$	1,799,630 		
(1)Share amounts have been retroactively restated to reflect the Company’s reverse stock split, which was effected June 30, 2020. Refer to Note 10—Equity and Warrants for further information.

The accompanying notes to consolidated financial statements are an integral part of this statement.
F-8

ALTUS MIDSTREAM COMPANY
CONSOLIDATED STATEMENTS OF CASH FLOWS

 		For the Year Ended December 31,	
 		2021		2020		2019	
							
		(In thousands)	
CASH FLOWS FROM OPERATING ACTIVITIES:							
Net income (loss) including noncontrolling interests		$	99,221 			$	81,684 			$	(1,327,720)		
Adjustments to reconcile net income (loss) to net cash provided by operating activities:							
Unrealized derivative instrument (gain) loss		(82,114)			36,080 			8,470 		
Depreciation and accretion		16,201 			15,945 			41,480 		
Deferred income tax expense		— 			— 			64,915 		
Income from equity method interests, net		(113,764)			(58,739)			(19,069)		
Distributions from equity method interests		133,974 			80,747 			25,316 		
Impairments		441 			1,643 			1,300,719 		
Impairment on equity method interests		160,441 			— 			— 		
Power credit, net		(5,701)			— 			— 		
Warrants valuation adjustment		(664)			(1,200)			(11,180)		
Other		2,741 			3,368 			907 		
Changes in operating assets and liabilities:							
(Increase) decrease in inventories		356 			430 			(620)		
(Increase) decrease in prepaid assets and other		217 			(56)			3,877 		
Increase in accounts receivable		(1,216)			(1,033)			— 		
(Increase) decrease in revenue receivables (Note 2)		(2,339)			4,083 			(4,532)		
(Increase) decrease in account receivables from/payable to affiliate		(8,174)			1,043 			(6,361)		
	
Increase in accrued expenses		9,353 			280 			71 		
Increase in deferred charges, deferred credits and other noncurrent liabilities		746 			19 			— 		
NET CASH PROVIDED BY OPERATING ACTIVITIES		209,719 			164,294 			76,273 		
							
CASH FLOWS FROM INVESTING ACTIVITIES:							
Capital expenditures		(4,588)			(29,981)			(342,650)		
Proceeds from sale of assets		3,037 			10,240 			13,309 		
Contributions to equity method interests		(28,420)			(327,305)			(501,352)		
Distributions from equity method interests		38,755 			17,419 			— 		
Acquisition of equity method interests		— 			— 			(670,625)		
Capitalized interest paid		— 			(8,733)			(2,370)		
NET CASH PROVIDED BY (USED IN) INVESTING ACTIVITIES		8,784 			(338,360)			(1,503,688)		
							
CASH FLOWS FROM FINANCING ACTIVITIES:							
Redeemable noncontrolling interest - Preferred Unit limited partners, net		— 			— 			611,249 		
Distributions paid to Preferred Unit limited partners		(46,249)			(23,124)			— 		
Distributions paid to Apache limited partner		(75,000)			— 			— 		
Dividends paid		(22,479)			— 			— 		
Proceeds from revolving credit facility		33,000 			228,000 			396,000 		
Finance lease		— 			(11,789)			(22,994)		
Deferred facility fees		— 			(816)			(792)		
NET CASH PROVIDED BY (USED IN) FINANCING ACTIVITIES		(110,728)			192,271 			983,463 		
							
INCREASE (DECREASE) IN CASH AND CASH EQUIVALENTS		107,775 			18,205 			(443,952)		
CASH AND CASH EQUIVALENTS AT BEGINNING OF YEAR		24,188 			5,983 			449,935 		
CASH AND CASH EQUIVALENTS AT END OF PERIOD		$	131,963 			$	24,188 			$	5,983 		
SUPPLEMENTAL CASH FLOW DATA:							
Accrued capital expenditures(1)		$	514 			$	834 			$	18,573 		
Finance lease liability(2)		— 			— 			9,767 		
Interest paid, net of capitalized interest		9,540 			1,013 			903 		
Cash received for income tax refunds		— 			696 			527 		
(1)Includes $0.8 million due from Apache and $0.4 million and $1.5 million due to Apache of capital expenditures for the years ended December 31, 2021, 2020, and 2019, respectively, pursuant to the terms of the Construction, Operations, and Maintenance Agreement entered into at the closing of the Altus Combination. Refer to Note 2—Transactions with Affiliates for more information.
(2)The Company entered into a finance lease in the first quarter of 2019 for power generators, which ended during the first quarter of 2020. The Company then exercised its option to purchase the generators.

The accompanying notes to consolidated financial statements are an integral part of this statement.
F-9

ALTUS MIDSTREAM COMPANY
STATEMENT OF CONSOLIDATED CHANGES IN EQUITY AND NONCONTROLLING INTERESTS

	Redeemable Noncontrolling Interest — Preferred Unit Limited Partners(2)		Redeemable Noncontrolling Interest — Apache Limited Partner			Class A Common Stock		Class C Common Stock		Additional Paid-in Capital		Retained Earnings (Accumulated Deficit)		Accumulated Other Comprehensive Income (Loss)		Total Equity (Deficit)	
 						Shares(1)		Amount		Shares(1)		Amount									
																					
	(In thousands)			(In thousands)	
																					
Balance at December 31, 2018	$	— 			$	1,940,500 				3,746 			$	1 			12,500 			$	1 			$	(22,464)			$	(204,517)			$	— 			$	(226,979)		
Issuance of Series A Cumulative Redeemable Preferred Units	516,790 			— 				— 			— 			— 			— 			— 			— 			— 			— 		
Net income (loss)	38,809 			(1,008,039)				— 			— 			— 			— 			— 			(358,490)			— 			(358,490)		
Change in redemption value of noncontrolling interest	— 			(230,575)				— 			— 			— 			— 			39,792 			190,783 			— 			230,575 		
Accumulated other comprehensive loss	— 			(886)				— 			— 			— 			— 			— 			— 			(266)			(266)		
Balance at December 31, 2019	555,599 			701,000 				3,746 			1 			12,500 			1 			17,328 			(372,224)			(266)			(355,160)		
Distributions paid to Preferred Unit limited partners	(23,124)			— 				— 			— 			— 			— 			— 			— 			— 			— 		
Distributions payable to Apache limited partner	— 			(18,750)																			
Quarterly Common Dividends declared ($1.50 per share)	— 			— 				— 			— 			— 			— 			(5,620)			— 			— 			(5,620)		
Net income	75,906 			2,987 				— 			— 			— 			— 			— 			2,791 			— 			2,791 		
Change in redemption value of noncontrolling interest	— 			(110,514)				— 			— 			— 			— 			110,514 			— 			— 			110,514 		
Accumulated other comprehensive income	— 			402 				— 			— 			— 			— 			— 			— 			121 			121 		
Balance at December 31, 2020	608,381 			575,125 				3,746 			1 			12,500 			1 			122,222 			(369,433)			(145)			(247,354)		
Distributions paid to Preferred Unit limited partners	(46,249)			— 				— 			— 			— 			— 			— 			— 			— 			— 		
Distributions payable to Preferred Unit limited partners	(11,562)			— 				— 			— 			— 			— 			— 			— 			— 			— 		
Distributions paid to Apache limited partner	— 			(56,250)				— 			— 			— 			— 			— 			— 			— 			— 		
Quarterly Common Dividends declared ($1.50 per share)	— 			— 				— 			— 			— 			— 			(16,860)			— 			— 			(16,860)		
Net income (loss)	161,906 			(48,741)				— 			— 			— 			— 			— 			(13,944)			— 			(13,944)		
Change in redemption value of noncontrolling interests	— 			299,236 				— 			— 			— 			— 			(105,362)			(193,874)			— 			(299,236)		
Accumulated other comprehensive income	— 			485 				— 			— 			— 			— 			— 			— 			145 			145 		
Balance at December 31, 2021	$	712,476 			$	769,855 				3,746 			$	1 			12,500 			$	1 			$	— 			$	(577,251)			$	— 			$	(577,249)		
(1)Share amounts have been retroactively restated to reflect the Company’s reverse stock split, which was effected June 30, 2020. Refer to Note 10—Equity and Warrants for further information.
(2)Certain redemption features embedded within the Preferred Unit purchase agreement require bifurcation and measurement at fair value. For further detail, refer to Note 11—Series A Cumulative Redeemable Preferred Units.

The accompanying notes to consolidated financial statements are an integral part of this statement.
F-10

ALTUS MIDSTREAM COMPANY
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

Unless the context otherwise requires, the “Company,” “ALTM” and “Altus” refers to Altus Midstream Company and its consolidated subsidiaries. “Altus Midstream” refers to Altus Midstream LP and its consolidated subsidiaries. “Apache” refers to Apache Corporation and its consolidated subsidiaries. All references to the Company’s Class A common stock, $0.0001 par value (Class A Common Stock), and Class C common stock, $0.0001 par value (Class C Common Stock), reflect such share amounts as retrospectively restated to reflect the Company’s reverse stock split, which was effected June 30, 2020. Refer to Note—10 Equity and Warrants for further information.
Nature of Operations
Through its consolidated subsidiaries, the Company owns gas gathering, processing, and transmission assets in the Permian Basin of West Texas. Construction on the assets began in the fourth quarter of 2016, and operations commenced in the second quarter of 2017. Additionally, the Company owns equity interests in four separate Permian Basin pipeline entities that have access to various points along the Texas Gulf Coast. The Company’s operations consist of one reportable segment.
Organization
The Company originally incorporated on December 12, 2016 in Delaware under the name Kayne Anderson Acquisition Corp. (KAAC) for the purpose of effecting a merger, capital stock exchange, asset acquisition, stock purchase, reorganization or similar business combination with one or more businesses. KAAC completed its initial public offering in the second quarter of 2017.
On August 3, 2018, Altus Midstream LP was formed in Delaware as a limited partnership and wholly-owned subsidiary of KAAC. On August 8, 2018, KAAC and Altus Midstream LP entered into a contribution agreement (the Altus Contribution Agreement) with certain wholly-owned subsidiaries of Apache, including four Delaware limited partnerships (collectively, Altus Midstream Operating) and their general partner (Altus Midstream Subsidiary GP LLC, a Delaware limited liability company, and together with Altus Midstream Operating, the Altus Midstream Entities). The Altus Midstream Entities were formed by Apache between May 2016 and January 2017 for the purpose of acquiring, developing, and operating midstream oil and gas assets in the Alpine High resource play and surrounding areas (Alpine High).
On November 9, 2018 (the Closing Date) and pursuant to the terms of the Altus Contribution Agreement, KAAC acquired from Apache the entire equity interests of the Altus Midstream Entities and options to acquire equity interests in five separate third-party pipeline projects (the Pipeline Options). The acquisition of the entities and the Pipeline Options is referred to herein as the Altus Combination. In exchange, the consideration provided to Apache included economic voting and non-economic voting shares in KAAC and partnership units representing limited partner interests in Altus Midstream LP (Common Units). Following the Closing Date and in connection with the completion of the Altus Combination, KAAC changed its name to Altus Midstream Company.
Ownership of Altus Midstream LP
As of and following the Closing Date and in connection with the completion of the Altus Combination, the Company’s wholly-owned subsidiary, Altus Midstream GP LLC, a Delaware limited liability company (Altus Midstream GP), is the sole general partner of Altus Midstream LP. The Company operates its business through Altus Midstream LP and its subsidiaries, which include Altus Midstream Operating. As of December 31, 2021, the Company held approximately 23.1 percent of the outstanding Common Units, and a controlling interest, in Altus Midstream and Apache held the remaining 76.9 percent. As a result of a direct exchange by the Company of Class A Common Stock for Apache’s Common Units in January 2022, the Company owns 100% of the outstanding Common Units (see Note—10 Equity and Warrants).
Business Combination with BCP
On October 21, 2021, the Company announced that it will combine with privately-owned BCP Raptor Holdco LP (BCP and, together with BCP Raptor Holdco GP, LLC, the Contributed Entities) in an all-stock transaction, pursuant to the Contribution Agreement dated as of that same date and entered into by and among Altus, Altus Midstream LP (the Partnership), New BCP Raptor Holdco, LLC (the Contributor), and BCP (the BCP Contribution Agreement). BCP is the parent company of EagleClaw Midstream, which includes EagleClaw Midstream Ventures, the Caprock Midstream and Pinnacle Midstream businesses, and a 26.7 percent interest in the Permian Highway Pipeline. Pursuant to the BCP Contribution Agreement,
F-11

Contributor will contribute all of the equity interests of the Contributed Entities (the Contributed Interests) to the Partnership, with each Contributed Entity becoming a wholly-owned subsidiary of the Partnership (the BCP Business Combination).
As consideration for the contribution of the Contributed Interests, the Company will issue 50 million shares of Class C Common Stock (and Altus Midstream LP will issue a corresponding number of Common Units) to BCP’s unitholders, which are principally funds affiliated with Blackstone and I Squared Capital. The transaction is expected to close during the first quarter of 2022 following completion of customary closing conditions.
F-12

1.    SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES
Basis of Presentation
The consolidated financial statements have been prepared in accordance with accounting principles generally accepted in the United States (GAAP).
Principles of Consolidation
The consolidated financial results of Altus Midstream are included in the Company’s consolidated financial statements due to the Company’s 100 percent ownership interest in Altus Midstream GP, and Altus Midstream GP’s control of Altus Midstream.
The Company has no independent operations or material assets other than its partnership interests in Altus Midstream, which constitutes all of its business. The Company’s only material net assets separate from Altus Midstream relate to deferred taxes and the current and deferred income tax expense (benefit) associated with its investment in Altus Midstream in 2018. In the fourth quarter of 2019, the Company recorded a full valuation allowance against its net deferred tax assets. Accordingly, the deferred tax asset balance was nil as of the years ended December 31, 2021 and 2020. Additionally, the Company’s balance sheet reflects the presentation of noncontrolling interest ownership attributable to the limited partner interests in Altus Midstream held by Apache and the holders of Series A Cumulative Redeemable Preferred Units (the Preferred Units). Refer to Note 12—Income Taxes, Note 10—Equity and Warrants, and Note 11—Series A Cumulative Redeemable Preferred Units for further information.
Variable Interest Entity
Altus Midstream is a variable interest entity (VIE) because the partners in Altus Midstream with equity at risk lack the power, through voting or similar rights, to direct the activities that most significantly impact Altus Midstream’s economic performance.
A reporting entity that concludes it has a variable interest in a VIE must evaluate whether it has a controlling financial interest in the VIE, such that it is the VIE’s primary beneficiary and should consolidate. The Company is the primary beneficiary of Altus Midstream, and therefore should consolidate Altus Midstream because (i) the Company has the ability to direct the activities of Altus Midstream that most significantly affect its economic performance, and (ii) the Company has the right to receive benefits or the obligation to absorb losses that could be potentially significant to Altus Midstream.
Redeemable Noncontrolling Interest — Apache Limited Partner
As of December 31, 2021, the Company’s redeemable noncontrolling interest presented in the consolidated financial statements consisted of Common Units representing limited partner interests in Altus Midstream held by Apache. Pursuant to certain provisions of the partnership agreement of Altus Midstream (as amended in connection with the Altus Combination, and subsequent issuance of Preferred Units, the Amended LPA), the limited partner interests held by Apache were equal to the number of shares of the Company’s Class C Common Stock held by Apache.
The Company initially recorded the redeemable noncontrolling interest upon the issuance of the Common Units to Apache as part of the Altus Combination and based on the recapitalization value ascribed at the Closing Date to the limited partner interest. All or a portion of these Common Units could be redeemed at Apache’s option, which it elected in January 2022 in respect of all such Common Units. The Company had the ability to settle the redemption option either (i) in shares of Class A Common Stock on a one-for-one basis, which it did in January 2022, or (ii) in cash (based on the fair market value of the Class A Common Stock as determined pursuant to the Altus Contribution Agreement), subject to customary conversion rate adjustments for stock splits, stock dividends, and reclassifications. Upon the January 2022 exchange of Common Units held by Apache for Class A Common Stock, a corresponding number of shares of Class C Common Stock were cancelled.
The Company’s policy is to record the redeemable noncontrolling interest represented by the Common Units held by Apache at the higher of (i) its initial fair value plus accumulated earnings/losses associated with the noncontrolling interest or (ii) the redemption value as of the balance sheet date.
See discussion and additional detail further discussed in Note 10—Equity and Warrants.

F-13

Redeemable Noncontrolling Interest — Preferred Unit Limited Partners
On June 12, 2019, Altus Midstream issued and sold the Preferred Units in a private offering, and the purchasers of the Preferred Units were admitted as limited partners of Altus Midstream. The Preferred Units will be exchangeable for shares of the Company’s Class A Common Stock at the option of the Preferred Unit holders after the seventh anniversary of the closing of the Preferred Unit offering or upon the occurrence of specified events, unless otherwise redeemed by Altus Midstream.
The Preferred Units are accounted for on the Company’s consolidated balance sheet as a redeemable noncontrolling interest classified as temporary equity based on the terms of the Preferred Units. Certain redemption features embedded within the terms of the Preferred Units require bifurcation and measurement at fair value and are accounted for on the Company’s consolidated balance sheet as a long-term liability embedded derivative.
See discussion and additional detail further discussed in Note 11—Series A Cumulative Redeemable Preferred Units and Note 14—Fair Value Measurements.
Equity Method Interests
The Company follows the equity method of accounting when it does not exercise control over its equity interests, but can exercise significant influence over the operating and financial policies of the entity. Under this method, the equity interests are carried originally at acquisition cost, increased by Altus’ proportionate share of the equity interest’s net income and contributions made by Altus, and decreased by Altus’ proportionate share of the equity interest’s net losses and distributions received by Altus.
Equity method interests are assessed for impairment whenever changes in the facts and circumstances indicate a loss in value has occurred, if the loss is deemed to be other than temporary. When the loss is deemed to be other than temporary, the carrying value of the equity method investment is written down to fair value, and the amount of the write-down is included in income. As part of its review of the fair value of its assets in relation to the announced BCP Business Combination, Altus determined the current fair value of its investment in EPIC was below carrying value. The Company subsequently determined that this loss in value was deemed to be other than temporary. As such, in the fourth quarter of 2021, Altus recorded an impairment charge of $160.4 million on its equity method interest in EPIC. The fair value of the impaired interest was determined using the income approach, which considered Altus’ estimates of future throughput volumes, tariff rates, and costs. These assumptions were applied to develop future operating cash flow projections that were then discounted to estimated fair value using a discount rate believed to be consistent with that which would be applied by market participants. The amount arrived at was then considered against EPIC’s debt and the carrying value of the Company’s interest in EPIC to determine the recoverability of Altus’ interest as of December 31, 2021, resulting in the fourth quarter impairment charge. Altus has classified this nonrecurring fair value measurements as Level 3 in the fair value hierarchy.
Refer to Note 9—Equity Method Interests for further details of the Company’s equity method interests.
Use of Estimates
Preparation of financial statements in conformity with GAAP and disclosure of contingent assets and liabilities requires management to make estimates and assumptions that affect reported amounts of assets and liabilities at the date of the financial statements and the reported amounts of revenues and expenses during the reporting period. The Company bases its estimates on historical experience and various other assumptions that are believed to be reasonable under the circumstances, the results of which form the basis for making judgments about carrying values of assets and liabilities that are not readily apparent from other sources. The Company evaluates its estimates and assumptions on a regular basis. Actual results may differ from these estimates and assumptions used in preparation of its financial statements, and changes in these estimates are recorded when known.
Fair Value Measurements
Accounting Standards Codification (ASC) 820-10-35, “Fair Value Measurement” (ASC 820), provides a hierarchy that prioritizes and defines the types of inputs used to measure fair value. The fair value hierarchy gives the highest priority to Level 1 inputs, which consist of unadjusted quoted prices for identical instruments in active markets. Level 2 inputs consist of quoted prices for similar instruments. Level 3 valuations are derived from inputs that are significant and unobservable; hence, these valuations have the lowest priority.
The valuation techniques that may be used to measure fair value include a market approach, an income approach and a cost approach. A market approach uses prices and other relevant information generated by market transactions involving identical or comparable assets or liabilities.
F-14

An income approach uses valuation techniques to convert future amounts to a single present amount based on current market expectations, including present value techniques, option-pricing models, and the excess earnings method. The cost approach is based on the amount that currently would be required to replace the service capacity of an asset (replacement cost).
Embedded features identified within the Company’s agreements are bifurcated and measured at fair value at the end of each period on the Company’s consolidated balance sheet. Such recurring fair value measurements are presented in further detail in Note 14—Fair Value Measurements. The Company also uses fair value measurements on a nonrecurring basis when certain qualitative assessments of its assets indicate a potential impairment. During the years ended December 31, 2021, 2020, and 2019, the Company recorded an impairment charge of $0.4 million, $1.6 million, and $1.3 billion, respectively, on certain assets. Refer to Property, Plant and Equipment—Impairment within this Note below and Note 4—Property, Plant and Equipment, for further detail. During the year ended December 31, 2021, the Company separately recorded an impairment of $160.4 million on its interest in EPIC. Refer to Equity Method Interests within this Note above and Note 9—Equity Method Interests for further detail.
Cash and Cash Equivalents
The Company considers all highly liquid short-term investments with a maturity of three months or less at the time of purchase to be cash equivalents. These investments are carried at cost, which approximates fair value. As of December 31, 2021 and 2020, Altus Midstream had $132.0 million and $24.2 million, respectively, of cash and cash equivalents.
Revenue Receivable
For each period presented and upon commencement of operations, revenues were primarily generated from midstream services provided to Apache, which included gathering, processing, and transmission of natural gas. Revenue receivables represents revenues accrued that have been earned by Altus Midstream but not yet invoiced to Apache. There were no doubtful accounts written off, nor have we provided an allowance for doubtful accounts, as of December 31, 2021 and 2020.
Inventories
Inventories consist principally of equipment and material, stated at the lower of cost or net realizable value.
Property, Plant, and Equipment
Property, plant, and equipment consists of the costs incurred to acquire and construct midstream assets including capitalized interest.

Depreciation
Depreciation is computed over each asset’s estimated useful life using the straight-line method based on estimated useful lives and estimated asset salvage values. The estimated lives are generally 30 years for plants and facilities and 40 years for pipelines and such estimated useful lives were used to depreciate the Company’s assets in 2019. The estimation of useful life also takes into consideration anticipated production lives from the fields serviced by these assets, whether operated by Apache or a third-party. Determination of depreciation expense requires judgment regarding the estimated useful lives and salvage values of property, plant, and equipment. As circumstances warrant, depreciation estimates are reviewed to determine if any changes in the underlying assumptions are necessary. Given the fourth quarter 2019 impairment discussed under Impairment below, and as discussed further in Note 4—Property, Plant and Equipment, the Company reassessed the useful life of its assets in January of 2020. This assessment resulted in a change to estimated useful lives on its impaired assets to 12 years. For the years ended December 31, 2021, 2020, and 2019 depreciation expense totaled $11.9 million, $12.0 million, and $39.8 million, respectively.
Asset Retirement Obligations and Accretion
The initial estimated asset retirement obligation related to property, plant, and equipment and subsequent revisions are recorded as a liability at fair value, with an offsetting asset retirement cost recorded as an increase to the associated property, plant, and equipment on the consolidated balance sheet. Revisions in estimated liabilities can result from changes in estimated inflation rates, changes in service and equipment costs, and changes in the estimated timing of an asset’s retirement. Asset retirement costs are depreciated using a systematic and rational method similar to that used for the associated property, plant, and equipment. Accretion expense on the liability is recognized over the estimated productive life of the related assets and is included on the consolidated statements of operations under “Depreciation and accretion.” For the years ended December 31, 2021, 2020, and 2019 accretion expense totaled $4.3 million, $4.0 million, and $1.6 million, respectively.
F-15

Capitalized Interest
Interest is capitalized as part of the historical cost of developing and constructing assets. Significant midstream development assets, including assets owned by Altus through its equity method interests, that have not commenced operations qualify for interest capitalization. Capitalized interest is determined by multiplying Altus Midstream’s weighted-average borrowing cost of debt by the average amount of qualifying midstream assets. The amount of capitalized interest cannot be greater than actual interest incurred. Once an asset is placed into service, the associated capitalization of interest ceases and is expensed through depreciation over the asset’s useful life.
Impairment
The Company assesses the carrying amount of its property, plant, and equipment whenever events or changes in circumstances indicate a possible significant deterioration in future cash flows expected to be generated by an asset group. Individual assets are grouped for impairment purposes based on the lowest level for which there are identifiable cash flows that are largely independent of the cash flows of other asset groups. If, upon review, the carrying amount of an asset group is greater than the sum of the undiscounted expected cash flows, an impairment loss is recognized for the excess of the carrying value over its fair value.
During the fourth quarter of 2020, the Company sold certain of its power generators and, as a result, the remaining power generators owned by the Company were remeasured at fair value based on the proceeds from such sale. This remeasurement resulted in an impairment of $1.6 million on these assets, and this nonrecurring fair value measurement is classified as Level 1 in the fair value hierarchy based on the negotiated sales price.
Apache, as part of its fourth quarter 2019 review of its capital expenditure program, notified Altus that it had materially reduced its investment plans and had no plans to drill new wells at Alpine High. This notification prompted Altus management to assess its long-lived infrastructure assets for impairment, and as a result of this assessment, Altus recorded impairments of $1.3 billion on its gathering, processing, and transmission assets in the fourth quarter of 2019. Altus also recorded an impairment charge of $9.3 million in the third quarter of 2019 related to the cancellation of construction on a previously planned compressor station. The fair values of the impaired assets were determined using a combination of the income approach and the market approach (when direct sales bids on equivalent equipment was provided from third parties). The income approach considered several internal estimates of future throughput volumes, processing rates, and costs. The assumptions were applied to develop future cash flow projections that were then discounted to estimated fair value, using a discount rate believed to be consistent with those applied by market participants. Altus has classified these nonrecurring fair value measurements as Level 3 in the fair value hierarchy.
These asset impairments are recorded within “Impairments” on the Company’s consolidated statement of operations. Refer to Note 4—Property, Plant and Equipment, for further detail.
Accounts Receivable From/Payable To Apache
The accounts receivable from or payable to Apache represent the net result of Altus Midstream’s monthly revenue, capital and operating expenditures, and other miscellaneous transactions to be settled with Apache as provided under the Construction, Operations and Maintenance Agreement (COMA) between the two entities. Generally, cash in this amount will be transferred to Apache in the month after the Company’s transactions are processed and the net results of operations are determined. However, from time to time, the Company may estimate and transfer the cash settlement amount in the month the transactions are processed, in order to minimize related-party working capital balances. See discussion and additional detail in Note 2—Transactions with Affiliates.
Other Income
In 2020, the Company entered into a contract with a provider to supply the Company with electrical power. If the Company does not utilize all of its fixed purchase volumes under this contract, then it will receive a credit based on a market rate for the related underutilization. In conjunction with increased power pricing due to the Texas freeze event and underutilization of contractual electricity volumes, the Company recognized an estimated total credit of approximately $9.7 million for the six months ended June 30, 2021. The Company did not recognize any additional credit during the remainder of 2021. These amounts are recorded on the statement of consolidated operations in “Other income.” The related power credit will offset the Company’s future monthly power payments and is recorded in “Prepaid assets and other” for the current portion and “Deferred charges and other” for the long-term portion on the consolidated balance sheet. No credits were recorded for the years ended December 31, 2020 and 2019. The Company has no remaining performance obligations related to these credits as of December 31, 2021.
F-16

Distributions to Apache
During 2021, the Company paid an aggregate $22.5 million in dividends on the Company’s Class A Common Stock, of which $5.6 million, or $1.50 per share, was paid in each quarter of 2021. Each quarterly Class A Common Stock dividend was funded by a distribution from Altus Midstream to its common unitholders of $1.50 per Common Unit, with each quarterly distribution totaling $24.4 million, of which $5.6 million was paid to the Company and the balance was paid to Apache due to its 76.9 percent ownership of outstanding Common Units. Please refer to Note 10—Equity and Warrants for further information.
General and Administrative Expense
General and administrative (G&A) expense represents indirect costs and overhead expenditures incurred by the Company associated with managing the midstream assets.
In connection with the closing of the Altus Combination, the Company entered into the COMA, as described above, pursuant to which Apache will provide certain services related to the design, development, construction, operation, management, and maintenance of Altus Midstream’s assets, on the Company’s behalf. See discussion and additional detail further discussed in Note 2—Transactions with Affiliates.
Maintenance and Repairs
Routine maintenance and repairs are charged to expense as incurred. The Company had no non-routine maintenance or repair costs in any period presented.
Income Taxes
The Company is subject to federal income tax and recognizes deferred tax assets and liabilities based on the difference between the financial statement carrying value and tax basis of its investment in Altus Midstream. For federal income tax purposes, Altus Midstream is regarded as a partnership and not subject to income tax. Income and deductions associated with Altus Midstream and the Altus Midstream Entities flow through to the Company. As such, Altus Midstream and the Altus Midstream Entities do not record a federal income tax provision. 
The Company, Altus Midstream, and the Altus Midstream Entities are also subject to the Texas margin tax. The Texas margin tax is assessed on corporations, limited liability companies, and limited partnerships. As such, each entity recognizes state deferred tax assets and liabilities based on the differences between the financial statement carrying value and tax basis of assets and liabilities on the balance sheet. 
The Company routinely assesses the ability to realize its deferred tax assets. If the Company concludes that it is more likely than not that some or all of the deferred tax assets will not be realized, the tax asset is reduced by a valuation allowance. In connection with this assessment, the Company maintained a full valuation allowance against its net deferred tax asset as of December 31, 2021 and 2020.
Change in Accounting Policy
Historically, the Company reported income and loss from equity method interests on a one-month reporting lag. Effective October 1, 2019, the Company eliminated this one-month reporting lag. In accordance with ASC 810-10-45-13, “A Change in the Fiscal Year-End Lag Between Subsidiary and Parent” (ASC 810), the elimination of this previously existing reporting lag is considered a voluntary change in accounting principle in accordance with ASC 250-10-50, “Change in Accounting Principle.” The Company believes that this change in accounting principle is preferable as it provides the Company with the ability to present the results of its equity method interests for the same period as all other consolidated results of the Company, which improves overall financial reporting to investors by providing the most current information available. The Company has not retrospectively applied the change in accounting principle since its impact to the consolidated balance sheet and related statements of operations and cash flows was immaterial for all periods. For more information on equity method interests owned by the Company, please refer to Note 9—Equity Method Interests.
New Pronouncements Issued But Not Yet Adopted
In March 2020, the FASB issued ASU 2020-04, “Reference Rate Reform (Topic 848),” which provides optional expedients and exceptions for applying U.S. GAAP to contracts, hedging relationships, and other transactions affected by the discontinuation of the London Interbank Offered Rate (LIBOR) or by another reference rate expected to be discontinued. In January 2021, the FASB issued ASU 2021-01, which clarified the scope and application of the original guidance. The guidance
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was effective beginning March 12, 2020 and can be applied prospectively through December 31, 2022. The Company is evaluating whether to apply any of these expedients and, if elected, will adopt these standards when LIBOR is discontinued.
In August 2020, the FASB issued ASU 2020-06, “Debt-Debt with Conversion and Other Options (Subtopic 470-20) and Derivatives and Hedging-Contracts in Entity’s Own Equity (Subtopic 815-40)” to improve financial reporting associated with accounting for convertible instruments and contracts in an entity’s own equity. This update is effective for the Company beginning in the first quarter of 2022, with early adoption permitted, using either the modified or fully retrospective method with a cumulative effect adjustment to the opening balance of retained earnings. The Company will adopt this ASU in the first quarter of 2022 and does not believe it will have a material impact on its financial statements.

2.    TRANSACTIONS WITH AFFILIATES
Revenues
The Company has contracted to provide services including gas gathering, compression, processing, transmission, and NGL transmission, pursuant to acreage dedications provided by Apache, comprising the entire Alpine High acreage. In accordance with the terms of these agreements, the Company receives prescribed fees and may receive excess recovery volumes based on the type and volume of product for which the services are provided. Additionally, beginning in 2020 Altus Midstream entered into three agreements to provide operating and maintenance services for Apache’s compressors in exchange for a fixed monthly fee per compressor serviced.
Revenues generated under these agreements are presented on the Company’s statement of consolidated operations as “Midstream services revenue — affiliate.” Revenues earned that have not yet been invoiced to Apache are presented on the Company’s consolidated balance sheet as “Revenue receivables.” Refer to Note 3—Revenue Recognition, for further discussion.
Cost and Expenses
The Company has no employees, and prior to the Altus Combination, the Company had no banking or cash management facilities. As such, the Company has contracted with Apache to receive certain operational, maintenance, and management services. In accordance with the terms of these agreements, the Company incurred operations and maintenance expenses of $5.6 million, $5.4 million, and $8.8 million for the years ended December 31, 2021, 2020, and 2019, respectively. The Company incurred general and administrative expenses of $9.1 million, $7.0 million, and $5.4 million for the years ended December 31, 2021, 2020, and 2019, respectively, including expenses related to the operational services agreement and the COMA. Further information on the related-party agreements in place during the period is provided below.
Construction, Operations, and Maintenance Agreement
At the closing of the Altus Combination, the Company entered into the COMA with Apache. Under the terms of the COMA, Apache provides certain services related to the design, development, construction, operation, management, and maintenance of certain gathering, processing and other midstream assets, on behalf of the Company. In return, the Company paid or will pay fees to Apache of (i) $3.0 million for the period beginning on the execution of the COMA at the closing of the Altus Combination through December 31, 2019, (ii) $5.0 million for the period of January 1, 2020 through December 31, 2020, (iii) $7.0 million for the period of January 1, 2021 through December 31, 2021 and (iv) $9.0 million annually thereafter, adjusted based on actual internal overhead and general and administrative costs incurred, until terminated. The annual fee was negotiated as part of the Altus Combination to reimburse Apache for indirect costs of performing administrative corporate functions for the Company, including services for information technology, risk management, corporate planning, accounting, cash management, and others.
In addition, Apache may be reimbursed for certain internal costs and third-party costs incurred in connection with its role as service provider under the COMA. Costs incurred by Apache directly associated with midstream activity, where substantially all the services are rendered for Altus Midstream, are charged to Altus Midstream on a monthly basis.
The COMA stipulates that the Company shall provide reimbursement of amounts owing to Apache attributable to a particular month by no later than the last day of the immediately following month. Unpaid amounts accrue interest until settled.
The COMA will continue to be effective until terminated (i) upon the mutual consent of Altus and Apache, (ii) by either of Altus and Apache, at its option, upon 30 days’ prior written notice in the event Apache or an affiliate no longer owns a direct or indirect interest in at least 50 percent of the voting or other equity securities of Altus, or (iii) by Altus if Apache fails to perform any of its covenants or obligations due to willful misconduct of certain key personnel and such failure has a material adverse financial impact on Altus.
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Lease Agreements
Concurrent with the closing of the Altus Combination, Altus Midstream entered into an operating lease agreement with Apache (the Lease Agreement) relating to the use of certain office buildings, warehouse and storage facilities located in Reeves County, Texas. Under the terms of the Lease Agreement, Altus Midstream shall pay to Apache on a monthly basis the sum of (i) a base rental charge of $44,500 and (ii) an amount based on Apache’s estimate of the annual costs it expects to incur in connection with the ownership, operation, repair, and/or maintenance of the facilities. The Company incurred total expenses of $0.6 million, $0.8 million and $1.1 million for the years ended December 31, 2021, 2020 and 2019, respectively, in relation to the Lease Agreement, which are included within operations and maintenance expenses. Unpaid amounts accrue interest until settled. The initial term of the Lease Agreement is four years and may be extended by Altus Midstream for three additional, consecutive periods of twenty-four months. To accommodate Altus Midstream’s desire to vacate the leased premises, the Lease Agreement was amended in July 2020 to provide for its termination with respect to all or any portion of the leased premises which Apache may sell, with a pro rata rent reduction if Apache sells less than all of the leased premises.
The Company classified this lease as an operating lease and elected to account for lessee-related lease and non-lease components as a single lease component. The right-of-use (ROU) asset related to this lease is reflected within “Deferred charges and other” on the Company’s consolidated balance sheet, and the associated operating lease liability is reflected within “Other current liabilities” and “Other noncurrent liabilities,” as applicable.
Operating lease expense associated with ROU assets is recognized on a straight-line basis over the lease term. Lease expense is reflected on the consolidated statement of operations commensurate with the leased activities and nature of the services performed. The remaining undiscounted future minimum lease payment as of December 31, 2021 is $0.4 million, which will be paid in 2022.
In 2020 and 2021, Altus Midstream entered into various operating lease agreements with Apache related to the use of certain of Altus Midstream’s compressors. Under the terms of the agreement, Apache pays Altus Midstream fixed monthly lease payments, which are recorded as “Other” in the Company’s consolidated statement of operations. Each of the lease agreements has an initial term of thirty months and automatically extends on a month-to-month basis unless either party cancels the agreement. The Company recorded income related to these agreements of $1.6 million and $0.4 million for the years ended December 31, 2021 and 2020, respectively. Altus also earns a monthly fee to operate and maintain the compressors under lease. Refer to Note 3—Revenue Recognition for further discussion.

Distributions to Apache
During 2021, the Company paid an aggregate $22.5 million in dividends on the Company’s Class A Common Stock, of which $5.6 million, or $1.50 per share, was paid in each quarter of 2021. Each quarterly Class A Common Stock dividend was funded by a distribution from Altus Midstream to its common unitholders of $1.50 per Common Unit, with each quarterly distribution totaling $24.4 million, of which $5.6 million was paid to the Company and the balance was paid to Apache due to its 76.9 percent ownership of outstanding Common Units Please refer to Note 10—Equity and Warrants for further information.
Altus Combination Agreements
Limited Partnership Agreement of Altus Midstream LP
In connection with the Altus Combination, Altus Midstream Company, Altus Midstream GP, Altus Midstream LP, and Apache entered into an amended and restated limited partnership agreement of Altus Midstream LP, which was further amended in connection with the subsequent issuance of Preferred Units. The Amended LPA sets forth, among other things, the rights and obligations of (i) Altus Midstream GP as general partner and (ii) Altus Midstream Company, Apache, and Preferred Unit holders as limited partners of Altus Midstream LP. Altus Midstream GP is not entitled to reimbursement for its services as general partner. Refer to Note 1—Summary of Significant Accounting Policies and Note 11—Series A Cumulative Redeemable Preferred Units, for further information.
Purchase Rights and Restrictive Covenants Agreement
At the closing of the Altus Combination, the Company entered into a purchase rights and restrictive covenants agreement (the Purchase Rights and Restrictive Covenants Agreement) with Apache. Under the Purchase Rights and Restrictive Covenants Agreement, until the later of the five-year anniversary of the Closing and the date on which Apache and its affiliates cease to own a majority of the Company’s voting common stock, Apache is obligated to provide (i) the first right to pursue any opportunity (including any expansion opportunities) of Apache to acquire or invest, directly or indirectly (including equity investments), in any midstream assets or participate in any midstream opportunities located, in whole or part, within an area
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covering approximately 1.7 million acres in Reeves, Pecos, Brewster, Culberson, and Jeff Davis Counties in Texas, and (ii) a right of first offer on certain retained midstream assets of Apache.

3.    REVENUE RECOGNITION
The following table presents a disaggregation of the Company’s revenue.

		Year Ended December 31,	
		2021		2020		2019	
							
		(In thousands)	
Gas gathering and compression		$	18,192 			$	20,060 			$	17,077 		
Gas processing		107,878 			106,396 			101,199 		
Transmission		12,572 			14,548 			15,942 		
NGL transmission		2,422 			2,773 			1,580 		
Other		1,663 			937 			— 		
Midstream services revenue — affiliate		142,727 			144,714 			135,798 		
							
Product sales — affiliate		9,754 			— 			— 		
Product sales — third parties		8,136 			3,695 			— 		
Total revenues		$	160,617 			$	148,409 			$	135,798 		
The Company primarily generates revenue from its contracts with customers for the gathering, compression, processing, transmission, and sale of natural gas and NGLs in exchange for a fee per unit of volumes processed or delivered during a given month.
Midstream services revenue is primarily attributable to services performed for Apache pursuant to separate long-term commercial midstream agreements. As part of these agreements, substantially all of Apache’s natural gas production from its existing and future owned or controlled properties within the dedicated area of its entire Alpine High resource play is provided to the Company, so long as Apache has the right to market such product. Providing the related service on each volumetric unit represents a single, distinct performance obligation that is satisfied over time as services are rendered. Prior to the Company entering the new Gas Processing Agreement discussed below, the Company did not own or take title to the volumes it serviced under these agreements. Altus Midstream, in return for its performance, receives a fee per volumetric unit serviced during a given month. The related service fee charged per unit is set forth for each contract year, subject to yearly fee escalation recalculations.
As the amount of volumes serviced are not subject to minimum commitments and each midstream service agreement contains provisions for fee recalculations, substantially all of the transaction price is variable at inception of each contract term. Revenue is measured using the output method based on the amount of volumes serviced each month and the applicable service fee and recognized over time in the amount to which Altus Midstream has the right to invoice, as performance completed to date corresponds directly with the value to its customers. The transaction price is not constrained as variability is resolved prior to the recognition of revenue.
The Company entered into a new Gas Processing Agreement with Apache in October 2021, which superseded the prior agreement. In addition to the service fees discussed above, the new Gas Processing Agreement contains terms for Apache to provide the Company with excess recovery volumes as consideration under the contract. Excess recovery volumes represent the net difference between the actual recovery rate of processed volumes and contractually fixed volumetric recovery rates. The Company obtains control of excess recovery volumes, if any, on a monthly basis. Any product received is reflected as non-cash consideration and the associated value is included in the transaction price for gas processing services on a net basis. The associated revenue is valued using the market price of the relevant product during the month such product was processed. The subsequent sale of any excess recovery volumes to third parties is recorded as “Product sales — third parties” and the subsequent sale of any excess recovery volumes to Apache is recorded as “Product sales — affiliate” in the Company’s statement of operations.
The associated costs of excess recovery volumes sold are recorded based on the market price of the relevant product and are recorded as “Cost of product sales — third parties” or “Cost of product sales — affiliate” in the Company’s consolidated statement of operations. In 2021, the Company recorded $9.8 million of revenues and costs related to sales of excess recovery volumes to Apache and $2.4 million of revenues and costs related to sales of excess recovery volumes to third parties.
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In addition to the $2.4 million of revenue and costs related to the sales of excess recovery volumes to third parties under the new Gas Processing Agreement, the Company also purchased and processed NGL volumes for other third-party customers during 2021 and 2020. As part of these agreements, Altus Midstream purchases volumes from a third party, which Altus Midstream then owns, controls and services, prior to ultimate sale to the customer. The Company recorded revenue related to these contracts of $5.7 million and $3.7 million, respectively, in 2021 and 2020, with associated purchase costs of $5.4 million and $3.0 million, respectively. As it relates to product sales, the physical delivery of each unit of quantity represents a single, distinct performance obligation that is satisfied at a point in time when control transfers to the customer, generally determined as the point of delivery. Prices are determined based on market-indexed values, adjusted for quality and other market-reflective differentials. As there are no provisions for minimum volume commitments and pricing is variable based on index values, revenue is measured by allocating an entirely variable market price to each performance obligation and recognized at a point in time when control is transferred to the customer. The transaction price is not constrained as variability is resolved prior to the recognition of revenue.
Other Midstream Service Revenue — Affiliate
Beginning in 2020, Altus Midstream entered into various agreements with Apache to provide compressor maintenance, operations, and other related services for various compressors at compressor stations owned by Apache. Altus Midstream receives a fixed monthly fee under these contracts for each month that services are provided. Providing such services on each compressor unit represents a single, distinct performance obligation that is satisfied over time as services are rendered. Income generated from these contracts in 2021 and 2020 totaled $1.7 million and $0.9 million, respectively, and is classified as “Other” within Midstream Services Revenue — Affiliate in the table above.
Payment Terms and Contract Balances
Payments are generally due the month immediately following the month of service. Amounts settled with Apache each month are based on the net amount owed to either party. Revenue receivables from the Company’s contracts with Apache totaled $13.7 million and $11.4 million, as of December 31, 2021 and 2020, respectively, as presented on the Company’s consolidated balance sheet. Sales revenue receivables from the Company’s contracts with third parties totaled $2.2 million and $1.0 million as of December 31, 2021 and 2020, respectively, as presented on the Company’s consolidated balance sheet.
In accordance with the provisions of ASC Topic 606, “Revenue from Contracts with Customers,” a variable transaction price for each short-term sale is allocated to each performance obligation as the terms of payment relate specifically to the Company’s efforts to satisfy its obligations. As such, the Company has elected the practical expedients available under the standard to not disclose the aggregate transaction price allocated to unsatisfied, or partially unsatisfied, performance obligations as of the end of the reporting period.

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4.    PROPERTY, PLANT, AND EQUIPMENT
Property, plant, and equipment, at carrying value, is as follows:

		December 31,	
		2021		2020	
					
		(In thousands)	
Gathering, processing, and transmission systems and facilities(1)		$	208,211 			$	204,643 		
Construction in progress		335 			904 		
	
Other property and equipment		3,154 			3,323 		
Total property, plant, and equipment		211,700 			208,870 		
Less: accumulated depreciation and accretion		(24,713)			(13,034)		
Total property, plant, and equipment, net		$	186,987 			$	195,836 		
(1)Included in Gathering, processing, and transmissions systems and facilities are compressors under lease to Apache totaling $10.0 million and $6.2 million, net as of December 31, 2021 and December 31, 2020, respectively.
The cost of property classified as “Construction in progress” is excluded from capitalized costs being depreciated. These amounts represent property that is not yet available to be placed into productive service as of the respective balance sheet dates.
During 2020, the Company sold various assets for total proceeds of $10.2 million. Included in these assets sales was the sale of 15 power generators. As a result of the sale, the remaining power generators owned by the Company were remeasured at fair value calculated based on the proceeds of this sale. This remeasurement resulted in an impairment of $1.6 million on these assets based on this fair value assessment, which were written down to their fair value of $2.3 million. The fair value of the assets was determined using the market approach based on the sales proceeds of the assets, which are classified as Level 1 inputs in the fair value hierarchy.
Property, plant, and equipment are evaluated for potential impairment when events or changes in circumstances indicate a possible significant deterioration in future cash flows expected to be generated by an asset group. In conjunction with Apache’s decision in the fourth quarter of 2019 to materially reduce funding to Alpine High, Altus management assessed its long-lived infrastructure assets for impairment given the expected reduction to future throughput volumes. As a result of this assessment, Altus recorded impairments totaling $1.3 billion on its gathering, processing, and transmission assets in the fourth quarter of 2019. The fair values of the impaired assets were determined to be $203.6 million as of the time of the impairment and were estimated using the income approach. Altus has classified these nonrecurring fair value measurements as Level 3 in the fair value hierarchy.
During 2019, the Company also elected to cancel construction on a compressor station, and, as a result, certain of its components were marketed for sale. Accordingly, these assets were measured at fair value less costs to sell. The Company recorded an impairment of $9.3 million on these assets, which were written down to their fair value of $18.2 million. The fair value of the assets was determined using the market approach based on estimated sales proceeds, classified as Level 1 inputs in the fair value hierarchy.
The Company entered into a finance lease during the first quarter of 2019 related to power generators leased on a one-year term with the right to purchase. The lease expired in January 2020, at which time the Company exercised its purchase option and purchased the power generators under lease for $9.8 million. Depreciation on the Company's finance lease asset was $5.0 million for the year ended December 31, 2019. Interest on the Company's finance lease assets was $0.9 million for the year ended December 31, 2019. No depreciation expense nor interest were recorded related to this finance lease for the years ended December 31, 2021 and 2020.
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5.    DEBT AND FINANCING COSTS
In November 2018, Altus Midstream entered into a revolving credit facility for general corporate purposes that matures in November 2023 (subject to Altus Midstream’s two, one year extension options). The agreement for this revolving credit facility, as amended (the Amended Credit Agreement), provides aggregate commitments from a syndicate of banks of $800.0 million. The aggregate commitments include a letter of credit subfacility of up to $100.0 million and a swingline loan subfacility of up to $100.0 million. Altus Midstream may increase commitments up to an aggregate $1.5 billion by adding new lenders or obtaining the consent of any increasing existing lenders. As of December 31, 2021, there were $657.0 million of borrowings and a $2.0 million of letter of credit outstanding under this facility. As of December 31, 2020, there were $624.0 million of borrowings and no letters of credit outstanding under this facility.
Altus Midstream’s revolving credit facility is unsecured and is not guaranteed by the Company, Apache, APA Corporation or any of their respective subsidiaries.
At Altus Midstream’s option, the interest rate per annum for borrowings under this facility is either a base rate, as defined, plus a margin, or the London Interbank Offered Rate (LIBOR), plus a margin. Altus Midstream also pays quarterly a facility fee at a rate per annum on total commitments. The margins and the facility fee vary based upon (i) the Leverage Ratio (as defined below) until Altus Midstream has a senior long-term debt rating and (ii) such senior long-term debt rating once it exists. The Leverage Ratio is the ratio of (1) the consolidated indebtedness of Altus Midstream and its restricted subsidiaries to (2) EBITDA (as defined in the Amended Credit Agreement) of Altus Midstream and its restricted subsidiaries for the 12-month period ending immediately before the determination date. At December 31, 2021, the base rate margin was 0.05 percent, the LIBOR margin was 1.05 percent, and the facility fee was 0.20 percent. In addition, a commission is payable quarterly to the lenders on the face amount of each outstanding letter of credit at a per annum rate equal to the LIBOR margin then in effect. Customary letter of credit fronting fees and other charges are payable to issuing banks.
The Amended Credit Agreement contains restrictive covenants that may limit the ability of Altus Midstream and its restricted subsidiaries to, among other things, incur additional indebtedness or guaranty indebtedness, sell assets, make investments in unrestricted subsidiaries, enter into mergers, make certain payments and distributions, incur liens on certain property securing indebtedness, and engage in certain other transactions without the prior consent of the lenders. Altus Midstream also is subject to a financial covenant under the Amended Credit Agreement, which requires it to maintain a Leverage Ratio not exceeding 5.00:1.00 at the end of any fiscal quarter, starting with the quarter ended December 31, 2019, except that during the period of up to one year following a qualified acquisition, the Leverage Ratio cannot exceed 5.50:1.00 at the end of any fiscal quarter. Unless the Leverage Ratio is less than or equal to 4.00:1.00, the Amended Credit Agreement limits distributions in respect of Altus Midstream LP’s capital to $30 million per calendar year until either (i) the consolidated net income of Altus Midstream LP and its restricted subsidiaries, as adjusted pursuant to the Amended Credit Agreement, for three consecutive calendar months equals or exceeds $350.0 million on an annualized basis or (ii) Altus Midstream LP has a specified senior long-term debt rating; in addition, before the occurrence of one of those events, the Leverage Ratio must be less than or equal to 5.00:1.00. In no event can any distribution be made that would, after giving effect to it on a pro forma basis, result in a Leverage Ratio greater than (i) 5.00:1.00 or (ii) for a specified period after a qualifying acquisition, 5.50:1.00. The Leverage Ratio as of December 31, 2021 was less than 4.00:1.00.
The terms of Altus Midstream’s Preferred Units also contain certain restrictions on distributions on Altus Midstream LP’s Common Units, including the Common Units held by the Company, and any other units that rank junior to the Preferred Units with respect to distributions or distributions upon liquidation. Refer to Note 11—Series A Cumulative Redeemable Preferred Units for further information. In addition, the amount of any cash distributions to Altus Midstream LP by any entity in which it has an interest accounted for by the equity method is subject to such entity’s compliance with the terms of any debt or other agreements by which it may be bound, which in turn may impact the amount of funds available for distribution by Altus Midstream LP to its partners.
There are no clauses in the Amended Credit Agreement that permit the lenders to accelerate payments or refuse to lend based on unspecified material adverse changes. The Amended Credit Agreement has no drawdown restrictions or prepayment obligations in the event of a decline in credit ratings. However, the agreement allows the lenders to accelerate payment maturity and terminate lending and issuance commitments for nonpayment and other breaches, and if Altus Midstream or any of its restricted subsidiaries defaults on other indebtedness in excess of the stated threshold, is insolvent, or has any unpaid, non-appealable judgment against it for payment of money in excess of the stated threshold. Lenders may also accelerate payment maturity and terminate lending and issuance commitments if Altus Midstream undergoes a specified change in control or has specified pension plan liabilities in excess of the stated threshold. Altus Midstream was in compliance with the terms of the Amended Credit Agreement as of December 31, 2021.
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Interest Income and Financing Costs, Net of Capitalized Interest
The following table presents the components of Altus Midstream’s interest income and financing costs, net of capitalized interest:

		Year Ended December 31,	
		2021		2020		2019	
							
		(in thousands)	
Interest income		$	4 			$	9 			$	3,606 		
Interest income		$	4 			$	9 			$	3,606 		
							
Interest expense		$	9,431 			$	9,775 			$	6,384 		
Amortization of deferred facility fees		1,167 			1,148 			889 		
Capitalized interest		— 			(8,733)			(5,481)		
Financing costs, net of capitalized interest		$	10,598 			$	2,190 			$	1,792 		

6.    OTHER CURRENT LIABILITIES
The following table provides detail of the Company’s other current liabilities at December 31, 2021 and 2020:

		December 31,	
 		2021		2020	
					
		(In thousands)	
Accrued taxes other than income		$	10,888 			$	165 		
Accrued capital costs		1,346 			360 		
Accrued incentive compensation		1,585 			1,466 		
Accrued operations and maintenance expense		645 			926 		

	
	
Other		1,218 			2,696 		
Total other current liabilities		$	15,682 			$	5,613 		

7.    ASSET RETIREMENT OBLIGATION
The following table describes changes to the Company’s asset retirement obligation (ARO) liability for the years ended December 31, 2021 and 2020:

		December 31,	
		2021		2020	
					
		(In thousands)	
Asset retirement obligation, beginning balance		$	64,062 			$	60,095 		
Liabilities incurred during the period		— 			— 		
Accretion expense		4,269 			3,967 		
Revisions in estimated liabilities		— 			— 		
Asset retirement obligation, ending balance		$	68,331 			$	64,062 		
ARO reflects the estimated present value of the amount of dismantlement, removal, site reclamation, and similar activities associated with the Company’s infrastructure assets which include central processing facilities, gathering systems, and pipelines. Management utilizes independent valuation reports and estimates of current costs to project expected cash outflows for retirement obligations. Management estimates the ultimate productive life of the properties, a risk-adjusted discount rate, and an inflation factor in order to determine the current present value of this obligation. To the extent future revisions to these assumptions impact the present value of existing ARO, a corresponding adjustment is made to the property, plant, and equipment balance.
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8.    COMMITMENTS AND CONTINGENCIES
Accruals for loss contingencies arising from claims, assessments, litigation, environmental, and other sources are recorded when it is probable that a liability has been incurred and the amount can be reasonably estimated. These accruals are adjusted as additional information becomes available or circumstances change. As of December 31, 2021 and 2020, there were no accruals for loss contingencies.
Litigation
The Company is subject to governmental and regulatory controls arising in the ordinary course of business. The Company is not aware of any pending or threatened legal proceedings against it at the time of the filing of this Annual Report on Form 10-K that would have a material impact on its financial position, results of operations, or liquidity.
Environmental Matters
As an owner of infrastructure assets and with rights to surface lands, the Company is subject to various local and federal laws and regulations relating to discharge of materials into, and protection of, the environment. These laws and regulations may, among other things, impose liability on the Company for the cost of pollution clean-up resulting from operations and subject the Company to liability for pollution damages. In some instances, Altus Midstream may be directed to suspend or cease operations. The Company maintains insurance coverage, which management believes is customary in the industry, although insurance does not fully cover against all environmental risks. Additionally, there can be no assurance that current regulatory requirements will not change or past non-compliance with environmental laws will not be discovered. The Company is not aware of any environmental claims existing as of December 31, 2021, that have not been provided for or would otherwise have a material impact on its financial position, results of operations, or liquidity.
Contractual Obligations
Altus Midstream’s existing fee-based midstream services agreements, which have no minimum volume commitments or firm transportation commitments, are underpinned by acreage dedications covering Alpine High. Pursuant to these agreements, Altus Midstream is obligated to perform low and high pressure gathering, processing, dehydration, compression, treating, conditioning, and transportation on all volumes produced from the dedicated acreage, so long as Apache has the right to market such gas.
At the closing of the Altus Combination, the Company entered into the COMA and the Lease Agreement with Apache, which include contractual obligations for the Company to pay certain management and lease rental fees, respectively, to Apache over the term of the agreements. Refer to Note 2—Transactions with Affiliates for further discussion.
During the fourth quarter of 2020, the Company entered into a three year fixed-rate power contract with a third-party. The Company estimates its minimum obligation will be $4.7 million and $3.6 million for 2022 and 2023, respectively. The actual amount incurred will vary based on usage.
In the second quarter of 2019, Altus Midstream issued and sold the Preferred Units. Under the terms of the Amended LPA, the Preferred Unit holders are entitled to receive quarterly distributions until such time as the Preferred Units are redeemed or exchanged. Refer to Note 11—Series A Cumulative Redeemable Preferred Units for further discussion regarding the terms of the Preferred Units and the rights of the holders thereof.
Additionally, the Company is required to fund its pro-rata portion of any future capital expenditures for the development of the pipeline projects as referenced in Note 9—Equity Method Interests.
At December 31, 2021 and 2020, there were no other material contractual obligations related to the entities included in the consolidated financial statements other than the performance of asset retirement obligations as referenced in Note 7—Asset Retirement Obligation and required credit facility fees discussed in Note 5—Debt and Financing Costs.

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9.    EQUITY METHOD INTERESTS
As of December 31, 2021, the Company owns the following equity method interests in Permian Basin long-haul pipeline entities. For each of the equity method interests, the Company has the ability to exercise significant influence based on certain governance provisions and its participation in the significant activities and decisions that impact the management and economic performance of the equity method interests.

	December 31, 2021		December 31, 2020	
In thousands, except for ownership percentages	Ownership		Amount		Ownership		Amount	
Gulf Coast Express Pipeline LLC	16.0 	%		$	273,940 			16.0 	%		$	283,530 		
EPIC Crude Holdings, LP	15.0 	%		— 			15.0 	%		176,640 		
Permian Highway Pipeline LLC	26.7 	%		629,896 			26.7 	%		615,186 		
Breviloba, LLC	33.0 	%		460,990 			33.0 	%		479,826 		
			$	1,364,826 					$	1,555,182 		
As of December 31, 2021 and 2020, unamortized basis differences included in the equity method interest balances were $34.0 million and $37.7 million, respectively. These amounts represent differences in the Company’s initial costs paid to acquire the equity method interests and Altus’ initial underlying equity in the respective entities, as well as capitalized interest related to Permian Highway Pipeline (PHP) construction costs. Unamortized basis differences are amortized into equity income (loss) over the useful lives of the underlying pipeline assets when they are placed into service.
The following table presents the activity in the Company’s equity method interests for the years ended December 31, 2021 and 2020:

	Gulf Coast Express Pipeline LLC		EPIC Crude Holdings, LP		Permian Highway Pipeline LLC		Breviloba, LLC			
									Total	
	(In thousands)	
Balance at December 31, 2019	$	291,628 			$	163,199 			$	310,421 			$	492,800 			$	1,258,048 		
	
Contributions	1,715 			29,250 			296,340 			— 			327,305 		
Distributions	(52,009)			— 			— 			(46,157)			(98,166)		
Capitalized interest(1)	— 			— 			8,733 			— 			8,733 		
Equity income (loss), net	42,196 			(16,332)			(308)			33,183 			58,739 		
Other comprehensive loss			523 			— 			— 			523 		
Balance at December 31, 2020	$	283,530 			$	176,640 			$	615,186 			$	479,826 			$	1,555,182 		
	
Contributions	314 			2,250 			25,856 			— 			28,420 		
Distributions	(49,953)			— 			(73,668)			(49,108)			(172,729)		
	
Equity income (loss), net	40,049 			(19,079)			62,522 			30,272 			113,764 		
Other comprehensive income	— 			630 			— 			— 			630 		
Impairment(2)	— 			(160,441)			— 			— 			(160,441)		
Balance at December 31, 2021	$	273,940 			$	— 			$	629,896 			$	460,990 			$	1,364,826 		
(1)Altus’ proportionate share of the PHP construction costs were funded with the revolving credit facility. Accordingly, Altus capitalized $8.7 million of related interest expense during 2020, which is included in the basis of the PHP equity interest.
(2)The Company impaired its investment in EPIC in the fourth quarter of 2021. Refer to Note 1—Summary of Significant Accounting Policies for further details on this impairment charge.

F-26

Summarized Financial Information
The following represents selected income statement and balance sheet data for the Company’s equity method interests (on a 100 percent basis):

		For the Year Ended December 31,	
		2021	
		Gulf Coast Express Pipeline LLC		EPIC Crude Holdings, LP		Permian Highway Pipeline LLC		Breviloba, LLC	

Statements of Income		(In thousands)	
Revenues		$	362,399 			$	164,774 			$	397,237 			$	157,683 		
	
Operating income (loss)		254,772 			(36,488)			237,230 			92,568 		
Net income (loss)		253,535 			(114,519)			236,528 			92,005 		
Other comprehensive income		— 			4,197 			— 			— 		

		For the Year Ended December 31,	
		2020	
		Gulf Coast Express Pipeline LLC		EPIC Crude Holdings, LP		Permian Highway Pipeline LLC		Breviloba, LLC	

Statements of Income		(In thousands)	
Revenues		$	366,185 			$	165,970 			$	7,220 			$	167,784 		
	
Operating income (loss)		266,219		(35,566)		(1,798)		102,526 		
Net income (loss)		264,956		(109,614)		(1,140)		102,048 		
Other comprehensive income		—		3,484		—		— 		

		For the Year Ended December 31,	
		2019(1)	
		Gulf Coast Express Pipeline LLC		EPIC Crude Holdings, LP		Permian Highway Pipeline LLC		Breviloba, LLC	

Statements of Income		(In thousands)	
Revenues		$	132,103 			$	40,756 			$	— 			$	129,559 		
	
Operating income (loss)		108,056		(67,763)		(93)		81,369 		
Net income (loss)		109,997		(72,535)		1,587		81,469 		
Other comprehensive loss		—		(7,681)		—		— 		
	
(1)Although the Company’s interests in EPIC Crude Holdings, LP, Permian Highway Pipeline LLC, and Breviloba, LLC were acquired in March, May, and July of 2019, respectively, the financial results for all equity method interests are presented for the entire twelve months of 2019 for comparability.

		As of December 31,	
		2021		2020	
		Gulf Coast Express Pipeline LLC		EPIC Crude Holdings, LP		Permian Highway Pipeline LLC		Breviloba, LLC		Gulf Coast Express Pipeline LLC		EPIC Crude Holdings, LP		Permian Highway Pipeline LLC		Breviloba, LLC	

Balance Sheets		(In thousands)	
Current assets		$	74,408 			$	101,189 			$	69,995 			$	34,159 			$	59,910 			$	122,995 			$	23,734 			$	53,206 		
Noncurrent assets		1,655,941 			2,177,616 			2,267,940 			1,344,178 			1,714,062 			2,272,805 			2,316,176 			1,375,155 		
Total assets		$	1,730,349 			$	2,278,805 			$	2,337,935 			$	1,378,337 			$	1,773,972 			$	2,395,800 			$	2,339,910 			$	1,428,361 		
																	
Current liabilities		$	46,151 			$	58,729 			$	36,657 			$	11,244 			$	32,997 			$	67,073 			$	95,863 			$	10,326 		
Noncurrent liabilities		461 			1,185,003 			— 			8,254 			526 			1,187,615 			— 			2,389 		
Equity		1,683,737 			1,035,073 			2,301,278 			1,358,839 			1,740,449 			1,141,112 			2,244,047 			1,415,646 		
Total liabilities and equity		$	1,730,349 			$	2,278,805 			$	2,337,935 			$	1,378,337 			$	1,773,972 			$	2,395,800 			$	2,339,910 			$	1,428,361 		

F-27

10. EQUITY AND WARRANTS
Reverse Stock Split
On June 30, 2020, the Company effected a reverse stock split of the Company’s Class A Common Stock and Class C Common Stock by a ratio of one-for-twenty. The par value and number of authorized shares of common stock and preferred stock were not affected by the reverse stock split. A corresponding number of Altus Midstream Common Units were also restated as part of the reverse stock split. All corresponding per-share and share amounts have been retroactively restated in this Annual Report on Form 10-K for all periods presented to reflect the reverse stock split.

Common Stock and Warrants
The Company’s second amended and restated certificate of incorporation authorizes the issuance of 1,500,000,000 shares of Class A Common Stock, $0.0001 par value, and 1,500,000,000 shares of Class C Common Stock, $0.0001 par value. The Company’s shares of Class A Common Stock are listed on the Nasdaq under the symbol “ALTM.” As of December 31, 2021, there were 3,746,460 and 12,500,000 issued and outstanding shares of Class A Common Stock and Class C Common Stock, respectively.
In January 2022, a direct exchange by the Company and Apache was effectuated under the Amended LPA, pursuant to which the Company succeeded to Apache’s 12,500,000 Common Units, issued an additional 12,500,000 shares of Class A Common Stock to Apache, and cancelled Apache’s 12,500,000 shares of Class C Common Stock, whereupon the Company and Altus Midstream remained subsidiaries of Apache.

Holders of each of the Class A Common Stock and Class C Common Stock vote together as a single class on all matters submitted to a vote of the Company’s stockholders, except as required by law. Only holders of Class A Common Stock are entitled to dividends or other liquidating distributions made by the Company. On December 10, 2020, the Company announced that its board of directors initiated a dividend program on the Company’s Class A Common Stock as further detailed below under the section titled “Common Stock Dividend.”
Shares of Class A Common Stock and certain warrants were originally issued in connection with the Company’s public offering, while shares of Class C Common Stock were newly-issued in connection with the Altus Combination.
Public Warrants
As of December 31, 2021, 2020, and 2019 there were 12,577,350 Public Warrants (as defined below) outstanding. Each whole public warrant entitles the holder to purchase one twentieth of a share of Class A Common Stock at a price of $230.00 per share (the Public Warrants). The Public Warrants will expire five years after closing of the Altus Combination or earlier upon redemption or liquidation. The Company may call the Public Warrants for redemption, in whole and not in part, at a price of $0.01 per warrant with not less than 30 days’ notice provided to the Public Warrant holders. However, this redemption right can only be exercised if the reported last sale price of the Class A Common Stock equals or exceeds $360.00 per share for any 20 trading days within a 30-trading day period ending three business days prior to sending the notice of redemption to the Public Warrant holders.
Following the closing of the Altus Combination, the Public Warrants continued trading under the symbol “ALTMW.” On December 11, 2018, the Company received notice from the Staff of the Nasdaq of a delisting determination with respect to its Public Warrants for failure to satisfy the Nasdaq’s minimum round lot holder listing requirement. The Public Warrants ceased trading on the Nasdaq at the opening of business on December 20, 2018. The delisting of the Public Warrants did not impact the listing or trading of the Company’s Class A Common Stock.
Private Placement Warrants
As of December 31, 2021, 2020, and 2019 , there were 6,364,281 Private Placement Warrants (as defined below) outstanding, of which Apache holds 3,182,140. The private placement warrants are identical to the Public Warrants discussed above, except (i) they will not be redeemable by the Company so long as they are held by the initial holders or their respective permitted transferees and (ii) they may be exercised by the holders on a cashless basis (the Private Placement Warrants and, together with the Public Warrants, the Warrants).
The Warrants are recorded at a fair value of $0.2 million and $0.9 million as of December 31, 2021 and 2020, respectively, on the consolidated balance sheet in other non-current liabilities.
F-28

Earn-Out Consideration
As part of the Altus Combination, Apache was granted the right to receive earn-out consideration of up to 1,250,000 shares of Class A Common Stock as follows:
•625,000 shares if the per share closing price of the Class A Common Stock as reported by Nasdaq during any 30-trading-day period ending prior to the fifth anniversary of the Closing Date is equal to or greater than $280.00 for any 20 trading days within such 30-trading-day period.
•625,000 shares if the per share closing price of the Class A Common Stock as reported by Nasdaq during any 30-trading-day period ending prior to the fifth anniversary of the Closing Date is equal to or greater than $320.00 for any 20 trading days within such 30-trading-day period.
Redeemable Noncontrolling Interest — Apache Limited Partner
As of December 31, 2021, in conjunction with its ownership of the Class C Common Stock, Apache owned 12,500,000 Altus Midstream Common Units, approximately 76.9 percent of the total Common Units issued and outstanding. The financial results of Altus Midstream and its subsidiaries are included in the Company’s consolidated financial statements as detailed in Note 1—Summary of Significant Accounting Policies, under the section titled “Principles of Consolidation.”
As of December 31, 2021, Apache had the right, at any time, to cause Altus Midstream to redeem all or a portion of the Common Units issued to Apache, in exchange for shares of the Company’s Class A Common Stock on a one-for-one basis or, at Altus Midstream’s option, an equivalent amount of cash; provided that the Company could, at its option, effect a direct exchange of cash or Class A Common Stock for such Common Units in lieu of such a redemption by Altus Midstream. Upon the future redemption or exchange of Common Units held by Apache, a corresponding number of shares of Class C Common Stock held by Apache would be cancelled. In January 2022, a direct exchange by the Company and Apache was effectuated under the Amended LPA, pursuant to which the Company succeeded to Apache’s 12,500,000 Common Units, issued an additional 12,500,000 shares of Class A Common Stock to Apache, and cancelled Apache’s 12,500,000 shares of Class C Common Stock, whereupon the Company and Altus Midstream remained subsidiaries of Apache.
As of December 31, 2021, Apache’s limited partner interest associated with the Common Units issued with the Class C Common Stock is reflected as a redeemable noncontrolling interest in the Company. The redeemable noncontrolling interest is recognized at the higher of (i) its initial fair value plus accumulated earnings/losses associated with the noncontrolling interest and (ii) the maximum redemption value as of the balance sheet date. The redemption value is determined based on a 5-day volume weighted average closing price of the Class A Common Stock (5-day VWAP) as defined in the Amended LPA, a Level 1 non-recurring fair value measurement. At December 31, 2021 and 2020, the redeemable noncontrolling interest was recorded based on the redemption value as of the balance sheet date of $769.9 million and $575.1 million, respectively.
For further discussion of Apache’s right to receive additional shares of Class A Common Stock, and other outstanding equity instruments that may impact ownership interests and the limited partner interests of Altus Midstream in future periods, see Note 13—Net Income (Loss) Per Share.
Redeemable Noncontrolling Interest — Preferred Unit Limited Partners
On June 12, 2019, Altus Midstream issued and sold the Preferred Units in a private offering, and the purchasers of the Preferred Units were admitted as limited partners of Altus Midstream. The Preferred Units will be exchangeable for shares of the Company’s Class A Common Stock at the option of the Preferred Unit holders after the seventh anniversary of Closing (as defined below) or upon the occurrence of specified events, unless otherwise redeemed by Altus Midstream. Refer to Note 11—Series A Cumulative Redeemable Preferred Units for further discussion.
Common Stock Dividend
During 2021, the Company paid an aggregate $22.5 million in dividends on the Company’s Class A Common Stock, of which $5.6 million, or $1.50 per share, was paid in each quarter of 2021. Each quarterly Class A Common Stock dividend was funded by a distribution from Altus Midstream to its common unitholders of $1.50 per Common Unit, with each quarterly distribution totaling $24.4 million, of which $5.6 million was paid to the Company and the balance was paid to Apache due to its 76.9 percent ownership of outstanding Common Units.
Refer to Note 2—Transactions with Affiliates for further discussion of the Common Unit distribution.

F-29

11.    SERIES A CUMULATIVE REDEEMABLE PREFERRED UNITS
On June 12, 2019, Altus Midstream issued and sold the Preferred Units in a private offering exempt from the registration requirements of the Securities Act of 1933, as amended (the Closing). The Closing occurred pursuant to a Preferred Unit Purchase Agreement among Altus Midstream, the Company, and the purchasers party thereto, dated as of May 8, 2019. A total of 625,000 Preferred Units were sold at a price of $1,000 per Preferred Unit, for an aggregate issue price of $625.0 million. Altus Midstream received approximately $611.2 million in cash proceeds from the sale after deducting transaction costs and discounts to certain purchasers.
At the Closing, the partners of Altus Midstream entered into the Amended LPA. The Amended LPA provides the terms of the Preferred Units, including the distribution rate, redemption rights, and rights to exchange the Preferred Units for shares of the Company’s Class A Common Stock, as well as rights of holders of the Preferred Units to approve certain partnership business, financial, and governance-related matters. The Preferred Units have a perpetual term, unless redeemed or exchanged as described below. Pursuant to the Amended LPA:
•The Preferred Units entitle the holders thereof to receive quarterly distributions at a rate of 7 percent per annum, commencing with the quarter ended June 30, 2019. The rate increases to 10 percent per annum after the fifth anniversary of Closing and upon the occurrence of specified events. For any quarter ending on or prior to December 31, 2020, Altus Midstream could elect to pay distributions in-kind and did so in respect of quarters ended on and before March 31, 2020.
•The Preferred Units are redeemable at Altus Midstream’s option at any time in cash at a redemption price (the Redemption Price) equal to (a) the greater of (i) an 11.5 percent internal rate of return (increasing to 13.75 percent after the fifth anniversary of Closing), and (ii) a 1.3x multiple of invested capital plus (b) if applicable, the value of any accrued and unpaid distributions. The Preferred Units will be redeemable at the holder’s option upon a change of control or liquidation of Altus Midstream and certain other events, including certain asset dispositions. The Company and Altus Midstream remained subsidiaries of Apache upon consummation of the January 2022 direct exchange by the Company and Apache under the Amended LPA, pursuant to which the Company succeeded to Apache’s 12.5 million Common Units, issued an additional 12.5 million shares of Class A Common Stock to Apache, and cancelled Apache’s 12.5 million shares of Class C Common Stock (as further discussed in Note 10—Equity and Warrants).
•The Preferred Units will be exchangeable for shares of the Company’s Class A Common Stock at the option of the Preferred Unit holders after the seventh anniversary of Closing or upon the occurrence of specified events. Each Preferred Unit will be exchangeable for a number of shares of Class A Common Stock equal to the Redemption Price divided by the volume-weighted average trading price of the Class A Common Stock on the Nasdaq Global Select Market for the 20 trading days immediately preceding the second trading day prior to the applicable exchange date, less a 6 percent discount.
•Each outstanding Preferred Unit has a liquidation preference equal to the Redemption Price payable before any amounts are paid in respect of Altus Midstream’s Common Units and any other units that rank junior to the Preferred Units with respect to distributions or distributions upon liquidation. 
•Altus Midstream is restricted from declaring or making cash distributions on its Common Units until all required distributions on the Preferred Units have been paid. In addition, before the fifth anniversary of Closing, aggregate cash distributions on, and redemptions of, Common Units are limited to $650 million of cash from ordinary course of operations if permitted under the Amended Credit Agreement. Cash distributions on, and redemptions of, Common Units also are subject to satisfaction of leverage ratio requirements specified in the Amended LPA.
Since the Preferred Units could be exchangeable for a number of shares of Class A Common Stock equal to 20 percent or more of the Company’s outstanding voting power, the Company submitted the potential issuance of such shares for approval of its stockholders (the Stockholder Approval) at its annual stockholder meeting in 2020 and obtained Stockholder Approval.
Classification
The Preferred Units are accounted for on the Company’s consolidated balance sheet as a redeemable noncontrolling interest classified as temporary equity based on the terms of the Preferred Units, including the redemption rights with respect thereto.
F-30

Initial Measurement
The net transaction price as shown below was based on the negotiated transaction price, less issue discounts and transaction costs.

		June 12, 2019	
		(In thousands)	
Transaction price, gross		$	625,000 		
Issue discount		(3,675)		
Transaction costs to other third parties		(10,076)		
Transaction price, net		$	611,249 		
Certain redemption features embedded within the terms of the Preferred Units require bifurcation and measurement at fair value. As such, the net transaction price shown in the table above was allocated to the preferred redeemable noncontrolling interest and the embedded features according to the associated initial fair value measurements as follows:

		June 12, 2019	
		(In thousands)	
Redeemable noncontrolling interest - Preferred Units		$	516,790 		
Long-term liability: Embedded derivative(1)		94,459 		
		$	611,249 		
(1)See Note 14—Fair Value Measurements for further discussion on the nature and recognition of the embedded derivative.
Subsequent Measurement
The Company applies a two-step approach to subsequently measure the redeemable noncontrolling interest related to the Preferred Units, by first allocating a portion of the net income of Altus Midstream in accordance with the terms of the Amended LPA described above.
After consideration of the foregoing, the Company records an additional adjustment to the carrying value of the Preferred Unit redeemable noncontrolling interest at each period end, if applicable. The amount of such adjustment is determined based upon the accreted value method to reflect the passage of time until the Preferred Units are exchangeable at the option of the holder. Pursuant to this method, the net transaction price is accreted using the effective interest method, to the Redemption Price calculated at the seventh anniversary of Closing. The total adjustment is limited to an amount such that the carrying amount of the Preferred Unit redeemable noncontrolling interest at each period end is equal to the greater of (a) the sum of (i) the carrying amount of the Preferred Units determined in accordance with ASC 810, plus (ii) the fair value of the embedded derivative liability and (b) the accreted value of the net transaction price.

F-31

Activity related to the Preferred Units for the years ended December 31, 2021 and 2020 is as follows:

		Units Outstanding		Financial Position(1)	
					
		(In thousands, except for unit data)	
Redeemable noncontrolling interest — Preferred Units: at December 31, 2019		638,163 			$	555,599 		
Distribution of in-kind additional Preferred Units		22,531 			— 		
Cash distributions paid to Preferred Unit limited partners		— 			(23,124)		
Allocation of Altus Midstream net income		N/A		75,906 		
Redeemable noncontrolling interest — Preferred Units: at December 31, 2020		660,694 			608,381 		
Cash distributions paid to Preferred Unit limited partners		— 			(46,249)		
Distributions payable to Preferred Unit limited partners		— 			(11,562)		
Allocation of Altus Midstream net income		N/A		79,931 		
Accreted redemption value adjustment		N/A		81,975 		
Redeemable noncontrolling interest — Preferred Units: at December 31, 2021		660,694 			$	712,476 		
Embedded derivative liability(2)				56,895 		
				$	769,371 		
(1)The Preferred Units are redeemable at Altus Midstream’s option at a redemption price (the Redemption Price), which as of December 31, 2021 is calculated as the greater of (i) an 11.5 percent internal rate of return and (ii) a 1.3 times multiple of invested capital. As of December 31, 2021, the Redemption Price would have been based on an 11.5 percent internal rate of return, which would equate to a redemption value of $738.7 million.
(2)Certain redemption features embedded within the terms of the Preferred Units require bifurcation and measurement at fair value. Refer to Note 14—Fair Value Measurements for discussion of the fair value changes in the embedded derivative liability during the period.
N/A - not applicable.

F-32

12. INCOME TAXES
The total income tax provision (benefit) consists of the following:

		Year Ended December 31,	
		2021		2020		2019	
							
		(In thousands)	
Current income taxes:							
Federal		$	— 			$	(696)			$	(15)		
State		— 			— 			— 		
		— 			(696)			(15)		
Deferred income taxes:							
Federal		— 			— 			67,516 		
State		— 			— 			(2,601)		
		— 			— 			64,915 		
Total		$	— 			$	(696)			$	64,900 		
The total income tax provision (benefit) differs from the amounts computed by applying the U.S. statutory income tax rate to net income (loss) before income taxes. A reconciliation of the tax on the Company’s net income (loss) before income taxes and total tax expense (benefit) is shown below:

		Year Ended December 31,	
		2021		2020		2019	
							
		(In thousands)	
Income tax expense (benefit) at U.S. statutory rate		$	20,836 			$	17,008 			$	(265,192)		
Income tax expense (benefit) attributable to Apache limited partner		(15,932)			(12,892)			205,844 		
Income tax benefit attributable to Preferred Unit limited partners		(7,833)			(3,676)			(1,879)		
State tax benefit(1)		— 			— 			(2,610)		
CARES Act tax impact		— 			(266)			— 		
Valuation allowance(1)		3,068 			(620)			130,988 		
Warrant valuation adjustment		(139)			(252)			(2,348)		
All other, net		— 			2 			97 		
Income tax expense (benefit)		$	— 			$	(696)			$	64,900 		
(1) The change in state valuation allowance is included as a component of state income tax.

F-33

The net deferred tax assets reflect the tax impact of temporary differences between the asset and liability amounts carried on the balance sheet under U.S. GAAP and amounts utilized for income tax purposes. The net deferred tax assets consist of the following:
															
		December 31,	
		2021		2020	
					
		(In thousands)	
Deferred tax assets:					
  Investment in partnership		$	88,054 			$	92,881 		
  Asset retirement obligation		512 			480 		
  Net operating losses		44,437 			37,675 		
  Property, plant, and equipment		3,358 			4,471 		
	
      Total deferred tax assets		136,361 			135,507 		
Valuation allowance		(135,263)			(133,077)		
Net deferred tax assets		1,098 			2,430 		
Deferred tax liabilities:					
	
  Other		1,098 			2,430 		
Net deferred tax assets		$	— 			$	— 		
In 2021, the Company recorded an increase in valuation allowance against its net deferred tax asset. The Company has assessed the future potential to realize these deferred tax assets and has concluded that it is more likely than not that these deferred tax assets will not be realized.
The Company reconciles its effective tax rate to its net income (loss) before income taxes. This includes net income (loss) before income taxes attributable to both the controlling and noncontrolling interests. As such, the Company’s effective tax rate includes adjustments to remove income (loss) attributed to the noncontrolling interests. In 2021, 2020, and 2019, the Company recorded tax benefit adjustments of $15.9 million and $12.9 million and a tax expense adjustment of $205.8 million, respectively, associated with income and losses allocated to Apache.
On March 27, 2020, the President signed into law the Coronavirus Aid, Relief and Economic Security Act (CARES Act) in response to the COVID-19 pandemic. Under the CARES Act, 100 percent of net operating losses arising in tax years beginning after December 31, 2017 and before January 1, 2021 may be carried back to each of the five preceding tax years of such loss. For the year ended December 31, 2020, the Company recorded a current income tax benefit of $0.7 million associated with a net operating loss carryback claim.
In the first quarter of 2020, the Company early adopted ASU 2019-12, “Simplifying the Accounting for Income Taxes.” The Company’s adoption of ASU 2019-12 did not result in a material impact on the consolidated financial statements.
On June 12, 2019, Altus Midstream issued and sold the Preferred Units in a private offering. Concurrently, the Preferred Units were established as a new class of partnership unit representing limited partner interests in Altus Midstream pursuant to the terms of the Amended LPA, and the purchasers were admitted as limited partners of Altus Midstream. In 2021, 2020 and 2019, the Company recorded a tax benefit adjustment of $7.8 million, $3.7 million, and $1.9 million, respectively, associated with income allocated to the noncontrolling Preferred Unit limited partners of Altus Midstream. For further details on the terms of the Preferred Units and the rights of the holders thereof, refer to Note 11—Series A Cumulative Redeemable Preferred Units.
Altus is also subject to the Texas margin tax. Unlike federal income taxes, the Texas margin regime assesses tax on corporations, limited liability companies, limited partnerships, and disregarded entities. As such, the Company records deferred tax assets and liabilities for Texas margin tax based on the differences between the financial statement carrying value and tax basis of assets and liabilities on the balance sheet. The Texas margin tax associated with Apache's share of the liability is recorded as a component of the noncontrolling interest.
The Company has a federal net operating loss carryforward of $211.6 million, which has an indefinite carryforward period. The Company has recorded a full valuation allowance against the federal net operating loss because it is more likely than not that this attribute will not be realized.
F-34

On January 14, 2022, a direct exchange by the Company and Apache Midstream LLC was effectuated under the Amended LPA, pursuant to which the Company succeeded to Apache’s 12,500,000 Common Units, issued an additional 12,500,000 shares of Class A Common Stock to Apache, and cancelled Apache’s 12,500,000 shares of Class C Common Stock (as further discussed in Note 10—Equity and Warrants). For federal income tax purposes, the Company is deemed to have acquired 12,500,000 Common Units and as a result, the tax basis of the assets held by Altus Midstream LP was increased to the market value of Class A Common Stock on the exchange date.
The Company accounts for income taxes in accordance with ASC Topic 740, “Income Taxes,” which prescribes a minimum recognition threshold a tax position must meet before being recognized in the financial statements. Tax positions generally refer to a position taken in a previously filed income tax return or expected to be included in a tax return to be filed in the future that is reflected in the measurement of current and deferred income tax assets and liabilities. A reconciliation of the beginning and ending amount of unrecognized tax benefits is as follows:
																					
		December 31,	
		2021		2020		2019	
							
		(In thousands)	
Balance at beginning of year		$	4,613 			$	2,057 			$	— 		
Additions based on tax positions related to the prior year		— 			— 			— 		
Additions based on tax positions related to the current year		1,622 			2,556 			2,057 		
Reductions for tax positions of prior years		— 			— 			— 		
Balance at end of year		$	6,235 			$	4,613 			$	2,057 		
The Company records interest and penalties related to unrecognized tax benefits as a component of income tax expense. Each quarter the Company assesses the amounts provided for and, as a result, may increase (expense) or reduce (benefit) the amount of interest and penalties. The Company has recorded no interest or penalties associated with its unrecognized tax benefit. Uncertain tax positions may change in the next twelve months; however, the Company does not expect any possible change to have a significant impact on the results of operations or financial position. If incurred, Altus will record income tax interest and penalties as a component of income tax expense. The contributor of Altus Midstream LP’s operating assets, Apache Corporation, is currently under IRS audit for the 2014 through 2017 tax years.
F-35

13.    NET INCOME (LOSS) PER SHARE
Basic net income (loss) per share is calculated by dividing net income (loss) attributable to Class A common shareholders by the weighted average number of shares of Class A Common Stock outstanding during the period. Class C Common Stock is excluded from the weighted average shares outstanding for the calculation of basic net income (loss) per share, as holders of Class C Common Stock are not entitled to any dividends or liquidating distributions.
The Company uses the “if-converted method” to determine the potential dilutive effect of (i) an assumed exchange of outstanding Common Units of Altus Midstream (and the cancellation of a corresponding number of shares of outstanding Class C Common Stock) for shares of Class A Common Stock, and (ii) an assumed exchange of the outstanding Preferred Units of Altus Midstream for shares of Class A Common Stock. The treasury stock method is used to determine the potential dilutive effect of its outstanding warrants. The dilutive effect of any earn-out consideration payable in shares is only included in periods for which the underlying conditions for the issuance are met.
The computation of basic and diluted net income (loss) per share for the periods presented in the consolidated financial statements is shown in the table below.

	For the Year Ended December 31,	
	2021		2020		2019	
	Loss		Shares		Per Share		Income		Shares		Per Share		Loss		Shares(3)		Per Share	
																		
	(In thousands, except per share data)	
Basic:																		
Net income (loss) attributable to Class A common shareholders	$	(13,944)			3,746		$	(3.72)			$	2,791 			3,746		$	0.75 			$	(358,490)			3,746		$	(95.70)		
Effect of dilutive securities:																		
Redeemable noncontrolling interest — Apache limited partner	$	(48,741)			12,500				$	2,987 			12,500				$	— 			—			
	
Diluted(1)(2):																		
Net income (loss) attributable to Class A common shareholders	$	(62,685)			16,246		$	(3.86)			$	5,778 			16,246		$	0.36 			$	(358,490)			3,746		$	(95.70)		

	

	
(1)The effect of an assumed exchange of outstanding Common Units of Altus Midstream (and the cancellation of a corresponding number of shares of outstanding Class C Common Stock) would have been anti-dilutive for the year ended December 31, 2019.
(2)The effect of an assumed exchange of the outstanding Preferred Units of Altus Midstream for shares of Class A Common Stock would have been anti-dilutive for all periods presented in which the Preferred Units were outstanding.
(3)Share and per share amounts have been retroactively restated to reflect the Company’s reverse stock split, which was effected June 30, 2020. Refer to Note 10—Equity and Warrants for further information.
The diluted earnings per share calculation excludes the effects of the outstanding warrants of the Company to purchase an aggregate 947,082 shares of Class A Common Stock, since the associated impacts would have been anti-dilutive for all periods presented. Earn-out consideration granting Apache the right to receive additional shares of Class A Common Stock is also not included in the earnings per share calculation above, as the conditions for issuance were not satisfied as of the year ended December 31, 2021.
Further discussion of the Company’s outstanding common stock, warrants, and earn-out consideration as well as any applicable redemption rights is provided in Note 10—Equity and Warrants. Further discussion of the Preferred Units and associated embedded features can be found in Note 11—Series A Cumulative Redeemable Preferred Units and Note 14—Fair Value Measurements, respectively.
F-36

14. FAIR VALUE MEASUREMENTS
The Company’s financial assets and liabilities measured at fair value on a recurring basis consist of: cash and cash equivalents; revenue receivables; accounts receivable from/payable to Apache, the Company’s warrant liability, and an embedded derivative liability related to the issuance of Preferred Units. This embedded derivative liability is recorded on the Company’s consolidated balance sheet at fair value. The carrying amounts reported on the consolidated balance sheet for the Company’s remaining financial assets and liabilities approximate fair value due to their short-term nature. The carrying amount of Altus Midstream’s revolving credit facility approximates fair value because the interest rate is variable and reflective of market rates. There were no transfers between Level 1, Level 2 or Level 3 of the fair value hierarchy during the years ended December 31, 2021 or 2020.
The Company bifurcated and recognized the embedded derivative associated with the Preferred Units related to the exchange option provided to the Preferred Unit holders under the terms of the Amended LPA. The valuation of the embedded derivative (using an income approach) was based on a range of factors including expected future interest rates using the Black-Karasinski model, the Company’s imputed interest rate, interest rate volatility, the expected timing of periodic cash distributions, any anticipated early redemptions of the Preferred Units, the estimated timing for the potential exercise of the exchange option, and anticipated dividend yields of the Preferred Units. The Company recorded an unrealized gain of $82.1 million and unrealized losses of $36.1 million and $8.5 million for the years ended December 31, 2021, 2020 and 2019, respectively, which are recorded in “Unrealized derivative instrument loss” in the consolidated statement of operations. Altus has classified these recurring fair value measurements as Level 3 in the fair value hierarchy.
As of the December 31, 2021 valuation date, the Company used the forward B-rated Energy Bond Yield curve to develop the following key unobservable inputs used to value this embedded derivative:

		Quantitative Information About Level 3 Fair Value Measurements	
		Fair Value at December 31, 2021		Valuation Technique		Significant Unobservable Inputs		Range/Value	
									
		(In thousands)							
Preferred Units Embedded Derivative		$	56,895 			Option Model		Altus Midstream Company’s Imputed Interest Rate		5.54-11.21%	
						Interest Rate Volatility		40.08%	
In addition, no early redemptions of the Preferred Units were assumed for the December 31, 2020 valuation. As a result of the announced BCP Business Combination and associated publicly filed information, the December 31, 2021 valuation assumed 250,000 Preferred Units would be redeemed before the Preferred Unit holders had the right to exercise their exchange option. This early redemption assumption significantly reduced the value of the derivative liability year over year.
A one percent increase in the imputed interest rate assumption would significantly increase the value of the embedded derivative liability at December 31, 2021, while a one percent decrease would lead to a similar decrease in value as of December 31, 2021. The assumed expected timing until exercise of the exchange option at December 31, 2021 was 4.45 years.
The Company has additional embedded derivatives in the Preferred Units related to the exchange option and redemption features that are accounted for separately from the Preferred Units. Level 3 valuations of the embedded derivatives are based on a range of factors including the likelihood of the event occurring, and these factors are assessed quarterly. There was no value associated with these additional identified embedded derivatives for any applicable period presented.
The fair value of the Company’s warrant liability was insignificant as of December 31, 2021 and 2020.
F-37

Exhibit 21.1
Altus Midstream Company (a Delaware corporation)
Listing of Subsidiaries as of December 31, 2021

									
Exact Name of Subsidiary and Name under which Subsidiary does Business    		Jurisdiction of Incorporation or Organization    	
			
Altus Midstream GP LLC		Delaware	
Altus Midstream LP		Delaware	
Altus Midstream Subsidiary GP LLC		Delaware	
Altus Midstream Gathering LP		Delaware	
Altus Midstream Processing LP		Delaware	
Altus Midstream NGL Pipeline LP		Delaware	
Altus Midstream Pipeline LP		Delaware	

1

Exhibit 23.1

Consent of Independent Registered Public Accounting Firm
We consent to the incorporation by reference in the following Registration Statements:

(1)Registration Statement (Form S-3 No. 333-262043) of Altus Midstream Company and in the related Prospectus, and
(2)Registration Statement (Form S-8 No. 333-234475) of Altus Midstream Company;

of our report dated February 22, 2022, with respect to the consolidated financial statements of Altus Midstream Company, included in this Annual Report (Form 10-K) for the year ended December 31, 2021.

/s/ Ernst & Young LLP
Houston, Texas
February 22, 2022

Exhibit 23.2
Consent of Independent Auditors
We consent to the incorporation by reference in the following Registration Statements:

(1)Registration Statement (Form S-3 No. 333-262043) of Altus Midstream Company and in the related prospectus, and
(2)Registration Statement (Form S-8 No. 333-234475) of Altus Midstream Company;

of our report dated February 22, 2022, with respect to the financial statements of Breviloba, LLC included in this Annual Report (Form 10-K) of Altus Midstream Company for the year ended December 31, 2021.

/s/ Ernst & Young LLP

Houston, Texas
February 22, 2022

Exhibit 23.3
Consent of Independent Registered Public Accounting Firm

We hereby consent to the incorporation by reference in the Registration Statements on Form S-3 (No. 333-262043) and Form S-8 (No. 333-234475) of Altus Midstream Company of our report dated February 16, 2022, relating to the financial statements of Gulf Coast Express Pipeline LLC, which appears in this Annual Report on Form 10-K of Altus Midstream Company.

/s/ BDO USA, LLP

Houston, Texas
February 22, 2022

Exhibit 23.4
Consent of Independent Registered Public Accounting Firm

We hereby consent to the incorporation by reference in the Registration Statements on Form S-3 (No. 333-262043) and Form S-8 (No. 333-234475) of Altus Midstream Company (“Altus”) of our reports dated February 16, 2022, relating to the financial statements of Permian Highway Pipeline LLC (“PHP”) as of and for the years ended December 31, 2021 and 2020, which appear as Exhibit 99.3 to this Annual Report on Form 10-K of Altus, and March 16, 2020, relating to the financial statements of PHP as of and for the year ended December 31, 2019, which appears in this Annual Report on Form 10-K of Altus.

/s/ BDO USA, LLP

Houston, Texas
February 22, 2022

Exhibit 23.5
Consent of Independent Registered Public Accounting Firm
We consent to the incorporation by reference in the registration statement (No. 333-262043) on Form S-3 and (No. 333-234475) on Form S-8 of Altus Midstream Company of our report dated February 25, 2021, with respect to the consolidated financial statements of EPIC Crude Holdings, LP, which report appears in the Form 10-K of Altus Midstream Company dated February 22, 2022.

/s/ KPMG LLP

San Antonio, TX
February 22, 2022

EXHIBIT 31.1

CERTIFICATIONS

I, Clay Bretches, certify that:

1.I have reviewed this Annual Report on Form 10-K of Altus Midstream Company;

2.Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3.Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4.The registrant’s other certifying officer and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:

a.Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

b.Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, 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;

c.Evaluated the effectiveness of the registrant’s disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

d.Disclosed in this report any change in the registrant’s internal control over financial reporting that occurred during the registrant’s most recent fiscal quarter (the registrant’s fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant’s internal control over financial reporting; and

5.     The registrant’s other certifying officer and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant’s auditors and the audit committee of the registrant’s board of directors (or persons performing the equivalent functions):

a.All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant’s ability to record, process, summarize and report financial information; and

b.Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant’s internal control over financial reporting.

Date: February 22, 2022

/s/ Clay Bretches		
Clay Bretches		
Chief Executive Officer and President
(Principal Executive Officer)	

EXHIBIT 31.2

CERTIFICATIONS

I, Ben C. Rodgers, certify that:

1.I have reviewed this Annual Report on Form 10-K of Altus Midstream Company;

2.Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3.Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4.The registrant’s other certifying officer and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:

a.Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

b.Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, 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;

c.Evaluated the effectiveness of the registrant’s disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

d.Disclosed in this report any change in the registrant’s internal control over financial reporting that occurred during the registrant’s most recent fiscal quarter (the registrant’s fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant’s internal control over financial reporting; and

5.     The registrant’s other certifying officer and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant’s auditors and the audit committee of the registrant’s board of directors (or persons performing the equivalent functions):

a.All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant’s ability to record, process, summarize and report financial information; and

b.Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant’s internal control over financial reporting.

Date: February 22, 2022

/s/ Ben C. Rodgers		
Ben C. Rodgers		
Chief Financial Officer and Treasurer
(Principal Financial Officer)	

EXHIBIT 32.1

ALTUS MIDSTREAM COMPANY	
	
Certification of Principal Executive Officer and Principal Financial Officer	

I, Clay Bretches, certify pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, that, to my knowledge, the Annual Report on Form 10-K of Altus Midstream Company for the period ending December 31, 2021, fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934 (15 U.S.C. §78m or §78o (d)) and that information contained in such report fairly represents, in all material respects, the financial condition and results of operations of Altus Midstream Company. 

Date: February 22, 2022

/s/ Clay Bretches	
By:	Clay Bretches	
Title:	Chief Executive Officer and President
(Principal Executive Officer)	

I, Ben C. Rodgers, certify pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, that, to my knowledge, the Annual Report on Form 10-K of Altus Midstream Company for the period ending December 31, 2021, fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934 (15 U.S.C. §78m or §78o (d)) and that information contained in such report fairly represents, in all material respects, the financial condition and results of operations of Altus Midstream Company. 

Date: February 22, 2022

/s/ Ben C. Rodgers	
By:	Ben C. Rodgers	
Title:	Chief Financial Officer and Treasurer
(Principal Financial Officer)	

FINANCIAL STATEMENTS With Report of Independent Registered Public Accounting Firm GULF COAST EXPRESS PIPELINE LLC As of December 31, 2021 and 2020 and For the Years Ended December 31, 2021, 2020 and 2019

 

GULF COAST EXPRESS PIPELINE LLC TABLE OF CONTENTS Page Number Report of Independent Registered Public Accounting Firm 1 Financial Statements Statements of Income 3 Balance Sheets 4 Statements of Cash Flows 5 Statements of Members’ Equity 6 Notes to Financial Statements 7

 

1 Report of Independent Registered Public Accounting Firm Board of Directors and Members Gulf Coast Express Pipeline LLC Houston, Texas Opinion on the Financial Statements We have audited the accompanying balance sheets of Gulf Coast Express Pipeline LLC (the “Company”) as of December 31, 2021 and 2020, the related statements of income, members’ equity and cash flows for each of the three years ended December 31, 2021, and the related notes (collectively referred to as the “financial statements”). In our opinion, the financial statements present fairly, in all material respects, the financial position of the Company at December 31, 2021 and 2020, and the results of its operations and its cash flows for each of the three years ended December 31, 2021, in conformity with accounting principles generally accepted in the United States of America. 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 Public Company Accounting Oversight Board (United States) (“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 and in accordance with auditing standards generally accepted in the United States of America. 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. The Company is not required to have, nor were we engaged to perform, an audit of its internal control over financial reporting. As part of our audit we are required to obtain an understanding of internal control over financial reporting but not for the purpose of expressing an opinion on the effectiveness of the Company’s internal control over financial reporting. Accordingly, we express no such opinion. 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 Critical audit matters are matters arising from the current period audit of the financial statements that were communicated or required to be communicated to the audit committee and that: (1) relate to accounts or disclosures that are material to the financial statements and (2) involved our especially challenging, subjective, or complex judgments. We determined that there are no critical audit matters.

 

2 Emphasis of Matter – Significant Transactions with Related Parties As discussed in Note 4 to the financial statements, the Company has entered into significant transactions with related parties. /s/ BDO USA, LLP We have served as the Company's auditor since 2020. Houston, Texas February 16, 2022

 

3 GULF COAST EXPRESS PIPELINE LLC STATEMENTS OF INCOME (In thousands) Year Ended December 31, 2021 2020 2019 Revenues $ 362,399 $ 366,185 $ 132,103 Operating Costs and Expenses Operations and maintenance 14,269 7,409 1,900 Depreciation and amortization 60,012 59,456 19,272 General and administrative 7,644 7,058 2,194 Taxes, other than income taxes 25,702 26,043 681 Total Operating Costs and Expenses 107,627 99,966 24,047 Operating Income 254,772 266,219 108,056 Other Income (Expense) Interest income 2 132 1,577 Other 121 — 639 Total Other Income 123 132 2,216 Income Before Taxes 254,895 266,351 110,272 Income Tax Expense (1,360) (1,395) (275) Net Income $ 253,535 $ 264,956 $ 109,997 The accompanying notes are an integral part of these financial statements.

 

4 GULF COAST EXPRESS PIPELINE LLC BALANCE SHEETS (In thousands) December 31, 2021 2020 ASSETS Current assets Cash and cash equivalents $ 21,777 $ 21,626 Accounts receivable 13,609 13,585 Accounts receivable from affiliates 17,654 17,522 Natural gas imbalance receivable 21,223 7,065 Other current assets 145 112 Total current assets 74,408 59,910 Property, plant and equipment, net 1,655,941 1,714,062 Total Assets $ 1,730,349 $ 1,773,972 LIABILITIES AND MEMBERS’ EQUITY Current liabilities Accounts payable $ 1,999 $ 2,389 Accrued taxes, other than income taxes 19,527 18,642 Natural gas imbalance payable 22,378 9,921 Other current liabilities 2,247 2,045 Total current liabilities 46,151 32,997 Long-term liabilities and deferred credits 461 526 Total Liabilities 46,612 33,523 Commitments and contingencies (Note 6) Members’ Equity 1,683,737 1,740,449 Total Liabilities and Members’ Equity $ 1,730,349 $ 1,773,972 The accompanying notes are an integral part of these financial statements.

 

5 GULF COAST EXPRESS PIPELINE LLC STATEMENTS OF CASH FLOWS (In thousands) Year Ended December 31, 2021 2020 2019 Cash Flows From Operating Activities Net income $ 253,535 $ 264,956 $ 109,997 Adjustment to reconcile net income to net cash provided by operating activities: Depreciation and amortization 60,012 59,456 19,272 Changes in components of working capital: Accounts receivable (156) 7,982 (37,447) Accounts payable (89) (86) 868 Accrued taxes, other than income 885 15,184 3,457 Other current assets and liabilities (1,532) 3,367 447 Other long-term assets and liabilities (65) (56) 286 Net Cash Provided by Operating Activities 312,590 350,803 96,880 Cash Flows From Investing Activities Capital expenditures (2,192) (47,605) (1,172,136) Net Cash Used in Investing Activities (2,192) (47,605) (1,172,136) Cash Flows From Financing Activities Contributions from Members 1,961 10,722 1,135,128 Distributions to Members (312,208) (325,058) (101,302) Net Cash (Used in) Provided by Financing Activities (310,247) (314,336) 1,033,826 Net Increase (Decrease) in Cash and Cash Equivalents 151 (11,138) (41,430) Cash and Cash Equivalents, beginning of period 21,626 32,764 74,194 Cash and Cash Equivalents, end of period $ 21,777 $ 21,626 $ 32,764 The accompanying notes are an integral part of these financial statements.

 

6 GULF COAST EXPRESS PIPELINE LLC STATEMENTS OF MEMBERS’ EQUITY (In thousands) Year Ended December 31, 2021 2020 2019 Beginning Balance $ 1,740,449 $ 1,789,829 $ 646,006 Net income 253,535 264,956 109,997 Contributions 1,961 10,722 1,135,128 Distributions (312,208) (325,058) (101,302) Ending Balance $ 1,683,737 $ 1,740,449 $ 1,789,829 The accompanying notes are an integral part of these financial statements.

 

7 GULF COAST EXPRESS PIPELINE LLC NOTES TO FINANCIAL STATEMENTS 1. General We are a Delaware limited liability company, formed on October 13, 2017. When we refer to “us,” “we,” “our,” “the Company,” or “GCX,” we are describing Gulf Coast Express Pipeline LLC. The Members’ interests in us are as follows: • 34% - Kinder Morgan Texas Pipeline LLC (KMTP), an indirect subsidiary of Kinder Morgan, Inc. (KMI); • 25% - DCP GCX Pipeline LLC (DCP), an indirect subsidiary of DCP Midstream, LP; • 25% - Targa GCX Pipeline LLC (Targa), an indirect subsidiary of Targa Resources Corp.; and • 16% - Altus Midstream LP (Altus), a subsidiary of Apache Corporation. Effective February 3, 2022, Targa Resources Corp executed agreements selling Targa, which holds the 25% equity interest in us, to another party. We were formed to develop, construct, own, operate and maintain the GCX Pipeline system. Beginning at the Waha Hub near Coyanosa, Texas in the Permian Basin and extending to Agua Dulce, Texas, the 530-mile pipeline is designed to transport approximately 2 billion cubic feet per day of natural gas. 2. Summary of Significant Accounting Policies Basis of Presentation We have prepared our accompanying financial statements in accordance with the accounting principles contained in the Financial Accounting Standards Board’s Accounting Standards Codification, the single source of United States (U.S.) Generally Accepted Accounting Principles and referred to in this report as the Codification. Management has evaluated subsequent events through February 16, 2022, the date the financial statements were available to be issued. Coronavirus Diseases 2019 (COVID-19) The COVID-19 pandemic resulted in reductions in energy demand and the dramatic decline in commodity prices in 2020. Sharp declines in the supply of and demand for energy related commodities due to the economic shutdown in the wake of the pandemic also affected the energy industry during 2020. The sustainability of the economic recovery observed in 2021 remains unclear as efforts to combat the virus have been complicated by new variants. Further, significant uncertainty remains regarding the duration and extent of the impact of the pandemic (including the pace and efficacy of vaccination efforts) on the energy industry, including demand and prices for hydrocarbons to reasonably predict the potential impact of COVID-19 on our business and operations. Use of Estimates Certain amounts included in or affecting our financial statements and related disclosures must be estimated, requiring us to make certain assumptions with respect to values or conditions which cannot be known with certainty at the time our financial statements are prepared. These estimates and assumptions affect the amounts we report for assets and liabilities, our revenues and expenses during the reporting period, and our disclosures, including those related to contingent assets and liabilities at the date of our financial statements. We evaluate these estimates on an ongoing basis, utilizing historical experience, consultation with

 

8 experts and other methods we consider reasonable in the particular circumstances. Nevertheless, actual results may differ significantly from our estimates. Any effects on our business, financial position or results of operations resulting from revisions to these estimates are recorded in the period in which the facts that give rise to the revision become known. Certain accounting policies are of more significance in our financial statement preparation process than others, and set out below are the principal accounting policies we apply in the preparation of our financial statements. Cash Equivalents We define cash equivalents as all highly liquid short-term investments with original maturities of three months or less. Allowance for Credit Losses We evaluate our financial assets measured at amortized cost and off-balance sheet credit exposures for expected credit losses over the contractual term of the asset or exposure. We consider available information relevant to assessing the collectability of cash flows including the expected risk of credit loss even if that risk is remote. We measure expected credit losses on a collective (pool) basis when similar risk characteristics exist and we reflect the expected credit losses on the amortized cost basis of the financial asset as of the reporting date. Our financial instruments primarily consist of our accounts receivable from customers. We utilized historical analysis of credit losses experienced over the previous five years along with current conditions and reasonable and supportable forecasts of future conditions in our evaluation of collectability of our financial assets. We had no allowance for credit losses recorded as of December 31, 2021 and 2020. Natural Gas Imbalances Natural gas imbalances occur when the amount of natural gas delivered from or received by a pipeline system differs from the scheduled amount of gas to be delivered or received. We value these imbalances due to or from shippers and operators at current index prices. Imbalances are settled in cash or made up in-kind. Imbalances due from others are reported on our accompanying Balance Sheets in “Natural gas imbalance receivable.” Imbalances owed to others are reported on our accompanying Balance Sheets in “Natural gas imbalance payable.” We classify all imbalances due from or owed to others as current as we expect to settle them within a year. Property, Plant and Equipment, net Our property, plant and equipment is recorded at its original cost of construction. For constructed assets, we capitalize all construction-related direct labor and material costs. We expense costs for routine maintenance and repairs in the period incurred. We use the composite method to depreciate our property, plant and equipment. Under this method, assets with similar economic characteristics are grouped and depreciated as one asset. When property, plant and equipment is retired, accumulated depreciation and amortization is charged for the original cost of the assets in addition to the cost to remove, sell or dispose of the assets, less salvage value. We do not recognize gains or losses upon normal retirement of assets under the composite depreciation method. Asset Retirement Obligations (ARO) We record liabilities for obligations related to the retirement and removal of long-lived assets used in our businesses. We record, as liabilities, the fair value of ARO on a discounted basis when they are incurred and can be reasonably estimated, which is typically at the time the assets are installed or acquired. Amounts recorded for the related assets are increased by the amount of these obligations. Over time, the liabilities increase due to the change in their present value, and the initial capitalized costs

 

9 are depreciated over the useful lives of the related assets. The liabilities are eventually extinguished when the asset is taken out of service. We are required to operate and maintain our natural gas pipeline system, and intend to do so as long as supply and demand for our services exists, which we expect for the foreseeable future. Therefore, we believe that we cannot reasonably estimate the ARO for the substantial majority of our assets because these assets have indeterminate lives. We continue to evaluate our ARO and future developments could impact the amounts we record. We had no ARO recorded as of December 31, 2021 and 2020. Long-lived Asset Impairments We evaluate our long-lived assets for impairment when events or changes in circumstances indicate that the carrying values may not be recoverable. These events include changes in the manner in which we intend to use a long-lived asset, decisions to sell an asset and adverse changes in market conditions, that are believed to be other than temporary, or in the legal or business environment such as adverse actions by regulators. If an event occurs, which is a determination that involves judgment, we evaluate the recoverability of the carrying value of our long-lived asset based on the long-lived asset’s ability to generate future cash flows using a two-step approach. If an impairment is indicated, or if we decide to sell a long-lived asset or group of assets, we adjust the carrying value of the asset downward, if necessary, to its estimated fair value. To determine if a long-lived asset is recoverable, we compare the asset’s estimated undiscounted cash flows to its carrying value (step 1). If the carrying value of a long-lived asset or asset group is in excess of estimated undiscounted cash flows, we typically use discounted cash flow analyses to calculate the fair value of the long-lived asset to determine if an impairment is required (step 2). Our fair value estimates are generally based on assumptions market participants would use, including market data obtained through the sales process or an analysis of expected discounted future cash flows. There were no impairments for the years ended December 31, 2021, 2020 and 2019. Revenue Recognition Revenue from Contracts with Customers We review our contracts with customers using the following steps to recognize revenue based on the transfer of goods or services to customers and in amounts that reflect the consideration the Company expects to receive for those goods or services. The steps include: (i) identify the contract; (ii) identify the performance obligations of the contract; (iii) determine the transaction price; (iv) allocate the transaction price to the performance obligations in the contract; and then (v) recognize revenue when (or as) the performance obligation is satisfied. Each of these steps involves management judgment and an analysis of the contract’s material terms and conditions. Our revenues are generated from the transportation of natural gas under firm service customer contracts with take-or-pay elements (principally for capacity reservation) where both the price and quantity are fixed. Generally, for these contracts: (i) our promise is to transfer (or stand ready to transfer) a series of distinct integrated services over a period of time, which is a single performance obligation; (ii) the transaction price includes both fixed and/or variable consideration which is determinable at contract inception and/or at each month end based on our right to invoice at month end for the value of services provided to the customer that month; and (iii) the transaction price is recognized as revenue over the service period specified in the contract as the services are rendered. In these arrangements, the customer is obligated to pay for services associated with its take-or-pay obligation regardless of whether or not the customer chooses to utilize the service in that period. Because we make the service continuously available over the service period, we recognize the take-or-pay amount as revenue ratably over such period based on the passage of time. The natural gas we receive under our transportation contracts remains under the control of our customers. Under firm service contracts, the customer generally pays a two-part transaction price that includes (i) a fixed fee reserving the right to transport

 

10 natural gas in our facilities up to contractually specified capacity levels (referred to as “reservation”) and (ii) a fee-based per-unit rate for quantities of natural gas actually transported in excess of contractual quantities. In our firm service contracts we generally promise to provide a single integrated service each day over the life of the contract, which is fundamentally a stand-ready obligation to provide services up to the customer’s reservation capacity prescribed in the contract. Our customers have a take-or- pay payment obligation with respect to the fixed reservation fee component, regardless of the quantities they actually transport. In other cases, generally described as interruptible service, there is no fixed fee associated with these transportation services because the customer accepts the possibility that service may be interrupted at our discretion in order to serve customers who have firm service contracts. We do not have an obligation to perform under interruptible customer arrangements until we accept and schedule the customer’s request for periodic service. The customer pays a transaction price based on a fee-based per-unit rate for the quantities actually transported. Contract Balances Contract assets and contract liabilities are the result of timing differences between revenue recognition, billings and cash collections. Our contract liabilities are related to capital improvements paid for in advance by certain customers, which we recognize as revenue on a straight-line basis over the initial term of the related customer contracts. Refer to Note 5 for further information. Environmental Matters We capitalize or expense, as appropriate, environmental expenditures. We capitalize certain environmental expenditures required to obtain rights-of-way, regulatory approvals or permitting as part of the construction of facilities we use in our business operations. We accrue and expense environmental costs that relate to an existing condition caused by past operations, which do not contribute to current or future revenue generation. We generally do not discount environmental liabilities to a net present value, and we record environmental liabilities when environmental assessments and/or remedial efforts are probable and we can reasonably estimate the costs. Generally, our accrual of these environmental liabilities coincides with either our completion of a feasibility study or our commitment to a formal plan of action. We recognize receivables for anticipated associated insurance recoveries when such recoveries are deemed to be probable. We routinely conduct reviews of potential environmental issues and claims that could impact our assets or operations. These reviews assist us in identifying environmental issues and estimating the costs and timing of remediation efforts. We also routinely adjust our environmental liabilities to reflect changes in previous estimates. In making environmental liability estimations, we consider the material effect of environmental compliance, pending legal actions against us, and potential third-party liability claims we may have against others. Often, as the remediation evaluation and effort progresses, additional information is obtained, requiring revisions to estimated costs. These revisions are reflected in our income in the period in which they are reasonably determinable. We are subject to environmental cleanup and enforcement actions from time to time. In particular, the Comprehensive Environmental Response, Compensation and Liability Act generally imposes joint and several liability for cleanup and enforcement costs on current and predecessor owners and operators of a site, among others, without regard to fault or the legality of the original conduct, subject to the right of a liable party to establish a “reasonable basis” for apportionment of costs. Our operations are also subject to federal, state and local laws and regulations relating to protection of the environment. Although we believe our operations are in substantial compliance with applicable environmental laws and regulations, risks of additional costs and liabilities are inherent in our operations, and there can be no assurance that we will not incur significant costs and liabilities. Moreover, it is possible that other developments could result in substantial costs and liabilities to us, such as increasingly stringent environmental laws, regulations and enforcement policies under the terms of authority of those laws, and claims for damages to property or persons resulting from our operations.

 

11 Although it is not possible to predict the ultimate outcomes, we believe that the resolution of environmental matters, and other matters to which we are a party, will not have a material adverse effect on our business. We had no accruals for any outstanding environmental matters as of December 31, 2021 and 2020. Income Taxes We are a limited liability company that is treated as a partnership for income tax purposes and are not subject to federal or state income taxes. Accordingly, no provision for federal or state income taxes has been recorded in our financial statements. The tax effects of our activities accrue to our Members who report on their individual federal income tax returns their share of revenues and expenses. However, we are subject to Texas margin tax (a revenue based calculation), which is presented as “Income Tax Expense” on our accompanying Statements of Income. 3. Property, Plant and Equipment, net Our property, plant and equipment, net consisted of the following: Annual Depreciation Rates December 31, 2021 2020 % (In thousands) Transmission facilities 3.33 $ 1,775,195 $ 1,772,123 Intangible plant 3.33 15,824 16,103 General plant 10.0 - 20.0 3,570 3,559 Accumulated depreciation and amortization (138,985) (78,973) 1,655,604 1,712,812 Land 283 283 Construction work in progress 54 967 Property, plant and equipment, net $ 1,655,941 $ 1,714,062 4. Related Party Transactions LLC Agreement Under the terms of the LLC Agreement, the Members are obligated to make capital contributions to fund the construction of our pipeline. Affiliate Agreements We have a Construction and Maintenance Agreement (CMA) Operations and Maintenance Agreement (OMA) with KMTP to develop and construct the GCX pipeline and upon completion of each phase facility, to operate, maintain and administer the GCX pipeline. Pursuant to the CMA, we paid KMTP a monthly capital overhead fee, which began in February 2018 and continued through the completion of the construction phases. Pursuant to the OMA, we pay KMTP an annual corporate overhead charge in monthly installments. Affiliate Balances and Activities We do not have employees. Employees of KMI provide services to us. In accordance with our governance documents, we reimburse KMI at cost.

 

12 The following table summarizes our other balance sheet affiliate balances not presented separately on the accompanying Balance Sheets: December 31, 2021 2020 (In thousands) Natural gas imbalance receivable $ 20,711 $ 6,839 Accounts payable 988 272 Natural gas imbalance payable 21,779 9,524 The following table shows revenues and costs from our affiliates: Year Ended December 31, 2021 2020 2019 (In thousands) Revenues $ 203,098 $ 206,804 $ 95,315 Operations and maintenance 13,227 2,379 705 General and administrative(a) 6,673 6,092 1,754 Capitalized costs(a) 863 898 27,623 (a) Includes costs associated with the affiliate agreements described above. Subsequent Event Subsequent to December 31, 2021 and through the issuance of this report, we made distributions to our Members totaling $29,052,000. 5. Revenue Recognition Disaggregation of Revenues The following table presents our revenues disaggregated by revenue source and type of revenue for each revenue source: Year Ended December 31, 2021 2020 2019 (In thousands) Revenue from contracts with customers Services Firm services $ 362,217 $ 363,007 $ 96,027 Fee-based services 117 3,196 35,766 Other 65 (18) 310 Total revenues from contracts with customers $ 362,399 $ 366,185 $ 132,103 Contract Balances We did not have any contract assets as of December 31, 2021 and 2020. As of December 31, 2021 and 2020, our contract liability balances were $520,000 and $592,000, respectively. Of the contract liability balance at December 31, 2020, $66,000 was recognized as an adjustment to revenue during the year ended December 31, 2021.

 

13 Revenue Allocated to Remaining Performance Obligations The following table presents our estimated revenue allocated to remaining performance obligations for contracted revenue that has not yet been recognized, representing our “contractually committed” revenue as of December 31, 2021 that we will invoice or transfer from contract liabilities and recognize in future periods: Year Estimated Revenue (In thousands) 2022 $ 363,105 2023 363,105 2024 364,100 2025 363,105 2026 363,105 Thereafter 996,085 Total $ 2,812,605 Our contractually committed revenue, for purposes of the tabular presentation above, is generally limited to service customer contracts which have fixed pricing and fixed volume terms and conditions, generally including contracts with take-or-pay payment obligations. Our contractually committed revenue amounts generally exclude, based on the following practical expedient that we elected to apply, remaining performance obligations for contracts with variable volume attributes in which such variable consideration is allocated entirely to a wholly unsatisfied performance obligation. Major Customers The following table presents revenues from our largest customers, each of which exceeded 10% of our revenues as determined for each year individually and irrespective of the other periods presented below: Year Ended December 31, 2021 2020 2019 (In thousands) Revenues from largest affiliated customer (number one) $ 65,559 $ 66,796 $ 29,546 Revenues from largest affiliated customer (number two) 55,581 53,143 28,805 Revenues from largest affiliated customer (number three) 41,518 43,972 17,836 Revenues from largest affiliated customer (number four) 40,440 42,623 n/a Revenues from largest non-affiliated customer 56,208 56,222 18,049 n/a - not applicable 6. Litigation and Commitments We are party to various legal, regulatory and other matters arising from the day-to-day operations of our business that may result in claims against the Company. Although no assurance can be given, we believe, based on our experiences to date and taking into account established reserves, that the ultimate resolution of such items will not have a material adverse impact on our business. We believe we have meritorious defenses to the matters to which we are a party and intend to vigorously defend the Company. 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.

 

14 Legal Proceeding Dispute with Pipe Supplier In January 2018, GCX entered into an agreement with Borusan Mannesmann Bore Sanayi ve Tricare A.S. (Borusan), a steel pipe producer in Turkey, under which Borusan supplied highly specialized steel pipe for the GCX project. Total pipe costs are approximately $172.5 million. During March 2018, the U.S. government, pursuant to Section 232 of the Trade Expansion Act of 1962 (Section 232), announced a 25% tariff on steel imported from Turkey, including steel pipe. The tariff was later increased to 50%. The amount of the Section 232 tariff applicable to the pipe supplied by Borusan to GCX is $74.3 million. GCX and Borusan each allege the other party is responsible to pay the tariff. During May 2018, GCX made a request to the U.S. Department of Commerce (DOC) for an exclusion from the Section 232 tariffs. On April 23, 2019, GCX was informed that its request for an exclusion was denied. On June 11, 2019, GCX resubmitted its request for an exclusion from the Section 232 tariff. GCX took possession of the Borusan supplied pipe in February 2019. Thereafter, GCX both exercised its legal right to set off the amount of the disputed tariff from unpaid invoices sent to GCX by Borusan and demanded that Borusan reimburse GCX for the amount of the tariff previously paid by GCX to Borusan. GCX is currently setting off $37.2 million from the amount Borusan claims it is owed and demanding that Borusan return $37.1 million to GCX. On January 28, 2020, GCX filed a lawsuit against Borusan in the U.S. District Court for the Southern District of Texas alleging breach of contract and seeking a judicial declaration of GCX’s rights under the parties’ agreement. The case is captioned Gulf Coast Express Pipeline, LLC v. Borusan Mannesmann Bore Sanayi ve Tricare A.S. On May 22, 2020, the DOC approved GCX’s request for an exclusion from the Section 232 tariff. GCX and Borusan sought to secure refunds of the Section 232 tariffs paid from the U.S. Bureau of Customs and Border Protection (CBP), who has not yet provided the refunds to GCX and Borusan. GCX and Borusan have agreed to an administrative stay of the litigation in the U.S. District Court for the Southern District of Texas and advanced litigation against CBP to secure the Section 232 tariff refunds in the U.S. Court of International Trade. That case is captioned Borusan Mannesmann Bore Sanayi ve Tricare A.S. et al v. United States. General We had no accruals for any outstanding legal proceedings as of December 31, 2021 and 2020. Commitments As of December 31, 2021, we had capital commitments of approximately $663,000 for purchases related to construction work in progress.

 

Breviloba, LLC Financial Statements for the Years Ended December 31, 2021 and 2020, and for the Period July 31, 2019 Through December 31, 2019

 

Breviloba, LLC Index to Financial Statements Page Report of Independent Auditors .................................................................................................................. 1 Financial Statements: Balance Sheets ..................................................................................................................................... 2 Statements of Operations ..................................................................................................................... 3 Statements of Cash Flows .................................................................................................................... 4 Statements of Members’ Equity ........................................................................................................... 5 Notes to Financial Statements .............................................................................................................. 6

 

Report of Independent Auditors To the Management Committee and Members Breviloba, LLC Opinion We have audited the accompanying financial statements of Breviloba, LLC, which comprise the balance sheet as of December 31, 2021 and 2020, and the related statements of operations, cash flows and members’ equity for the two years in the period ended December 31, 2021 and for the period July 31, 2019 through December 31, 2019, and the related notes (collectively referred to as the “financial statements”). In our opinion, the accompanying financial statements present fairly, in all material respects, the financial position of the Company at December 31, 2021 and 2020, and the results of its operations and its cash flows for the years then ended and for the period July 31, 2019 through December 31, 2019 in accordance with accounting principles generally accepted in the United States of America. Basis for Opinion We conducted our audits in accordance with auditing standards generally accepted in the United States of America (GAAS). Our responsibilities under those standards are further described in the Auditor’s Responsibilities for the Audit of Financial Statements section of our report. We are required to be independent of the Company and to meet our other ethical responsibilities in accordance with the relevant ethical requirements relating to our audits. We believe that the audit evidence we have obtained is sufficient and appropriate to provide a basis for our audit opinion. Responsibilities of Management for the Financial Statements Management is responsible for the preparation and fair presentation of these financial statements in accordance with accounting principles generally accepted in the United States of America, and for the design, implementation, and maintenance of internal control relevant to the preparation and fair presentation of financial statements that are free of material misstatement, whether due to fraud or error. In preparing the financial statements, management is required to evaluate whether there are conditions or events, considered in the aggregate, that raise substantial doubt about the Company’s ability to continue as a going concern for one year after the date of the financial statements are available to be issued. Auditor’s Responsibilities for the audit of the Financial Statements Our objectives are to obtain reasonable assurance about whether the financial statements as a whole are free of material misstatement, whether due to fraud or error, and to issue an auditor’s report that includes our opinion. Reasonable assurance is a high level of assurance but is not absolute assurance and therefore is not a guarantee that an audit conducted in accordance with GAAS will always detect a material misstatement when it exists. The risk of not detecting a material misstatement resulting from fraud is higher than for one resulting from error, as fraud may involve collusion, forgery, intentional omissions, misrepresentations, or the override of internal control. Misstatements are considered material if there is a substantial likelihood that, individually or in the aggregate, they would influence the judgment made by a reasonable user based on the financial statements. In performing an audit in accordance with GAAS, we: - Exercise professional judgment and maintain professional skepticism throughout the audit.

 

- Identify and assess the risks of material misstatement of the financial statements, whether due to fraud or error, and design and perform audit procedures responsive to those risks. Such procedures include examining, on a test basis, evidence regarding the amounts and disclosures in the financial statements. - Obtain an understanding of internal control relevant to the audit in order to design audit procedures that are appropriate in the circumstances, but not for the purpose of expressing an opinion on the effectiveness of the Company’s internal control. Accordingly, no such opinion is expressed. - Evaluate the appropriateness of accounting policies used and the reasonableness of significant accounting estimates made by management, as well as evaluate the overall presentation of the financial statements. - Conclude whether, in our judgment, there are conditions or events, considered in the aggregate, that raise substantial doubt about the Company’s ability to continue as a going concern for a reasonably period of time. We are required to communicate with those charged with governance regarding, among other matters, the planned scope and timing of the audit, significant audit findings, and certain internal control-related matters that we have identified during the audit. /s/ Ernst & Young LLP Houston, Texas February 22, 2022

 

2 Breviloba, LLC Balance Sheets (in thousands of dollars) December 31, Assets 2021 2020 Current assets: Cash and cash equivalents (see Note 2) $ 24,939 $ 45,346 Accounts receivable – related parties (see Note 6) 9,149 7,808 Other current assets 71 52 Total current assets 34,159 53,206 Property, plant and equipment, net (see Note 3) 1,340,417 1,370,900 Intangible asset, net (see Note 4) 3,321 3,790 Spare parts inventory 440 465 Total assets $ 1,378,337 $ 1,428,361 Liabilities and Members’ Equity Current liabilities: Accounts payable – trade $ 218 $ 624 Accounts payable – related parties (see Note 6) 317 74 Accrued payables 1,516 468 Accrued ad valorem taxes payable 9,180 9,144 Other current liabilities 13 16 Total current liabilities 11,244 10,326 Asset retirement obligations (see Note 3) 4,391 1,197 Deferred tax liabilities 1,763 1,192 Deferred revenue 2,100 -- Commitments and contingent liabilities (see Note 2) Members’ equity (see Note 5) 1,358,839 1,415,646 Total liabilities and members’ equity $ 1,378,337 $ 1,428,361 The accompanying notes are an integral part of these financial statements.

 

3 Breviloba, LLC Statements of Operations (in thousands of dollars) For the Year Ended December 31, For the Period July 31, 2019 Through December 31, 20192021 2020 Revenues: Transportation service agreements: Related party $ 89,292 $ 101,292 $ 41,229 Third party 634 780 326 Total transportation service agreements 89,926 102,072 41,555 Capacity arrangement: Related party 67,757 65,712 21,137 Total revenues (see Note 2) 157,683 167,784 62,692 Costs and expenses: Operating costs and expenses 22,508 23,055 8,207 Depreciation, accretion and amortization expense 40,445 40,124 15,859 General and administrative costs 2,162 2,079 854 Total costs and expenses 65,115 65,258 24,920 Operating income 92,568 102,526 37,772 Other income: Interest income 4 374 100 Income before income taxes 92,572 102,900 37,872 Provision for income taxes (see Note 2) (567) (852) (347) Net income $ 92,005 $ 102,048 $ 37,525 The accompanying notes are an integral part of these financial statements.

 

4 Breviloba, LLC Statements of Cash Flows (in thousands of dollars) For the Year Ended December 31, For the Period July 31, 2019 Through December 31, 20192021 2020 Operating activities Net income $ 92,005 $ 102,048 $ 37,525 Reconciliation of net income to net cash flows provided by operating activities: Depreciation, accretion and amortization expense 40,445 40,124 15,859 Net losses (gains) attributable to asset sales (5) 49 -- Deferred income tax expense 571 845 347 Effect of changes in operating accounts: Decrease in accounts receivable – trade -- 79 1,692 Increase in accounts receivable – related parties (1,334) (5,587) (2,227) Decrease (increase) in other current assets (19) 39 (61) Decrease in accounts payable – trade (42) -- (8,908) Increase (decrease) in accounts payable – related parties 243 (1,625) 1,615 Increase in other current liabilities 1,081 5,840 1,334 Increase in other liabilities 2,100 -- -- Net cash flows provided by operating activities 135,045 141,812 47,176 Investing activities Capital expenditures (6,667) (42,026) (71,724) Acquisition of intangible asset (see Note 4) -- (4,688) -- Acquisition of spare parts inventory -- (492) -- Proceeds from asset sales 27 13 -- Cash used in investing activities (6,640) (47,193) (71,724) Financing activities Cash contributions from Members -- -- 585,208 Cash distributions to Members (148,812) (139,873) (470,060) Cash provided by (used in) financing activities (148,812) (139,873) 115,148 Net change in cash and cash equivalents (20,407) (45,254) 90,600 Cash and cash equivalents, beginning of period 45,346 90,600 -- Cash and cash equivalents, end of period (see Note 2) $ 24,939 $ 45,346 $ 90,600 Supplemental disclosure of cash flow information Cash payments for state income taxes $ -- $ 3 Accruals for capital expenditures at end of period $ 32 $ 372 $ 26,680 Accrual for reimbursement to Enterprise in connection with intangible asset at December 31, 2019 (see Note 4) $ -- $ -- $ 4,688 The accompanying notes are an integral part of these financial statements.

 

5 Breviloba, LLC Statements of Members’ Equity (in thousands of dollars) Altus Midstream Processing LP (33%) Enterprise Products Operating LLC (67%) Total Balance – July 31, 2019, immediately prior to Altus’ exercise of option to acquire member interest (see Note 5) $ -- $ 1,300,798 $ 1,300,798 Net income 12,383 25,142 37,525 Cash contributions from Members 489,567 95,641 585,208 Cash distributions to Members (9,108) (460,952) (470,060) Balance – December 31, 2019 $ 492,842 $ 960,629 $ 1,453,471 Net income 33,676 68,372 102,048 Cash distributions to Members (46,158) (93,715) (139,873) Balance – December 31, 2020 $ 480,360 $ 935,286 $ 1,415,646 Net income 30,362 61,643 92,005 Cash distributions to Members (49,108) (99,704) (148,812) Balance – December 31, 2021 $ 461,614 $ 897,225 $ 1,358,839 The accompanying notes are an integral part of these financial statements.

 

6 Breviloba, LLC Notes to Financial Statements 1. Company Organization and Nature of Operations Company Organization Breviloba, LLC is a Texas limited liability company formed in April 2017. Unless the context requires otherwise, references to “we,” “us,” “our,” “Breviloba,” or the “Company” within these notes are intended to mean the business and operations of Breviloba, LLC. Effective July 31, 2019, Altus Midstream Processing LP (“Altus”) acquired a 33% interest from Enterprise Products Operating LLC (“Enterprise”). At December 31, 2021, our membership interests were owned 67% by Enterprise and 33% by Altus. Enterprise and Altus are referred to individually as “Member” and collectively as the “Members.” Description of Business We own the Shin Oak NGL Pipeline (“Shin Oak”), which is a 669-mile pipeline that transports natural gas liquids (“NGLs”) from the Permian Basin to Enterprise’s NGL fractionation and storage complex located in Chambers County, Texas. In February 2019, the 24-inch diameter mainline segment of Shin Oak from Orla, Texas to Mont Belvieu was placed into limited commercial service with an initial transportation capacity of 250 thousand barrels per day (“MBPD”). In June 2019, an additional pipeline segment, the 20-inch diameter Waha lateral, was placed into service. Shin Oak is designed to provide 550 MBPD of transportation capacity. Enterprise serves as operator of Shin Oak. Enterprise Option Agreement In May 2018, in conjunction with a long-term natural gas liquids (“NGL”) supply agreement, Enterprise granted Apache Corporation (“Apache”) an option to acquire up to a 33% equity interest in us. In November 2018, Apache contributed this option to Altus, which is its majority-owned subsidiary. In July 2019, Altus exercised the option and acquired a 33% equity interest in us (effective July 31, 2019). We amended our limited liability company agreement and reaffirmed Enterprise as operator of our pipeline upon Altus becoming a Member of the Company. 2. Significant Accounting Policies Our financial statements are prepared on the accrual basis of accounting in accordance with U.S. generally accepted accounting principles (“GAAP”). Dollar amounts presented in the tabular data within these footnote disclosures are stated in thousands of dollars. All statistical data (e.g., pipeline mileage, transportation capacity and similar operating and physical measurements) in these notes to financial statements are unaudited. In preparing these financial statements, we have evaluated subsequent events for potential recognition or disclosure through February 22, 2022, the issuance date of the financial statements. Cash and Cash Equivalents Cash and cash equivalents represent unrestricted cash on hand and may also include highly liquid investments with original maturities of less than three months from the date of purchase. Accounts Receivable Accounts receivable are with customers utilizing our pipeline. On a routine basis, we review all outstanding accounts receivable balances and record a reserve for amounts that we expect will not be fully recovered. We do not apply actual balances against any reserves until we have exhausted substantially all collection efforts.

 

7 In June 2016, the Financial Accounting Standards Board (“FASB”) issued Accounting Standards Update (“ASU”) 2016-13, “Financial Instruments – Credit Losses (Topic 326): Measurement of Credit Losses on Financial Instruments.” The new guidance, referred to as the current expected credit loss (“CECL”) model, requires the measurement of expected credit losses for financial assets (e.g., accounts receivable) held at the reporting date based on historical experience, current economic conditions, and reasonable and supportable forecasts. These changes are expected to result in the more timely recognition of losses. The adoption of this new guidance on January 1, 2020 did not have a material impact on our financial statements. We have no allowance for credit losses at December 31, 2021 or 2020. Commitments and Contingent Liabilities Certain conditions may exist as of the date the financial statements are issued, which may result in a loss to us but which will only be resolved when one or more future events occur or fail to occur. Our management and legal counsel assess such contingent liabilities, and such assessment inherently involves an exercise of judgment. When assessing loss contingencies related to pending legal proceedings against us or unasserted claims that may result in such proceedings, our management and legal counsel evaluate the perceived merits of any legal proceedings or unasserted claims as well as the perceived merits of the amount of relief sought or expected to be sought therein. We accrue an undiscounted liability for those contingencies where the incurrence of a loss is probable and the amount can be reasonably estimated. If a range of amounts can be reasonably estimated and no amount within the range is a better estimate than any other amount, then the minimum of the range is accrued. We do not record a contingent liability when the likelihood of loss is probable but the amount cannot be reasonably estimated or when the likelihood of loss is believed to be only reasonably possible or remote. For contingencies where an unfavorable outcome is reasonably possible and the impact would be material to our financial statements, we disclose the nature of the contingency and, where feasible, an estimate of the possible loss or range of loss. Loss contingencies considered remote are generally not disclosed or recognized unless they involve guarantees, in which case the guarantee would be disclosed. We have no unconditional purchase commitments or contingent liabilities at December 31, 2021 or 2020. Environmental Costs Our operations are subject to extensive federal and state environmental regulations. Environmental costs for remediation are accrued based on estimates of known remediation requirements. Such accruals are based on management’s best estimate of the ultimate cost to remediate a site and are adjusted as further information and circumstances develop. Those estimates may change substantially depending on information about the nature and extent of contamination, appropriate remediation technologies and regulatory approvals. Expenditures to mitigate or prevent future environmental contamination are capitalized. Ongoing environmental compliance costs are charged to expense as incurred. In accruing for environmental remediation liabilities, costs of future expenditures for environmental remediation are not discounted to their present value, unless the amount and timing of the expenditures are fixed or reliably determinable. We have no accrued liabilities for environmental remediation projects at December 31, 2021 or 2020. Estimates Preparing our financial statements in conformity with GAAP requires us to make estimates that affect amounts presented in the financial statements. Our most significant estimates relate to (i) the useful lives and depreciation/amortization methods used for fixed and identifiable intangible assets and (ii) revenue and expense accruals. Actual results could differ materially from our estimates. On an ongoing basis, we review our estimates based on currently available information. Any changes in the facts and circumstances underlying our estimates may require us to update such estimates, which could have a material impact on our financial statements. Fair Value Information The carrying amounts of cash and cash equivalents, accounts receivable and accounts payable approximate their fair values based on their short-term nature.

 

8 Impairment Testing for Long-Lived Assets Long-lived assets, which consist of intangible assets with finite useful lives and property, plant and equipment, are reviewed for impairment when events or changes in circumstances indicate that the carrying amount of such assets may not be recoverable. Long-lived assets with carrying values that are not expected to be recovered through future cash flows are written down to their estimated fair values. The carrying value of a long-lived asset is deemed not recoverable if it exceeds the sum of undiscounted cash flows expected to result from the use and eventual disposition of the asset. If the asset’s carrying value exceeds the sum of its undiscounted cash flows, a non-cash asset impairment charge equal to the excess of the asset’s carrying value over its estimated fair value is recorded. Fair value is defined as the price that would be received to sell an asset or paid to transfer a liability in an orderly transaction between market participants at a specified measurement date. We measure fair value using market price indicators or, in the absence of such data, appropriate valuation techniques. We did not recognize any asset impairment charges during the years ended December 31, 2021 and 2020, or for the period July 31, 2019 through December 31, 2019. Income Taxes We are organized as a pass-through entity for federal income tax purposes. As a result, our financial statements do not provide for such taxes, and our Members are individually responsible for their allocable share of our taxable income for federal income tax purposes. Income taxes reflect our state tax obligations under the Revised Texas Franchise Tax (the “Texas Margin Tax”). Deferred income tax liabilities are recognized for temporary differences between our assets for financial reporting and tax purposes. Based on our pre-tax book net income, our effective income tax rate was 0.6%, 0.8% and 0.9% for the years ended December 31, 2021 and 2020, and for the period July 31, 2019 through December 31, 2019, respectively. Property, Plant and Equipment Property, plant and equipment is recorded at historical cost. Expenditures for additions, improvements and other enhancements to property, plant and equipment are capitalized, and minor replacements, maintenance, and repairs that do not extend asset life or add value are charged to expense as incurred. When property, plant and equipment assets are retired or otherwise disposed of, the related cost and accumulated depreciation is removed from the accounts and any resulting gain or loss is included in results of operations for the respective period. In general, depreciation is the systematic and rational allocation of an asset’s cost, less its residual value (if any), to the reporting periods it benefits. Our property, plant and equipment is depreciated using the straight-line method, which results in depreciation expense being incurred evenly over the life of an asset. Our estimate of depreciation expense incorporates management assumptions regarding the useful economic lives and residual values of our assets. Asset retirement obligations (“AROs”) consist of estimated costs of dismantlement, removal, site reclamation and similar activities associated with the retirement of property, plant and equipment assets. We recognize the fair value of a liability for an ARO in the period in which it is incurred and can be reasonably estimated, with the associated asset retirement cost capitalized as part of the carrying value of the asset. ARO amounts are measured at their estimated fair value using expected present value techniques. Over time, the ARO liability is accreted to its present value (through accretion expense) and the capitalized amount is depreciated over the remaining useful life of the related long-term asset. We will incur a gain or loss to the extent that our ARO liabilities are not settled at their recorded amounts. See Note 3 for information regarding our property, plant and equipment and related AROs.

 

9 Revenues We account for our revenue streams using ASC 606, Revenue from Contracts with Customers, which requires the recognition of revenue in a manner that fairly depicts the transfer of goods or services to customers in amounts that reflect the consideration we expect to receive for those goods or services. We apply this core principle using the five key steps outlined in ASC 606: (i) identify the contract; (ii) identify the performance obligations in the contract; (iii) determine the transaction price; (iv) allocate the transaction price to the performance obligations in the contract; and (v) recognize revenue when (or as) the performance obligation is satisfied. Each of these steps involves management judgment and an analysis of the contract’s material terms and conditions. We classify our revenues as follows: (i) revenue from transportation service agreements (“TSAs”) and (ii) revenue from pipeline capacity arrangements. Revenues from TSAs are determined by multiplying a fixed transportation tariff per gallon by the volume transported by shippers. We recognize revenue from TSAs when the shipper’s volumes are redelivered. Revenues from capacity arrangements reflect a minimum amount billed regardless of whether the customer uses the capacity we make available to it, with a provision that allows the customer to make up any under- utilized capacity over an agreed-upon period (referred to as a customer “make-up right”), plus incremental contractual fees for throughput in excess of the base capacity volume. Revenue pursuant to the under-utilized capacity is initially deferred and subsequently recognized when either the make-up rights are exercised, the likelihood of the customer exercising the rights becomes remote, or we are otherwise released from the performance obligation. Revenues from the utilized capacity and the incremental contractual fees for throughput in excess of the base capacity volume are recognized when the associated volumes are redelivered. We believe these approaches to revenue recognition faithfully depict how we satisfy our performance obligations to shippers over time. The terms of our billings are typical of the midstream energy industry. See Note 6 for a description of our related party revenue arrangements. 3. Property, Plant and Equipment The historical cost of our property, plant and equipment and related accumulated depreciation balances were as follows at the dates indicated: Estimated Useful Life December 31, in Years 2021 2020 Pipeline assets 35 $ 1,444,615 $ 1,433,774 Transportation equipment 5 675 587 Land 3,460 3,482 Construction in progress 17 1,616 Total 1,448,767 1,439,459 Less accumulated depreciation 108,350 68,559 Property, plant and equipment, net $ 1,340,417 $ 1,370,900 We began recognizing depreciation expense on our pipeline asset when it was placed into service in February 2019. Depreciation expense was $39.8 million and $39.5 million for the years ended December 31, 2021 and 2020, respectively, and $15.4 million for the period July 31, 2019 through December 31, 2019. Asset Retirement Obligations We have AROs in connection with certain right-of-way agreements. Property, plant and equipment at December 31, 2021 and 2020 includes $3.9 million and $0.9 million, respectively, of asset retirement costs that were capitalized as an increase in the associated long-lived asset.

 

10 The following table presents information regarding our asset retirement liabilities for the periods presented: For the Year Ended December 31, For the Period July 31, 2019 Through December 31, 20192021 2020 Balance of ARO at beginning of period $ 1,197 $ 1,108 $ 1,328 Revision in estimated cash flows 3,033 -- (263) Accretion expense 161 89 43 Balance of ARO at end of period $ 4,391 $ 1,197 $ 1,108 The following table presents our forecast of accretion expense for the years indicated: 2022 2023 2024 2025 2026 $ 238 $ 253 $ 268 $ 285 $ 302 4. Intangible Asset During 2019, we recognized an intangible asset related to a connection agreement with an affiliate of Enterprise for connecting its storage facility in Mont Belvieu, Texas to our pipeline. Payment for this asset was made in 2020. We will amortize this intangible asset over a ten-year period, which commenced in February 2019 and corresponds to the tenure of our storage agreement with an affiliate of Enterprise (see Note 6). Amortization expense is computed using the straight-line method and was $0.5 million for each of the years ended December 31, 2021 and 2020, and $0.2 million for the period July 31, 2019 through December 31, 2019. Amortization expense for this intangible asset over the next five years is forecast to be $0.5 million annually. 5. Members’ Equity As a limited liability company, our Members are not personally liable for any of our debts, obligations or other liabilities. Income or loss amounts are allocated to our Members based on their respective membership interests. Cash contributions by and distributions to Members, if any, are also based on their respective membership interests. Cash contributions from Members for the period July 31, 2019 through December 31, 2019 reflect amounts contributed to construct Shin Oak. As described in Note 1, Altus acquired a 33% member interest in us upon exercising the option granted by Enterprise and providing an initial contribution of $440.7 million, which we immediately distributed to Enterprise. 6. Related Party Transactions Substantially all of our revenues for the years ended December 31, 2021 and 2020, and for the period July 31, 2019 through December 31, 2019 were earned from Enterprise and its affiliates. Revenues from Enterprise and its affiliates in connection with TSAs are based on actual volumes redelivered and a fixed transportation tariff of 4.5 cents per gallon (subject to annual escalations). Payments are due from these customers within 10 days from receipt of invoices.

 

11 Although the TSAs do not reflect minimum volume commitments, they do feature volume dedications from multiple origin points in West Texas that may aggregate up to 450 MBPD. The TSAs with Enterprise provide for a ten-year primary term, followed by two five-year extensions (each solely at the discretion of Enterprise). If a TSA has not been cancelled by either us or Enterprise at the end of the second five-year extension, the agreement will go evergreen year-to-year at that point and be cancellable by either us or Enterprise at the end of an evergreen contract year. A separate TSA with an affiliate of Enterprise also provides for a ten-year primary term. If this TSA is not cancelled by the affiliate of Enterprise at the end of the primary term, the agreement will go evergreen year-to-year at that point and be cancellable by the affiliate of Enterprise at the end of an evergreen contract year. Another affiliate of Enterprise utilizes Shin Oak for offloading mixed NGLs under a capacity arrangement that had an initial term of 15 years, with the option to extend the agreement for up to seven additional five-year terms at the election of the affiliate of Enterprise. The affiliate of Enterprise could cancel the capacity arrangement for any reason at any time during the term of the agreement by providing six months written notice to us. The capacity arrangement stipulated that the affiliate of Enterprise would pay us a monthly contractual fee of $5.1 million for the right to use 135 MBPD of available capacity on Shin Oak. We determined the amount of capacity available to the affiliate of Enterprise after first taking into account transportation commitments under our TSAs. The monthly contractual fee was subject to proportional reduction if (i) we determined that Shin Oak’s available capacity was less than 135 MBPD or (ii) the affiliate of Enterprise elected to use less than 135 MBPD of available capacity; however, the fee was subject to a floor amount of $3.8 million per month, which could have been reduced further if we were able to utilize any unused transportation capacity for our account. The affiliate of Enterprise would owe us the floor amount (or the reduced floor amount) regardless of whether it actually utilized the available capacity. Conversely, if we determined that Shin Oak had available capacity in excess of 135 MBPD, the affiliate of Enterprise had the right, but not the obligation, to use such excess capacity. To the extent such excess capacity was utilized by the affiliate of Enterprise, it would pay an incremental contractual fee that was in proportion to the monthly contractual fee of $5.1 million. In October 2021, the capacity arrangement was amended (the “amended capacity arrangement”) with an initial term of 10 years and the option to extend the agreement for up to seven additional five-year terms at the election of the affiliate of Enterprise. The amended capacity arrangement stipulates that the affiliate of Enterprise will pay us a monthly contractual fee of $4.2 million for the right to use 130 MBPD (the “base capacity volume”) of available capacity on Shin Oak. We determine the amount of capacity available to the affiliate of Enterprise after first taking into account transportation commitments under our TSAs. The monthly contractual fee, which is based on a fixed rate of 3 cents per gallon on the first 90 MBPD and a fixed rate of 1.5 cents per gallon (both rates subject to annual escalations) on the remaining 40 MBPD of the base capacity volume, is subject to reduction if we determine that Shin Oak’s available capacity is less than 130 MBPD. Conversely, if we determine that Shin Oak has available capacity in excess of the base capacity volume, the affiliate of Enterprise has the right, but not the obligation, to use such excess capacity. To the extent such excess capacity is utilized by the affiliate of Enterprise, it will pay an incremental contractual fee based on a fixed rate of 1.5 cents per gallon on the first 30 MBPD above the base capacity volume and a fixed rate of 1 cent per gallon (both rates subject to annual escalations) on all volumes above such first 30 MBPD. Since we have no employees, our operating functions, general and administrative support and project management services are provided by employees of an affiliate of Enterprise pursuant to an operating agreement (the “Operating Agreement”). Our reimbursements to Enterprise for payroll costs in connection with the Operating Agreement were $1.9 million for each of the years ended December 31, 2021 and 2020, and $0.8 million for the period July 31, 2019 through December 31, 2019. In addition, we paid Enterprise $2.1 million and $2.0 million for the years ended December 31, 2021 and 2020, respectively, and $0.8 million for the period July 31, 2019 through December 31, 2019 in management fees under the Operating Agreement. These related party costs are a component of operating costs and expenses on our Statements of Operations. We reserve underground storage capacity in Mont Belvieu, Texas from an affiliate of Enterprise. The agreement commenced in February 2019 and has an initial term of 10 years, with the option to extend the term thereafter on a year-to-year basis (up to 40 such renewals) at the discretion of the affiliate of Enterprise. The base annual cost of this storage reservation is approximately $2.8 million, with additional charges for overstorage and other customary amounts when required. We incurred related party operating expense in connection with this agreement of $2.9 million during each of the years ended December 31, 2021 and 2020, and $1.1 million during the period July 31, 2019 through December 31, 2019.

 

12 The following table summarizes our accounts receivable and accounts payable with related parties at the dates indicated: December 31, 2021 2020 Accounts receivable – related parties Altus $ 50 $ 61 Enterprise and its affiliates 9,099 7,747 Total $ 9,149 $ 7,808 Accounts payable – related parties Enterprise and its affiliates 317 74 Total $ 317 $ 74 7. Risks and Uncertainties Nature of Operations The NGL volumes we transport originate from domestic resource basins, which naturally deplete over time. Many economic and business factors beyond our control can adversely affect the decision by producers to explore for and develop new reserves. These factors could include relatively low crude oil and natural gas prices, cost and availability of equipment and labor, regulatory changes, capital budget limitations, the lack of available capital or the probability of success in finding hydrocarbons. A decrease in exploration and development activities in the region served by Shin Oak could result in a decrease in transportation volumes on our pipeline, which could have a material adverse effect on our financial position, results of operations and cash flows. Regulatory and Legal Risks As part of our normal business activities, we are subject to various laws and regulations, including those related to environmental matters. In the opinion of management, compliance with existing laws and regulations is not expected to have a material effect on our financial position, results of operations or cash flows. Also, in the normal course of business, we may be a party to lawsuits and similar proceedings before various courts and governmental agencies involving, for example, contractual disputes, environmental issues and other matters. We are not aware of any such material matters at December 31, 2021 or 2020. If new information becomes available, we will establish accruals and/or make disclosures as appropriate. Customer Concentration Enterprise and its affiliates account for substantially all of our revenues. The loss of this customer group would have a material adverse effect on our financial position, results of operations and cash flows.

 

FINANCIAL STATEMENTS With Report of Independent Auditor PERMIAN HIGHWAY PIPELINE LLC As of December 31, 2021 and 2020 and For the Years Ended December 31, 2021 and 2020

 

PERMIAN HIGHWAY PIPELINE LLC TABLE OF CONTENTS Page Number Report of Independent Auditor 1 Financial Statements Statements of Operations 3 Balance Sheets 4 Statements of Cash Flows 5 Statements of Members’ Equity 6 Notes to Financial Statements 7

 

1 Report of Independent Auditor Board of Directors and Members Permian Highway Pipeline LLC Houston, Texas Opinion We have audited the financial statements of Permian Highway Pipeline LLC (the “Company”), which comprise the balance sheets as of December 31, 2021 and 2020, and the related statements of operations, members’ equity, and cash flows for the years then ended, and the related notes to the financial statements. In our opinion, the accompanying financial statements present fairly, in all material respects, the financial position of the Company as of December 31, 2021 and 2020, and the results of its operations and its cash flows for the years then ended in accordance with accounting principles generally accepted in the United States of America. Basis for Opinion We conducted our audits in accordance with auditing standards generally accepted in the United States of America (GAAS). Our responsibilities under those standards are further described in the Auditor’s Responsibilities for the Audit of the Financial Statements section of our report. We are required to be independent of the Company and to meet our other ethical responsibilities, in accordance with the relevant ethical requirements relating to our audits. We believe that the audit evidence we have obtained is sufficient and appropriate to provide a basis for our audit opinion. Emphasis of Matter – Significant Transactions with Related Parties As discussed in Note 4 to the financial statements, the Company has entered into significant transactions with related parties. Responsibilities of Management for the Financial Statements Management is responsible for the preparation and fair presentation of the financial statements in accordance with accounting principles generally accepted in the United States of America, and for the design, implementation, and maintenance of internal control relevant to the preparation and fair presentation of financial statements that are free from material misstatement, whether due to fraud or error. In preparing the financial statements, management is required to evaluate whether there are conditions or events, considered in the aggregate, that raise substantial doubt about the Company’s ability to continue as a going concern within one year after the date that the financial statements are issued or available to be issued. Auditor’s Responsibilities for the Audit of the Financial Statements Our objectives are to obtain reasonable assurance about whether the financial statements as a whole are free from material misstatement, whether due to fraud or error, and to issue an auditor’s report that includes our opinion. Reasonable assurance is a high level of assurance but is not absolute assurance and therefore is not a guarantee that an audit conducted in accordance with GAAS will always detect a material misstatement when it exists. The risk of not detecting a material misstatement resulting from fraud is higher than for one resulting from error, as fraud may involve collusion, forgery, intentional omissions, misrepresentations, or the override of internal control. Misstatements are considered material if there is a substantial likelihood that, individually or in the aggregate, they would influence the judgment made by a reasonable user based on the financial statements.

 

2 In performing an audit in accordance with GAAS, we: a. Exercise professional judgment and maintain professional skepticism throughout the audit. b. Identify and assess the risks of material misstatement of the financial statements, whether due to fraud or error, and design and perform audit procedures responsive to those risks. Such procedures include examining, on a test basis, evidence regarding the amounts and disclosures in the financial statements. c. Obtain an understanding of internal control relevant to the audit in order to design audit procedures that are appropriate in the circumstances, but not for the purpose of expressing an opinion on the effectiveness of the Company’s internal control. Accordingly, no such opinion is expressed. d. Evaluate the appropriateness of accounting policies used and the reasonableness of significant accounting estimates made by management, as well as evaluate the overall presentation of the financial statements. e. Conclude whether, in our judgment, there are conditions or events, considered in the aggregate, that raise substantial doubt about the Company’s ability to continue as a going concern for a reasonable period of time. We are required to communicate with those charged with governance regarding, among other matters, the planned scope and timing of the audit, significant audit findings, and certain internal control-related matters that we identified during the audit. /s/ BDO USA, LLP Houston, Texas February 16, 2022

 

3 PERMIAN HIGHWAY PIPELINE LLC STATEMENTS OF OPERATIONS (In thousands) Year Ended December 31, 2021 2020 Revenues $ 397,237 $ 7,220 Operating Costs and Expenses Operations and maintenance 50,277 2,453 Depreciation and amortization 76,244 5,969 General and administrative 6,435 81 Taxes, other than income taxes 27,051 515 Total Operating Costs and Expenses 160,007 9,018 Operating Income (Loss) 237,230 (1,798) Other Income (Expense) Interest Income 5 512 Other, net 350 150 Total Other Income 355 662 Income (Loss) Before Income Taxes 237,585 (1,136) Income Tax Expense (1,057) (4) Net Income (Loss) $ 236,528 $ (1,140) The accompanying notes are an integral part of these financial statements.

 

4 PERMIAN HIGHWAY PIPELINE LLC BALANCE SHEETS (In thousands) December 31, 2021 2020 ASSETS Current assets Cash and cash equivalents $ 34,495 $ 12,622 Accounts receivable 13,307 248 Accounts receivable from affiliates 20,642 9,123 Other current assets 1,551 1,741 Total current assets 69,995 23,734 Property, plant and equipment, net 2,265,306 2,314,017 Deferred charges 2,634 2,159 Total Assets $ 2,337,935 $ 2,339,910 LIABILITIES AND MEMBERS’ EQUITY Current liabilities Accounts payable $ 4,888 $ 86,862 Accounts payable to affiliates 2,769 1,229 Accrued taxes, other than income taxes 24,792 6,363 Natural gas imbalance payable 1,910 875 Other current liabilities 2,298 534 Total current liabilities 36,657 95,863 Commitments and contingencies (Note 6) Members’ Equity 2,301,278 2,244,047 Total Liabilities and Members’ Equity $ 2,337,935 $ 2,339,910 The accompanying notes are an integral part of these financial statements.

 

5 PERMIAN HIGHWAY PIPELINE LLC STATEMENTS OF CASH FLOWS (In thousands) Year Ended December 31, 2021 2020 Cash Flows From Operating Activities Net income (loss) $ 236,528 $ (1,140) Adjustment to reconcile net income (loss) to net cash provided by operating activities: Depreciation and amortization 76,244 5,969 Change in components of working capital: Accounts receivable (30,886) (3,063) Accounts payable 1,215 3,099 Accrued taxes, other than income taxes 24,910 (121) Other current assets and liabilities 2,989 (128) Other long-term assets (475) (2,159) Net Cash Provided by Operating Activities 310,525 2,457 Cash Flows From Investing Activities Capital expenditures (109,355) (1,180,206) Net Cash Used in Investing Activities (109,355) (1,180,206) Cash Flows From Financing Activities Contributions from Members 96,960 1,111,274 Distributions to Members (276,257) — Net Cash (Used in) Provided by Financing Activities (179,297) 1,111,274 Net Increase (Decrease) in Cash and Cash Equivalents 21,873 (66,475) Cash and Cash Equivalents, beginning of period 12,622 79,097 Cash and Cash Equivalents, end of period $ 34,495 $ 12,622 The accompanying notes are an integral part of these financial statements.

 

6 PERMIAN HIGHWAY PIPELINE LLC STATEMENTS OF MEMBERS’ EQUITY (In thousands) Year Ended December 31, 2021 2020 Beginning Balance $ 2,244,047 $ 1,133,913 Net income (loss) 236,528 (1,140) Contributions 96,960 1,111,274 Distributions (276,257) — Ending Balance $ 2,301,278 $ 2,244,047 The accompanying notes are an integral part of these financial statements.

 

7 PERMIAN HIGHWAY PIPELINE LLC NOTES TO FINANCIAL STATEMENTS 1. General We are a Delaware limited liability company, formed on August 8, 2018. When we refer to “us,” “we,” “our,” “the Company,” or “PHP,” we are describing Permian Highway Pipeline LLC. The Members’ interests in us are as follows: • 26.66665% - Kinder Morgan Texas Pipeline LLC (KMTP), an indirect subsidiary of Kinder Morgan, Inc. (KMI); • 26.66665% - BCP PHP LLC (BCP), a portfolio company of Blackstone Energy Partners; • 26.66670% - Altus Midstream Processing LP (Altus), a subsidiary of Apache Corporation; and • 20% - an affiliate of an anchor shipper. In October 2021, it was announced that Altus and EagleClaw, a subsidiary of Blackstone Energy Partners, will merge and create a new midstream company. The transaction is expected to close in the first quarter of 2022 and upon completion of this transaction, the new midstream company would own a 53.333% interest in us. We were formed to develop, construct, own, operate and maintain the PHP pipeline system. Beginning in the Waha, Texas area and extending to the U.S. Gulf Coast and Mexico markets, the 430-mile pipeline is designed to transport up to approximately 2.1 billion cubic feet per day of natural gas. On November 1, 2020, the pipeline was placed into early in-service offering interruptible service only and was placed into full commercial service on January 1, 2021. 2. Summary of Significant Accounting Policies Basis of Presentation We have prepared our accompanying financial statements in accordance with the accounting principles contained in the Financial Accounting Standards Board’s Accounting Standards Codification, the single source of United States (U.S.) Generally Accepted Accounting Principles and referred to in this report as the Codification. Additionally, certain amounts from the prior year have been reclassified to conform to the current presentation. Management has evaluated subsequent events through February 16, 2022, the date the financial statements were available to be issued. Coronavirus Diseases 2019 (COVID-19) The COVID-19 pandemic resulted in reductions in energy demand and the dramatic decline in commodity prices in 2020. Sharp declines in the supply of and demand for energy related commodities due to the economic shutdown in the wake of the pandemic also affected the energy industry during 2020. The sustainability of the economic recovery observed in 2021 remains unclear as efforts to combat the virus have been complicated by new variants. Further, significant uncertainty remains regarding the duration and extent of the impact of the pandemic (including the pace and efficacy of vaccination efforts) on the energy industry, including demand and prices for hydrocarbons to reasonably predict the potential impact of COVID-19 on our business and operations. Use of Estimates Certain amounts included in or affecting our financial statements and related disclosures must be estimated, requiring us to make certain assumptions with respect to values or conditions which cannot be known with certainty at the time our financial statements are prepared. These estimates and assumptions affect the amounts we report for assets and liabilities, our revenues and

 

8 expenses during the reporting period, and our disclosures, including those related to contingent assets and liabilities at the date of our financial statements. We evaluate these estimates on an ongoing basis, utilizing historical experience, consultation with experts and other methods we consider reasonable in the particular circumstances. Nevertheless, actual results may differ significantly from our estimates. Any effects on our business, financial position or results of operations resulting from revisions to these estimates are recorded in the period in which the facts that give rise to the revision become known. Certain accounting policies are of more significance in our financial statement preparation process than others, and set out below are the principal accounting policies we apply in the preparation of our financial statements. Cash Equivalents We define cash equivalents as all highly liquid short-term investments with original maturities of three months or less. Allowance for Credit Losses We evaluate our financial assets measured at amortized cost and off-balance sheet credit exposures for expected credit losses over the contractual term of the asset or exposure. We consider available information relevant to assessing the collectability of cash flows including the expected risk of credit loss even if that risk is remote. We measure expected credit losses on a collective (pool) basis when similar risk characteristics exist and we reflect the expected credit losses on the amortized cost basis of the financial asset as of the reporting date. Our financial instruments primarily consist of our accounts receivable from customers. We utilized historical analysis of credit losses experienced over the previous five years along with current conditions and reasonable and supportable forecasts of future conditions in our evaluation of collectability of our financial assets. We had no allowance for credit losses recorded as of December 31, 2021 and 2020. Natural Gas Imbalances Natural gas imbalances occur when the amount of natural gas delivered from or received by a pipeline system differs from the scheduled amount of gas to be delivered or received. We value these imbalances due to or from shippers and operators at current index prices. Imbalances are settled in cash or made up in-kind. Imbalances due from others are reported on our accompanying Balance Sheets in “Other current assets.” Imbalances owed to others are reported on our accompanying Balance Sheets in “Natural gas imbalance payable.” We classify all imbalances due from or owed to others as current as we expect to settle them within a year. Property, Plant and Equipment, net Our property, plant and equipment is recorded at its original cost of construction. For constructed assets, we capitalize all construction-related direct labor and material costs, as well as indirect construction costs. The indirect capitalized labor and related cost amounts were established in the Construction Management Agreement (CMA) which represented the estimate of labor and related costs associated with supporting construction projects. We expense costs for routine maintenance and repairs in the period incurred. We use the composite method to depreciate our property, plant and equipment. Under this method, assets with similar economic characteristics are grouped and depreciated as one asset. When property, plant and equipment is retired, accumulated depreciation and amortization is charged for the original costs of the assets in addition to the costs to remove, sell or dispose of the assets, less salvage value. We do not recognize gains or losses upon normal retirement of assets under the composite depreciation method.

 

9 Asset Retirement Obligations (ARO) We record liabilities for obligations related to the retirement and removal of long-lived assets used in our businesses. We record, as liabilities, the fair value of ARO on a discounted basis when they are incurred and can be reasonably estimated, which is typically at the time the assets are installed or acquired. Amounts recorded for the related assets are increased by the amount of these obligations. Over time, the liabilities increase due to the change in their present value, and the initial capitalized costs are depreciated over the useful lives of the related assets. The liabilities are eventually extinguished when the asset is taken out of service. We are required to operate and maintain our natural gas pipeline system, and intend to do so as long as supply and demand for our services exists, which we expect for the foreseeable future. Therefore, we believe that we cannot reasonably estimate the ARO for the substantial majority of our assets because these assets have indeterminate lives. We continue to evaluate our ARO and future developments could impact the amounts we record. We had no ARO recorded as of December 31, 2021 and 2020. Long-lived Asset Impairments We evaluate our long-lived assets for impairment when events or changes in circumstances indicate that the carrying values may not be recoverable. These events include changes in the manner in which we intend to use a long-lived asset, decisions to sell an asset and adverse changes in market conditions, that are believed to be other than temporary, or in the legal or business environment such as adverse actions by regulators. If an event occurs, which is a determination that involves judgment, we evaluate the recoverability of the carrying value of our long-lived asset based on the long-lived asset’s ability to generate future cash flows using a two-step approach. If an impairment is indicated, or if we decide to sell a long-lived asset or group of assets, we adjust the carrying value of the asset downward, if necessary, to its estimated fair value. To determine if a long-lived asset is recoverable, we compare the asset’s estimated undiscounted cash flows to its carrying value (step 1). If the carrying value of a long-lived asset or asset group is in excess of estimated undiscounted cash flows, we typically use discounted cash flow analyses to calculate the fair value of the long-lived asset to determine if an impairment is required (step 2). Our fair value estimates are generally based on assumptions market participants would use, including market data obtained through the sales process or an analysis of expected discounted future cash flows. There were no impairments for the years ended December 31, 2021 and 2020. Revenue Recognition Revenue from Contracts with Customers We review our contracts with customers using the following steps to recognize revenue based on the transfer of goods or services to customers and in amounts that reflect the consideration the Company expects to receive for those goods or services. The steps include: (i) identify the contract; (ii) identify the performance obligations of the contract; (iii) determine the transaction price; (iv) allocate the transaction price to the performance obligations in the contract; and then (v) recognize revenue when (or as) the performance obligation is satisfied. Each of these steps involves management judgment and an analysis of the contract’s material terms and conditions. Our revenues are generated from the transportation of natural gas under firm service customer contracts with take-or-pay elements (principally for capacity reservation) where both the price and quantity are fixed. Generally, for these contracts: (i) our promise is to transfer (or stand ready to transfer) a series of distinct integrated services over a period of time, which is a single performance obligation; (ii) the transaction price includes both fixed and/or variable consideration which is determinable at contract inception and/or at each month end based on our right to invoice at month end for the value of services provided to the customer that month; and (iii) the transaction price is recognized as revenue over the service period specified in the contract as the services are rendered. In these arrangements, the customer is obligated to pay for services associated with its take-or-pay

 

10 obligation regardless of whether or not the customer chooses to utilize the service in that period. Because we make the service continuously available over the service period, we recognize the take-or-pay amount as revenue ratably over such period based on the passage of time. The natural gas we receive under our transportation contracts remains under the control of our customers. Under firm service contracts, the customer generally pays a two-part transaction price that includes (i) a fixed fee reserving the right to transport natural gas in our facilities up to contractually specified capacity levels (referred to as “reservation”) and (ii) a fee-based per-unit rate for quantities of natural gas actually transported in excess of contractual quantities. In our firm service contracts we generally promise to provide a single integrated service each day over the life of the contract, which is fundamentally a stand-ready obligation to provide services up to the customer’s reservation capacity prescribed in the contract. Our customers have a take-or- pay payment obligation with respect to the fixed reservation fee component, regardless of the quantities they actually transport. In other cases, generally described as interruptible service, there is no fixed fee associated with these transportation services because the customer accepts the possibility that service may be interrupted at our discretion in order to serve customers who have firm service contracts. We do not have an obligation to perform under interruptible customer arrangements until we accept and schedule the customer’s request for periodic service. The customer pays a transaction price based on a fee-based per-unit rate for the quantities actually transported. Refer to Note 5 for further information. Environmental Matters We capitalize or expense, as appropriate, environmental expenditures. We capitalize certain environmental expenditures required to obtain rights-of-way, regulatory approvals or permitting as part of the construction of facilities we use in our business operations. We accrue and expense environmental costs that relate to an existing condition caused by past operations, which do not contribute to current or future revenue generation. We generally do not discount environmental liabilities to a net present value, and we record environmental liabilities when environmental assessments and/or remedial efforts are probable and we can reasonably estimate the costs. Generally, our accrual of these environmental liabilities coincides with either our completion of a feasibility study or our commitment to a formal plan of action. We recognize receivables for anticipated associated insurance recoveries when such recoveries are deemed to be probable. We routinely conduct reviews of potential environmental issues and claims that could impact our assets or operations. These reviews assist us in identifying environmental issues and estimating the costs and timing of remediation efforts. We also routinely adjust our environmental liabilities to reflect changes in previous estimates. In making environmental liability estimations, we consider the material effect of environmental compliance, pending legal actions against us, and potential third-party liability claims we may have against others. Often, as the remediation evaluation and effort progresses, additional information is obtained, requiring revisions to estimated costs. These revisions are reflected in our income in the period in which they are reasonably determinable. We are subject to environmental cleanup and enforcement actions from time to time. In particular, the Comprehensive Environmental Response, Compensation and Liability Act generally imposes joint and several liability for cleanup and enforcement costs on current and predecessor owners and operators of a site, among others, without regard to fault or the legality of the original conduct, subject to the right of a liable party to establish a “reasonable basis” for apportionment of costs. Our operations are also subject to federal, state and local laws and regulations relating to protection of the environment. Although we believe our operations are in substantial compliance with applicable environmental laws and regulations, risks of additional costs and liabilities are inherent in our operations, and there can be no assurance that we will not incur significant costs and liabilities. Moreover, it is possible that other developments could result in substantial costs and liabilities to us, such as increasingly stringent environmental laws, regulations and enforcement policies under the terms of authority of those laws, and claims for damages to property or persons resulting from our operations. Although it is not possible to predict the ultimate outcomes, we believe that the resolution of the environmental matters, and other matters to which we are a party, will not have a material adverse effect on our business. We had no accruals for any outstanding environmental matters as of December 31, 2021 and 2020.

 

11 Income Taxes We are a limited liability company that is treated as a partnership for income tax purposes and are not subject to federal or state income taxes. Accordingly, no provision for federal or state income taxes has been recorded in our financial statements. The tax effects of our activities accrue to our Members who report on their individual federal income tax returns their share of revenues and expenses. However, we are subject to Texas margin tax (a revenue based calculation), which is presented as “Income Tax Expense” on our accompanying Statement of Operations. 3. Property, Plant and Equipment, net Our property, plant and equipment, net consisted of the following: Annual Depreciation Rates December 31, 2021 2020 % (In thousands) Transmission facilities 3.33 $ 2,249,547 $ 2,155,308 Intangible plant 3.33 85,390 45,958 General plant 10.0 - 20.0 2,162 1,637 Accumulated depreciation and amortization (82,213) (5,969) 2,254,886 2,196,934 Land 2,360 2,816 Construction work in progress 8,060 114,267 Property, plant and equipment, net $ 2,265,306 $ 2,314,017 4. Related Party Transactions LLC Agreement Under the terms of the LLC Agreement, our Members are obligated to make capital contributions to fund the construction of our pipeline. Affiliate Agreements As of September 4, 2018, we entered into a CMA and an Operations and Maintenance Agreement (OMA) with KMTP to develop and construct the PHP pipeline and to operate, maintain, and administer the pipeline and facilities once in-service or partially in-service. Pursuant to the CMA, we paid KMTP an owner fixed capital charge payable in monthly installments, which began in October 2018 and continued through the completion of the construction phase. Pursuant to the OMA, we pay KMTP an annual charge payable in equal monthly installments beginning with the full in-service of the pipeline system. Affiliate Balances and Activities We do not have employees. Employees of KMI provide services to us. In accordance with our governance documents, we reimburse KMI at cost.

 

12 The following table summarizes our other balance sheet affiliate balances not presented separately on the accompanying Balance Sheets: December 31, 2021 2020 (In thousands) Natural gas imbalance receivable(a) $ 119 $ — Deferred charges 1,568 1,568 Natural gas imbalance payable 1,475 875 (a) Included in “Other current assets” on our accompanying Balance Sheets. The following table shows revenues and costs from our affiliates: Year Ended December 31, 2021 2020 (In thousands) Revenues $ 241,951 $ 6,294 Operations and maintenance 30,790 1,755 General and administrative(a) 5,522 2 Capitalized costs(a) 885 42,806 (a) Includes costs associated with the affiliate agreements described above. Subsequent Events Subsequent to December 31, 2021 and through the issuance of this report, we made cash distributions to and received cash contributions from our Members totaling $33,151,000 and $1,500,000, respectively. 5. Revenue Recognition Disaggregation of Revenues The following table presents our revenues disaggregated by revenue source and type of revenue for each revenue source: Year Ended December 31, 2021 2020 (In thousands) Revenue from contracts with customers Services Firm services $ 395,309 $ — Fee-based services 1,928 7,220 Total revenues from contracts with customers $ 397,237 $ 7,220

 

13 Revenue Allocated to Remaining Performance Obligations The following table presents our estimated revenue allocated to remaining performance obligations for contracted revenue that has not yet been recognized, representing our “contractually committed” revenue as of December 31, 2021 that we will invoice or transfer from contract liabilities and recognize in future periods: Year Estimated Revenue (In thousands) 2022 $ 395,310 2023 395,310 2024 396,393 2025 395,309 2026 395,309 Thereafter 4,629,767 Total $ 6,607,398 Our contractually committed revenue, for purposes of the tabular presentation above, is generally limited to service customer contracts which have fixed pricing and fixed volume terms and conditions, generally including contracts with take-or-pay payment obligations. Our contractually committed revenue amounts generally exclude, based on the following practical expedient that we elected to apply, remaining performance obligations for contracts with variable volume attributes in which such variable consideration is allocated entirely to a wholly unsatisfied performance obligation. Major Customers The following table presents revenues from our largest customers, each of which exceeded 10% of our revenues as determined for each year individually and irrespective of the other periods presented below: Year Ended December 31, 2021 2020 (In thousands) Revenues from largest affiliated customer (number one) $ 81,377 $ 1,957 Revenues from largest affiliated customer (number two) 75,226 1,689 Revenues from largest affiliated customer (number three) 70,852 1,353 Revenues from largest affiliated customer (number four) n/a 1,295 Revenues from largest non-affiliated customer (number one) 75,171 908 Revenues from largest non-affiliated customer (number two) 56,393 n/a n/a - not applicable 6. Litigation and Commitments We are party to various legal, regulatory and other matters arising from the day-to-day operations of our business that may result in claims against the Company. Although no assurance can be given, we believe, based on our experiences to date and taking into account established reserves, that the ultimate resolution of such items will not have a material adverse impact on our business. We believe we have meritorious defenses to the matters to which we are a party and intend to vigorously defend the Company. 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.

 

14 Legal Proceedings Several lawsuits were filed by landowners and various governmental and non-governmental organizations while the PHP pipeline was being constructed which sought, among other relief, to enjoin construction or operation of the PHP pipeline. Those cases are resolved. On April 22, 2019, a lawsuit was filed in state court in Travis County, Texas by several landowners, a Texas county, and a municipality against PHP, the Texas Railroad Commission (RRC) and others alleging the administrative process by which gas utilities in Texas are granted certain permits and authority to exercise eminent domain violates the Texas Constitution. On July 5, 2019, the state court entered a final judgment dismissing all claims against the RRC, granting summary judgment in favor of PHP, and dismissing plaintiffs’ application for an injunction against PHP as moot. Plaintiffs filed an appeal in the Court of Appeals for the Third District of Texas. The Court of Appeals affirmed the trial court’s judgment on May 20, 2021. The case was captioned Andrew Sansom, et al. v. Texas Railroad Commission, et al. On January 25, 2020, a lawsuit was filed in the U.S. District Court for the W.D. of Texas—Austin Division, by several landowners against PHP and others. The lawsuit alleged the PHP pipeline is an interstate pipeline, that PHP should have secured a Certificate of Public Convenience and Necessity from the U.S. Federal Energy Regulatory Commission for construction and operation of the PHP pipeline, and that PHP, by not doing so, deprived the plaintiffs of procedural and substantive protections afforded them under federal law including the Natural Gas Act (NGA). PHP filed a motion to dismiss the case on March 3, 2020. The court dismissed the case on March 5, 2021. The case was captioned Belinda Kay Pence, et al. v. Permian Highway Pipeline, LLC, et al. On February 5, 2020, a lawsuit was filed in the U.S. District Court for the W.D. of Texas—Austin Division, by several landowners, two Texas counties, two municipalities and a conservation district against PHP, the U.S. Department of Interior (DOI), the U.S. Fish and Wildlife Service (FWS), and others alleging violations of the Endangered Species Act (ESA), the Administrative Procedure Act (APA), and the National Environmental Policy Act (NEPA). PHP filed a motion to dismiss the case on December 17, 2020. The U.S. Department of Justice, on behalf of the DOI and FWS, filed a motion to dismiss the case on January 15, 2021. The court dismissed the entire case on March 25, 2021. The case was captioned City of Austin, et al. v. Kinder Morgan Texas Pipeline, LLC, et al. General We had no accruals for any outstanding legal proceedings as of December 31, 2021 and 2020. Commitments Capital Commitments As of December 31, 2021, we had capital commitments of approximately $10,395,000 for purchases related to construction work in progress. Capacity Lease Commitments We have capacity lease commitments totaling $241,448,000 as of December 31, 2021, which are related to agreements with our affiliates, KMTP and Kinder Morgan Tejas Pipeline LLC, and a third party customer. We expect to spend $26,339,000 in 2022, $26,411,000 in 2023, $26,537,000 in 2024, $26,559,000 in 2025, $26,633,000 in 2026, and $108,969,000 in total thereafter. Transportation expense for the year ended December 31, 2021 was approximately $26,362,000 and is reflected in “Operations and maintenance” on our accompanying Statement of Income.

 

EPIC Crude Holdings, LP and Subsidiaries Consolidated Financial Statements For the Years Ended December 31, 2021, 2020, and 2019

 

EPIC Crude Holdings, LP and Subsidiaries Table of Contents Page Report of Independent Registered Public Accounting Firm 1 Consolidated Balance Sheets 2 Consolidated Statement of Operations 3 Consolidated Statement of Changes in Owners’ Equity 4 Consolidated Statement of Cash Flows 5 Notes to the Consolidated Financial Statements 6

 

Report of Independent Registered Public Accounting Firm To the Board of Directors and Owners EPIC Crude Holdings, LP: Opinion on the Consolidated Financial Statements We have audited the accompanying consolidated balance sheet of EPIC Crude Holdings, LP and subsidiaries (the Partnership) as of December 31, 2020, the related consolidated statements of operations, changes in owners’ equity, and cash flows for the year then ended, and the related notes (collectively, the consolidated financial statements). In our opinion, the consolidated financial statements present fairly, in all material respects, the financial position of the Partnership as of December 31, 2020, and the results of its operations and its cash flows for the year then ended, in conformity with U.S. generally accepted accounting principles. The consolidated financial statements of the Partnership as of December 31, 2019 and for the year then ended were audited by other auditors whose report dated March 11, 2020, expressed an unmodified opinion on those consolidated financial statements. Basis for Opinion These consolidated financial statements are the responsibility of the Partnership’s management. Our responsibility is to express an opinion on these consolidated financial statements based on our audit. We are a public accounting firm registered with the Public Company Accounting Oversight Board (United States) (PCAOB) and are required to be independent with respect to the Partnership 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 and in accordance with auditing standards generally accepted in the United States of America. Those standards require that we plan and perform the audit to obtain reasonable assurance about whether the consolidated financial statements are free of material misstatement, whether due to error or fraud. Our audit included performing procedures to assess the risks of material misstatement of the consolidated 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 consolidated financial statements. Our audit also included evaluating the accounting principles used and significant estimates made by management, as well as evaluating the overall presentation of the consolidated financial statements. We believe that our audit provides a reasonable basis for our opinion. /s/ KPMG LLP We have served as the Partnership’s auditor since 2020. San Antonio, Texas Feburary 25, 2021

 

EPIC Crude Holdings, LP and Subsidiaries Consolidated Balance Sheets December 31, 2021 and 2020 (Dollars in Thousands) Notes to the consolidated financial statements form an integral part of these statements. Page 2 (Unaudited) 2021 2020 Current assets Cash 25,358 9,433 Restricted cash 1,375 5,862 Account receivable 15,790 17,156 Related party receivable 46,375 55,009 Inventory 7,296 29,375 Prepaid expenses, deposits, and other current assets 4,995 6,160 Total current assets 101,189 122,995 Property and Equipment - net 2,176,579 2,267,630 Other assets Long-term deposits 1,037 5,175 Total assets 2,278,805 2,395,800 Current liabilities Accounts payable 5,990 8,203 Related party payable 5,910 6,902 Accrued expenses and other liabilities 34,741 35,281 Derivative liability - 4,197 Deferred revenue 338 740 Current portion of long-term debt 11,750 11,750 Total current liabilities 58,729 67,073 Long term liabilities Long-term debt, net of debt issuance costs 1,184,939 1,187,615 Other long-term liabilities 64 - Total long-term liabilities 1,185,003 1,187,615 Total liabilities 1,243,732 1,254,688 Owners' equity Owners' equity 1,035,073 1,141,112 Total liabilities and owners' equity 2,278,805 2,395,800

 

EPIC Crude Holdings, LP and Subsidiaries Consolidated Statement of Operations Years Ended December 31, 2021, 2020 and 2019 (Dollars in Thousands) Notes to the consolidated financial statements form an integral part of these statements. Page 3 (Unaudited) 2021 2020 2019 Transportation and terminal fees 139,694$ 165,047$ 40,756$ Sales of crude oil 25,080 923 - Total operating revenues 164,774 165,970 40,756 Operating expenses: Cost of goods sold 18,264$ -$ -$ Operations and maintenance 56,325 69,743 86,815 Loss on sale of assets 1,341 570 1,261 Gain on insurance proceeds (5,459) - - Inventory writedowns and project abandonments 3,540 24,476 - Depreciation 108,027 88,257 4,825 General and administrative 19,224 18,490 15,618 Total operating expenses 201,262 201,536 108,519 Operating Loss (36,488) (35,566) (67,763) Other income (expense) Interest expense - net (78,032) (74,045) (4,794) Other income (expense) 1 (3) 22 Total other expense (78,031) (74,048) (4,772) Net Loss (114,519)$ (109,614)$ (72,535)$ Consolidated Statement of Comprehensive Loss: Net loss (114,519)$ (109,614)$ (72,535)$ Changes in fair value of cash flow hedges 4,197 3,484 (7,681) Comprehensive loss (110,322)$ (106,130)$ (80,216)$

 

EPIC Crude Holdings, LP and Subsidiaries Consolidated Statement of Changes in Owners’ Equity Years Ended December 31, 2021, 2020 and 2019 (Dollars in Thousands) Notes to the consolidated financial statements form an integral part of these statements. Page 4 Balance at December 31, 2018 318,306$ Contributions 825,010 Net loss (72,535) Other comprehensive loss (7,681) Balance at December 31, 2019 1,063,100$ Contributions 195,000 Distribution related to purchase of assets (10,858) Net loss (109,614) Other comprehensive income 3,484 Balance at December 31, 2020 1,141,112$ Contributions 15,000 Distribution related to sale of inventory (10,717) Net loss (114,519) Other comprehensive income 4,197 Balance at December 31, 2021 (unaudited) 1,035,073$

 

EPIC Crude Holdings, LP and Subsidiaries Consolidated Statement of Cash Flows Years Ended December 31, 2021, 2020 and 2019 (Dollars in Thousands) Notes to the consolidated financial statements form an integral part of these statements. Page 5 (Unaudited) 2021 2020 2019 Cash flow from operating activities Net loss (114,520)$ (109,614)$ (72,535)$ Reconcil ing items: Depreciation of property and equipment 108,027 88,257 4,825 Amortization of debt issue costs 9,074 8,846 5,917 Inventory writedowns and project abandonments 3,540 24,476 - Loss on sale of asset 1,341 570 1,261 Changes in operating assets and l iabil ities: Accounts receivable 1,365 (4,447) (12,702) Prepaid expenses, deposits and inventory (470) 7,728 (3,352) Accounts payable and accrued expenses 4,130 11,888 34,434 Related party payable 7,751 (15,037) 9,427 Deferred income (402) 740 - Long-term deposits 4,138 - (4,445) Other long-term liabil ites 65 - - Net cash provided by / (used in) operating activities 24,039 13,407 (37,170) Cash flows from investing activities Repayments to parent - - 235,058 Capital expenditures (30,330) (451,670) (1,636,693) Cash advanded for asset purchase - - (82,299) Proceeds from disposal 15,635 166 551 Net cash used in investing activities (14,695) (451,504) (1,483,383) Cash flows from financing activities Proceeds from borrowings - 250,000 1,000,000 Repayments of borrowings (11,750) (2,937) (235,927) Proceeds from short term note payable 2,129 3,489 - Cash advances (to)/from related parties - - (136,726) Repayments of short term note payable (3,285) (364) - Contributions from partners 15,000 195,000 825,010 Debt issuance costs - (11,597) (50,863) Net cash provided by financing activities 2,094 433,591 1,401,494 Net increase / (decrease) in cash 11,438 (4,506) (119,059) Cash, including restricted cash, at beginning of year 15,295 19,801 138,860 Cash, including restricted cash, at end of year 26,733$ 15,295$ 19,801$ Supplemental Disclosures Cash paid for interest 65,248$ 75,847$ 59,362$ Supplemental Disclosures for Noncash Investing Activities Accounts payable and accrued capital expenditures 8,266$ 10,117$ 151,045$ Distributions related to purchase of assets -$ 10,858$ -$ Distributions related to sale of inventory 10,717$ -$ -$

 

EPIC Crude Holdings, LP and Subsidiaries Notes to the Consolidated Financial Statements Page 6 1. Operations and Nature of Business Presentation Reporting Entity and Nature of Operations EPIC Crude Holdings, LP (the “Partnership,” “Company,” “we,” “our,” or “us”) is a Delaware limited partnership formed in September 2017. In 2019, Rattler Midstream, LLC, Dos Rios Crude Holdings, LLC and Altus Midstream Processing, LP all became limited partners in the Partnership and members of EPIC Crude Holdings GP, LLC, which is the general partner of EPIC Crude Holdings, LP. The Partnership and its subsidiaries, EPIC Crude Marketing, LP; EPIC Crude Terminal Company, LP; EPIC Crude Pipeline, LP; and EPIC Crude Services, LP were created to acquire, construct, and operate crude oil midstream assets necessary to fulfill customer contracts to transport crude oil and condensate from West Texas to downstream infrastructure near Corpus Christi, Texas. Final construction of the Company’s nearly 700-mile large diameter pipeline originating near Orla, Texas and terminating near Corpus Christi, Texas was completed in the second quarter of 2020. The Company completed partial segments of its crude oil pipeline in 2019 and its waterborne crude loading facility in Corpus Christi, Texas. The crude project is supported by long-term contracts with shippers that include firm commitments and acreage dedications. 2. Estimates and Significant Accounting Policies Basis of Presentation The accompanying consolidated financial statements have been prepared in accordance with accounting principles generally accepted in the United States of America and include the accounts of the Partnership and its subsidiaries. Our reporting currency is U.S. dollars, and all references to dollars are U.S. dollars, unless stated otherwise. All significant intercompany balances and transactions have been eliminated in consolidation. The consolidated balance sheets, statements of operations, changes in members’ equity and cash flow for the year ended December 31, 2021 were not audited. All references to 2021 balances within the footnotes were also unaudited. Corrections to Prior Period Financial Statements During 2020, we identified an error related to the non-cash accrued capital expenditures classification within the Consolidated Statement of Cash Flows between operating and investing activities. The reclassification of the change in accounts payable related to capital expenditures for the year ended December 31, 2019 was previously reported within the operating section of the consolidated statement of cash flows and has correctly been reflected within the investing section of the consolidated statement in cash flows for the year ended December 31, 2019. The correction was not material to the prior period consolidated financial statements and resulted in: • a decrease of $25 million to net cash used in operating activities on the Consolidated Statement of Cash Flows, changes in operating assets and liabilities – accounts payable and accrued expenses; and • an increase of $25 million to net cash used in investing activities on the Consolidated Statement of Cash Flows, capital expenditures.

 

EPIC Crude Holdings, LP and Subsidiaries Notes to the Consolidated Financial Statements Page 7 The correction of the error did not have any impact on the Consolidated Balance Sheet, Consolidated Statement of Operations, or Consolidated Statement of Owner’s Equity as of or for the year ended December 31, 2019. Use of Estimates The preparation of financial statements in conformity with accounting principles generally accepted in the United States of America requires certain amounts included in or affecting our financial statements and related disclosures must be estimated, which requires us to make certain assumptions with respect to values or conditions which cannot be known with certainty at the time our financial statements are prepared. These estimates and assumptions affect the amounts we report for assets and liabilities, our revenues and expenses during the reporting period, and our disclosures, including as it relates to contingent assets and liabilities at the date of our financial statements. We evaluate these estimates on an ongoing basis, utilizing historical experience, consultation with experts, and other methods we consider reasonable in the particular circumstances. Nevertheless, actual results may differ significantly from our estimates. Any effects on our business, financial position or results of operations resulting from revisions to these estimates are recorded in the period in which the facts that give rise to the revision become known. In preparing our consolidated financial statements and related disclosures, examples of certain areas that require more judgment relative to others include, but are not limited to, our use of estimates in determining: (i) timing of certain transactions, (ii) economic useful lives of our assets for depreciation and amortization, (iii) purchase accounting allocations, (iv) market value of inventory, (v) provisions for uncollectible accounts receivable, (vi) revenue recognition and (vii) contingency reserves related to environmental or litigation claims. Recent Accounting Pronouncements Leases In February 2016, the Financial Accounting Standards Board (“FASB”) issued Accounting Standards Update No. 2016-02, Leases (Topic 842) (“ASU 2016-02”), which establishes the principles that lessees and lessors shall apply to report information about the amount, timing, and uncertainty of cash flows arising from a lease. The update requires lessees to record virtually all leases on their balance sheets. For lessors, this amended guidance modifies the classification criteria and the accounting for sales-type and direct financing leases. Leases will be classified as either finance or operating, with classification affecting the pattern of expense recognition in the statement of income. A modified retrospective transition approach is required for lessees for capital and operating leases existing at, or entered into after, the beginning of the earliest comparative period presented in the consolidated financial statements, with certain practical expedients available. In November 2019, the FASB issued Accounting Standards Update No. 2019-10 (“ASU 2019-10”), which deferred the effective date for the adoption of the lease guidance for one year from the original effective date. Based on the Coronavirus Disease 2019 (“COVID-19”) pandemic, the FASB issued Accounting Standards Update No. 2020-05 (“ASU 2020-05”), which granted a limited deferral of the effective dates for ASU 2016-02 in June 2020. The limited deferral period is for one year, and the new effective date is for fiscal years beginning after December 15, 2021, including interim periods within those fiscal years. The Partnership elected to take the limited deferral period granted in ASU 2020-05 and will adopt this standard beginning with its first quarter of fiscal 2022 and apply it retrospectively at the beginning of the period of adoption through a cumulative-effect adjustment to retained earnings.

 

EPIC Crude Holdings, LP and Subsidiaries Notes to the Consolidated Financial Statements Page 8 The Partnership has performed several procedures to evaluate the impact of the adoption of this standard on financial statements and disclosures and address the implications of Topic 842 on future lease arrangements. The procedures include reviewing all forms of leases, performing a completeness assessment over the lease population, establishing processes to timely identify new and modified lease agreements, educating its employees on these new processes. The Partnership is finalizing its evaluation of the impacts that the adoption of this accounting guidance will have on the consolidated financial statements and estimates approximately $8.3 million of rights-of-use assets and of lease liabilities will be recognized in the consolidated balance sheet upon adoption, with no material impact to its consolidated statement of operations. Financial Instruments – Credit Losses In June 2016, the FASB issued Accounting Standards Update No. 2016-13, “Financial Instruments - Credit Losses” (Topic 326) (“ASU 2016-13”), which requires organizations to measure all current expected credit losses for financial instruments held at the reporting date based on historical experience, current conditions, and reasonable and supportable forecasts. ASU 2016-13 is expected to improve financial reporting by requiring timelier recording of credit losses on financial assets measured at amortized costs basis including, but not limited to loans, net investments in leases and off-balance sheet credit exposure. ASU 2016-13 eliminates the probable initial recognition threshold under the current incurred loss methodology for recognizing credit losses. The Partnership will incorporate forward-looking information and macroeconomic factors into its credit loss estimates. ASU 2016-13 requires enhanced disclosures to help investors and other financial statement users to better understand significant estimates and judgments used in estimating credit losses, as well as the credit quality and underwriting standards of an organization’s portfolio. In May 2019, the FASB issued ASU 2019-05, Financial Instruments - Credit Losses ("ASU 2019-05"), to provide targeted transition relief upon the adoption of ASU 2016-13. The amendment provides an entity with the option to irrevocably elect the fair value option on certain financial assets on transition. ASU 2016-13 and its subsequent amendments is effective for annual reporting periods beginning after December 15, 2022, including interim periods within those annual reporting periods. The Partnership is currently evaluating the impact of its pending adoption of the new current expected credit loss standard on its consolidated financial statements. Cash and Cash Equivalents Cash includes bank deposits and all overnight cash sweep short-term investments that have a maturity of less than one day. We maintain our cash deposits with high credit quality financial institutions. At times, our cash may be uninsured or in deposit accounts that exceed the Federal Deposit Insurance Corporation insurance limits. Restricted Cash Restricted cash is restricted as to withdrawal or use under the terms of certain financial credit agreements including cash held to meet certain reserve requirements under the terms of our credit agreements.

 

EPIC Crude Holdings, LP and Subsidiaries Notes to the Consolidated Financial Statements Page 9 (Unaudited) December 31, 2021 December 31, 2020 December 31, 2019 Cash 25,358$ 9,433$ 15,212$ Restricted Cash 1,375 5,862 4,589 Total cash, including restricted cash, shown in the Consolidated Statement of Cash Flows 26,733$ 15,295$ 19,801$ Accounts Receivable These amounts primarily consist of amounts due from customers net of allowance for doubtful accounts. The allowance for doubtful accounts is established as losses are estimated to have occurred through a provision for bad debts charged to earnings. Losses are charged against the allowance when management believes, based on available customer-specific information and circumstances, the receivable is determined to be uncollectible. Subsequent recoveries, if any, are credited to the allowance. The allowance for doubtful accounts is evaluated on a regular basis by management and is based on historical experience and specifically identified questionable receivables. There was no allowance for doubtful accounts as of December 31, 2021 and 2020. Inventory Inventory consists principally of pipe, materials and spare parts held in primarily two warehouse locations. Inventory is held at lower of cost or market. The partnership recognized inventory write-offs of $0.4 million and $12.6 million during the years ended December 31, 2021 and 2020, respectively, primarily relating to obsolescence and scrapping in 2021 and adjustments to carrying value as of December 31, 2020 of large diameter pipe due to lower steel prices. There were no inventory write-offs during the year ended December 31, 2019. Property, Plant and Equipment Property and equipment are stated at cost less accumulated depreciation. Renewals and betterments that substantially extend the useful lives of the assets are capitalized. Maintenance and repairs that do not extend the useful life or add capacity are expensed when incurred. Additionally, we capitalize certain costs directly related to the construction of assets including internal labor costs, engineering costs and right-of- way easement costs. Depreciation expense is calculated on the straight-line method over the following estimated useful lives of the assets: Furniture, fixtures, and office equipment 3 years Right of Way 10 – 30 years Machinery, equipment, and buildings 10 – 40 years Vessels, towers, and tanks 25 – 30 years Pipelines 30 years Property, plant and equipment is evaluated for impairment whenever events or changes in business circumstances and market conditions indicate that the carrying amount of assets may not be recoverable. If such a review should indicate that the carrying amount of long-lived assets is not recoverable, we reduce the carrying amount of such assets to fair value.

 

EPIC Crude Holdings, LP and Subsidiaries Notes to the Consolidated Financial Statements Page 10 Debt Issuance Costs Debt issuance costs related to a recognized debt liability are presented in the balance sheet as a direct deduction from the carrying amount of that debt liability. Debt issuance costs are being amortized to interest expense using the effective interest method over the term of the related debt. Comprehensive Income Accounting principles generally require that recognized revenue, expenses, and gains and losses be included in net income. Although certain changes in assets and liabilities, such as unrealized gains and losses on cash flow hedges, are reported as a separate component of the equity section of the balance sheet, such items, along with net income, are components of comprehensive income. Asset Retirement Obligations We have determined that we are obligated by contractual or regulatory requirements to remove facilities or perform other remediation upon retirement of certain assets. The fair value of any asset retirement obligation (“ARO”) is determined based on estimates and assumptions related to retirement costs, which the Partnership bases on historical retirement costs, future inflation rates and credit-adjusted risk-free interest rates. An ARO is required to be recorded when a legal obligation to retire an asset exists and such obligation can be reasonably estimated. We will record an asset retirement obligation in the periods in which management can reasonably estimate the settlement dates. Management was not able to reasonably measure the fair value of asset retirement obligations as of December 31, 2021 and 2020, in most cases because the settlement dates were indeterminable. Although some of our assets are subject to agreements or regulations that give rise to an ARO upon the discontinued use of these assets, AROs were not recorded because these assets have an indeterminate removal or abandonment date given the expected continued use of the assets with proper maintenance or replacement. The retirement obligations for these assets cannot be measured at this time. Individual component assets have been and will continue to be replaced, but the pipelines and the terminal facilities will continue in operation as long as supply and demand for crude oil exists. Based on the widespread use of crude oil in industrial and refining activities, management expects supply and demand to exist for the foreseeable future. We have in place a continuous repair and maintenance program that keeps the pipelines and the terminal facilities in good operational condition. Therefore, although some of the individual assets may be replaced, the pipelines and the facilities themselves will remain intact indefinitely. Revenue Recognition The Partnership accounts for revenue from contracts with customers in accordance with ASU No. 2014- 09, Revenue from Contracts with Customers, and a series of related accounting standard updates included Accounting Standards Codification Topic 606. The principles for recognizing revenue under Topic 606 is an entity should recognize revenue as that entity satisfies its performance obligations which are represented by a promise in contract to transfer to a customer either a distinct good or service or a series of distinct goods or services over a period of time. Topic 606 requires that a contract’s transaction price, which is the amount of consideration to which an entity expects to be entitled in exchange for transferring promised goods or services to a customer, is to be allocated to each performance obligation in the

 

EPIC Crude Holdings, LP and Subsidiaries Notes to the Consolidated Financial Statements Page 11 contract based on relative standalone selling prices and recognized as revenue when control of the goods or services transfers to the customer and the performance obligation is satisfied, whether that is a point in time or over a period of time. Our customer service contracts primarily include two distinct services: (i) transportation services, and (ii) terminaling services. We provide disaggregated data for these two distinct services in Footnote # 12 Revenue Recognition. The contract structure for these services is consistent and discussed in further detail below. For the majority of these contracts, our promise is to transfer a distinct good or service (or bundle of goods or services) over a period of time, which represents a single performance obligation. The transaction price includes fixed and/or variable consideration which is generally determinable at contract inception and/or upon our right to invoice for the standalone value of services provided to the customer during the preceding time period which is commonly at month end or upon completion of services if the services were transferred over a period of time that is less than one month. If upon evaluation, we determined the contract contained multiple performance obligations we would identify and allocate the total contract consideration we expect to be entitled to, to each distinct performance obligation. The transaction price is recognized as revenue over the service period specified in the contract, either based on the passage of time or a units-based method for quantifying the transfer of services and satisfaction of our performance obligation over the service period or at a point in time. We provide services on both a firm and interruptible basis. These particular type of services are distinct from one another in that the Partnership must stand ready to perform the services under firm customer contracts regardless of whether that customer actually requires us to perform the service. Firm service contracts are a promise to make capacity available to the customer at all times during the period(s) covered by the contract. As consideration for us making capacity available, firm service contracts are typically structured with a minimum volume commitment, which requires a customer to pay for a minimum quantity even if they choose not to use the capacity/service in the specified service period (referred to as “deficiency payments”). We typically recognize the portion of the transaction price associated with making capacity available that was unused by the customer (“volume shortfall”), which required a deficiency payment, as revenue depending on whether the contract allows the customer to deliver excess volumes in subsequent periods and “make-up” the volume shortfall. If contractually the customer cannot make up volume shortfalls in future periods, our performance obligation is satisfied, and revenue associated with any deficiency payments is generally recognized as the contractual service period expires. Consequently, if the customer can acquire the promised service in a future period and make-up the volume shortfall in a future period, we have a performance obligation to transfer services at the customer’s request in the future. As the Company’s performance obligation has not yet been satisfied, we defer any consideration received as deficiency payments as a liability, and will recognize a proportionate amount as revenue once either: (i) the customer makes-up the volume shortfall and we have fully satisfied our obligation thru performance or (ii) the customer becomes unable to exercise their right to make-up the volume shortfall (e.g., there is insufficient capacity to make-up the volumes or the service period expires). For services transferred from the Company to the customer over a period of time we recognize the transaction price as revenue as those units of service are transferred to the customer in the specified service period (i.e., customer utilizes transportation capacity made available by the Company and receives the transfer of services from the Company during the service period).

 

EPIC Crude Holdings, LP and Subsidiaries Notes to the Consolidated Financial Statements Page 12 For interruptible service contracts, where the Company transfers transportation or terminaling services over a period of time we recognize the transaction price as revenue as those units of service are transferred to the customer in the specified service period, generally over a period of one month. Operating Costs and Expenses Operating expenses include all costs incurred to provide customers with transportation services and maintain Partnership assets, including compensation for operations personnel, vehicle expenses, fuel, cathodic protection, chemicals, utilities required for operations and maintenance and repair activities. General and administrative expenses include all partnership related expenses, insurance and compensation for executive and administrative personnel. Accounting for Price Risk Management Activities – Interest The Company engages in price risk management activities for nontrading purposes to manage forward interest rate risk. The Partnership does not engage in speculative trading. During 2019, the Partnership entered into interest rate swap agreements to hedge its floating interest rate risk on a portion of its issued and outstanding term loan. All derivative instruments are recorded in the consolidated balance sheets at their fair values. Changes in the derivative instrument’s fair value are recorded currently in earnings, unless the derivative qualifies as a cash flow hedge. Changes in the fair value of derivative instruments designated as cash flow hedges, to the extent they are effective in offsetting cash flows attributable to the hedged risk, are recorded in other comprehensive loss until the hedged item is recognized in earnings. There was no ineffectiveness recognized during the years ended December 31, 2021, 2020, and 2019. The company paid $4.2 million, $13.6 million, and $1.3 million related to its interest rate swaps during 2021, 2020, and 2019, respectively. The interest rate swaps expired in March 2021. Income Taxes For U.S. federal income tax purposes, the Partnership’s income is not directly subject to income tax and the Partnership is treated as a pass-through entity. Limited Partnerships (LPs) are formed in accordance with the laws of the state in which they are organized. LPs, such as the Partnership, are treated as partnerships or disregarded entities for federal income tax purposes, depending upon the structure. All income, expenses, gains and losses are passed through to and reported by its owner and ultimately flow to individual taxpayers. Accordingly, no provision has been made for federal income taxes in the accompanying consolidated financial statements. The Partnership is subject to the Texas state gross margin tax. The provision for state income taxes is immaterial for the years ended December 31, 2021, and 2020. Certain transactions may be subject to accounting treatment for income tax that differs from the presentation under GAAP. Accordingly, items of net income or loss and balances in the member’s capital accounts may differ between the balances presented in the accompanying financial statements and the balances shown in the respective income tax returns.

 

EPIC Crude Holdings, LP and Subsidiaries Notes to the Consolidated Financial Statements Page 13 The Partnership has evaluated tax positions taken or expected to be taken and concluded that there are no uncertain tax positions requiring adjustment to the consolidated financial statements for the years ended December 31, 2021, 2020, and 2019. The Partnership tax years are open to income tax examinations by U.S. federal, state or local tax authorities for tax years 2017, 2018, 2019, and 2020. Conclusions regarding the evaluation are subject to review and may change based on factors including, but not limited to, ongoing analysis of tax laws, regulations and interpretations thereof. The Partnership accounts for deferred income taxes using the asset and liability method. Under this method, deferred tax assets and liabilities are recognized for the future taxes attributable to the difference between financial statement carrying amounts of assets and liabilities and their respective tax basis. Deferred tax assets are also recognized for the future tax benefits attributable to the expected utilization of tax net operating loss carryforwards. In the event future utilization is determined to be unlikely, a valuation allowance is provided to reduce the tax benefits from such assets. There were no deferred tax assets or liabilities recorded as of December 31, 2021 or 2020. Contingencies Certain conditions may exist as of the date the consolidated financial statements are issued, which may result in a loss to the Partnership, but which will only be resolved when one or more future events occur or fail to occur. The Partnership’s management and its legal counsel assess such contingent liabilities, and such assessment inherently involves an exercise of judgment. In assessing loss contingencies related to legal proceedings that are pending against the Partnership or unasserted claims that may result in such proceedings, the Partnership’s legal counsel evaluates the perceived merits of any legal proceedings or unasserted claims, as well as the perceived merits of the amount of relief sought or expected to be sought therein. If the assessment of a contingency indicates that it is probable that a material loss has been incurred and the amount of the liability can be estimated, then the estimated liability would be accrued in the Partnership’s consolidated financial statements based on the available facts and circumstances surrounding the matter in question. If the estimated loss has a range of possible outcomes and all outcomes are equally possible, we accrue the lowest amount within the possible range. If the assessment indicates that a potentially material loss contingency is not probable, but is reasonably possible, or is probable, but cannot be estimated, then the nature of the contingent liability, together with an estimate of the range of possible loss, if determinable and material, would be disclosed. Loss contingencies considered remote are generally not disclosed unless they involve guarantees, in which case the guarantees would be disclosed. Risks and Uncertainties The Company’s future financial condition and results of operations are highly dependent on throughput volumes being transported through the Company’s pipeline. Customer demand is based on the demand and prices received by customers for their oil, gas and natural gas liquids production. Commodity prices are subject to wide fluctuation in response to relatively minor changes in the supply of and demand for oil, gas and natural gas liquids, and market uncertainty, and a variety of additional factors beyond the Company’s control. These factors include the supply of oil and gas reserves in our areas of operations, the level of consumer demand, weather conditions, government regulations and taxes, the price and availability of alternative fuels, and overall economic conditions. A decline in oil, gas and natural gas liquids

 

EPIC Crude Holdings, LP and Subsidiaries Notes to the Consolidated Financial Statements Page 14 prices may adversely affect the Company’s cash flow, liquidity, and profitability as customers reduce the amount of drilling activity in our areas of operations. 3. Fair Value Measurements and Disclosures The requirements of ASC 820, Fair Value Measurements and Disclosures apply to all financial instruments and all nonfinancial assets and nonfinancial liabilities that are being measured and reported on a fair value basis. Fair value is defined as the price that would be received to sell an asset or paid to transfer a liability in an orderly transaction between market participants at the measurement date. ASC 820 also establishes a fair value hierarchy that prioritizes the inputs used in valuation methodologies into the following three levels: • Level 1 Inputs – Unadjusted quoted prices in active markets for identical assets or liabilities. • Level 2 Inputs – Observable inputs other than Level 1 prices, such as quoted prices for similar assets or liabilities, or other inputs that can be corroborated by observable market data for substantially the full term of the assets or liabilities. • Level 3 Inputs – Unobservable inputs that are supported by little or no market activity and that are significant to the fair value of the assets or liabilities. Level 3 assets and liabilities include financial instruments whose value is determined using pricing models, discounted cash flow methodologies, or other valuation techniques, as well as instruments for which the determination of fair value requires significant management judgment or estimation. The fair value of the Company’s cash, cash equivalents, and trade accounts receivable and payable approximates the carrying amounts of such instruments due to their short maturity. The fair value of the Company’s debt approximates the carrying amounts of such instrument due to the variable interest rate. The Company obtains fair value measurements for derivative instruments from reputable pricing services. The fair value measurements are based on option pricing and discounted cash flow models which consider observable data that include forward market prices, volatilities and risk-free interest rates. The general classification of such instruments pursuant to the valuation hierarchy is set forth below. The swaps expired in March 2021. No fair value measurement was necessary at December 31, 2021. The following table represents liabilities measured at fair value on a recurring basis, as reported on the Consolidated Balance Sheet as of December 31, 2020 and by level within the fair value measurement hierarchy (dollars in thousands): Total Fair Value Level 1 Level 2 Level 3 Interest rate derivatives (4,197)$ -$ (4,197)$ -$ Fair Value Measurements at December 31, 2020

 

EPIC Crude Holdings, LP and Subsidiaries Notes to the Consolidated Financial Statements Page 15 4. Accounts Receivable Accounts receivable consist of the following (dollars in thousands): (Unaudited) December 31, December 31, 2021 2020 Trade receivables 15,376$ 15,879$ Related party receivables 46,375 55,009 Other receivables 414 1,277 Accounts Receivable, gross 62,165$ 72,165$ Trade receivables arise from the transportation of crude oil, terminal and storage services and the sale of crude oil to third party customers. There is $17.2 million of total trade receivables due as of December 31, 2021 from transportation, terminal services and crude oil sales of which $1.8 million is included in related party receivables. Related party receivables represent amounts owed to the Partnership for transportation of crude oil, terminal and storage services and for reimbursement of certain construction related activities that were performed under a single agreement or performance requirement by a vendor for the benefit of the Partnership and a related party. These certain construction services are critical to the construction and operations of the Partnership’s pipelines and terminals. See Footnote # 13 Related Party Transactions for further discussion of these transactions. 5. Property, Plant and Equipment Property, plant and equipment is comprised primarily of office equipment, furniture, and fixtures and crude oil transportation pipelines and associated facilities that were placed in-service in 2021, 2020 and 2019. The Partnership has placed in service a 700-mile pipeline originating near Orla, Texas and terminating near Corpus Christi, Texas at two waterborne crude loading facilities, various refineries, and third-party terminals in the Corpus Christi, Texas region. The Company placed $27.5 million and $1.923 billion, of assets into service during the years ended December 31, 2021 and 2020, respectively, primarily related to new pipeline mileage and connections to third party pipelines at our crude terminals in 2021 and pipeline assets and associated facilities in West Texas and Corpus Christi, Texas, as well as our first crude waterborne crude loading facility in Corpus Christi, Texas in 2020. Property, plant and equipment, net as of December 31, 2021 and 2020 consisted of the following (dollars in thousands):

 

EPIC Crude Holdings, LP and Subsidiaries Notes to the Consolidated Financial Statements Page 16 (Unaudited) December 31, 2021 December 31, 2020 Land 10,669$ 10,669$ Office equipment, furniture and fixtures 115,948 113,030 Pipeline 1,448,334 1,441,794 Machinery, equipment and buildings 227,752 214,933 Vessels, towers and tanks 233,567 228,553 ROW 292,252 292,305 Construction in progress - pipeline 49,224 59,486 Property, plant and equipment, gross 2,377,746$ 2,360,770$ Less: Accumulated depreciation and amortization (201,167) (93,140) Property, plant and equipment - less depreciation expense 2,176,579$ 2,267,630$ Depreciation is provided using the straight-line method based on the estimated useful life of each asset. Depreciation expense for the year ended December 31, 2021, 2020, and 2019, was $108 million, $88.3 million, and 4.8 million, respectively. We recognized the following capitalized interest amount in property, plant and equipment for the periods ended December 31, 2021, 2020, and 2019 as presented of $0.1 million, $24.1 million, $60.7 million, respectively. The partnership recognized impairment costs of $3.2 million and $11.9 million for the years ended December 31, 2021 and 2020, respectively, primarily related to Oryx connection at our Crane Terminal and additional costs for the Saragosa lateral abandonment in 2021, and the abandonment of the Saragosa lateral pipeline project in West Texas in 2020. These are recorded as Inventory writedowns and project abandonments on the Consolidation Statement of Operations. There were no impairment costs recognized in the year ended December 31, 2019. 6. Long-Term Debt Our outstanding long-term debt obligations consisted of the following (dollars in thousands): (Unaudited) December 31, 2021 December 31, 2020 Term Loan due 2026 1,160,313$ 1,172,063$ Revolving Credit Facil ity 75,000 75,000 Less: Deferred debt issuance costs (38,624) (47,698) Total Debt 1,196,689$ 1,199,365$ Less: Current Maturities (11,750) (11,750) Total Long-term debt, less current maturities 1,184,939$ 1,187,615$

 

EPIC Crude Holdings, LP and Subsidiaries Notes to the Consolidated Financial Statements Page 17 Term Loan Credit Agreement The Partnership has a Term Loan Credit Agreement dated March 1, 2019 which provides secured project financing in an aggregate principal amount of up to $1 billion due 2026 (“Term Loan”). Term Loan proceeds were used to pay off the outstanding Bridge Loan amount of $250 million and fund continued project construction costs. The Term Loan Credit Agreement was amended in February 2020 to provide for an additional $100 million Incremental Term Loan. The Partnership also entered into an additional Term Loan agreement in February 2020 with the same lender for additional principle amount of $75 million due 2026. Borrowings under all of our Term Loans bear interest at the LIBOR plus an applicable margin or a base rate as defined in the Term Loan Credit Agreements. The Term Loan Credit Agreement provides for a $75 million secured revolving credit facility commitment (“Revolving Credit Facility”) due 2024 for which any borrowings bear interest at the LIBOR plus an applicable margin or a base rate as defined in the Term Loan Credit Agreement. We had $75 million of borrowings under the revolving facility during 2020. The interest rate on the total amount outstanding under the Term Loan as of December 31, 2021, 2020, and 2019 was 5.13%, 5.26%, and 7.04%, respectively. The interest rate on the total amount outstanding on the Revolving Credit Facility as of December 31, 2021 and 2020 was 4.88% and 4.98%, respectively. Substantially all of our assets and equity are pledged as collateral under the Term Loan Credit Agreement. The Agreement contains customary representations and warranties and various covenants that limit the Partnership’s ability to, among other things, incur indebtedness, grant liens, enter into mergers, dispose of assets, or enter sales-leaseback transactions. In addition, the Agreement requires the Partnership to maintain the following financial covenants: • Minimum debt service coverage ratio of 1.1x commencing the 2nd full fiscal quarter occurring after completion • Maximum superpriority leverage ratio of 1.0x commencing the 2nd full fiscal quarter occurring after completion. The superpriority leverage ratio is calculated using only superpriority debt as defined by the Credit Agreement, which included only the outstanding balance of the Revolving Credit Facility as of December 31, 2021. The Partnership was in compliance with financial covenants related to our debt agreements as of December 31, 2021. Maturities of the Term Loan and Revolving Credit Facility for each of the five succeeding years are as follows (in thousands): Years Ending December 31, (unaudited) Term Loan Revolver Total 2022 11,750 - 11,750 2023 11,750 - 11,750 2024 11,750 75,000 86,750 2025 11,750 - 11,750 2026 1,113,313 - 1,113,313 Total 1,160,313$ 75,000$ 1,235,313$

 

EPIC Crude Holdings, LP and Subsidiaries Notes to the Consolidated Financial Statements Page 18 7. Short-Term Notes Payable The Partnership entered into a short-term note during the year ended December 31, 2021 for financing of its insurance policies. The balance of the short-term note at December 31, 2021 is $2.0 million, which is included in Accrued Expense and Other Liabilities on the Consolidated Balance Sheet. The interest rate for the note at December 31, 2021 is 2.89%. The Partnership entered into two short-term notes during the year ended December 31, 2020 for financing of its insurance policies. The balance of the short-term notes at December 31, 2020 is $3.1 million, which is included in Accrued Expense and Other Liabilities on the Consolidated Balance Sheet. The weighted average interest rate for the notes at December 31, 2020 is 3.06%. 8. Commitments and Contingent Liabilities The Partnership is subject to various regulatory, civil and legal claims and proceedings covering a wide range of matters that arise in the ordinary course of our business activities. Although no assurances can be given, management believes any liability that may ultimately result from the resolution of these matters will not have a material adverse effect on the consolidated financial condition or results of operations of the Partnership. We disclose contingencies where an adverse result may be material, or in the decision of management, we conclude the matter should be disclosed. The Partnership does not have any contingent liabilities recorded as of December 31, 2021 and 2020. Litigations Claims August 21, 2020 Corpus Christi Ship Channel Dredging Incident On August 21, 2020, a partially submerged third-party pipeline located along the Corpus Christi Ship Channel near a crude export facility owned by EPIC Crude Terminal Company, LP (“EPIC Terminal”), a wholly owned subsidiary of the Company, ruptured and released propane gas into the air. A dredge barge owned and operated by a contactor retained by EPIC Terminal to perform dredging operations was in the vicinity at the time of the rupture and caught fire when the propane gas ignited. Five crewmembers of the barge were killed and several other crewmembers were injured. No EPIC Terminal personnel were injured. The National Transportation Safety Board (the “NTSB”) investigated the incident and determined that the dredging contractor struck the submerged propane pipeline with a dredge cutter head, and no liability was attributed to EPIC Terminal. Several lawsuits were filed in connection with the incident. The contractor’s carriers accepted EPIC Terminal’s tender as an additional insured under the contractor’s insurance policies and the contractor acknowledged its defense and indemnity obligations to EPIC Terminal and its affiliates pursuant to the parties’ services agreement. In January 2022, all claims and litigation were settled on behalf of the EPIC Terminal and its affiliates by the dredging contractor and its insurance carriers. As a result of the settlement, EPIC Terminal and its affiliates were released from all claims arising from the incident and the Company received a settlement payment of approximately $1.2 million from the dredging contractor’s insurers. July 30, 2019 Line Strike by Pumpco On July 30, 2019, during construction of crude pipeline owned by EPIC Crude Pipeline, LP (“EPIC Crude”), a wholly owned subsidiary of the Company, an employee of a contractor retained by EPIC Crude to

 

EPIC Crude Holdings, LP and Subsidiaries Notes to the Consolidated Financial Statements Page 19 construct its pipeline struck a nearby third-party pipeline with a trencher. No injuries were sustained, but the line strike resulted in the release of crude oil from the third-party pipeline. The appropriate regulatory authorities were notified, and remediation efforts by the contractor and EPIC Crude commenced immediately. The affected landowner made certain demands to both the contractor and EPIC Crude but did not initiate litigation. The contractor’s carriers acknowledged EPIC Crude’s status as an additional insured under the contractor’s insurance policies. On June 30, 2021, EPIC Crude and the contractor and its insurance carrier reached a settlement agreement with the landowner, which provided for a one-time settlement payment and a comprehensive restoration plan funded by the contractor and its insurance carrier. As a result of the settlement, EPIC Crude and its affiliates were released from all landowner claims arising from the incident, subject to satisfactory completion of the restoration plan. Additional Matters The Partnership maintains its cash in bank deposit accounts which, at times, may exceed federally insured limits. Accounts are guaranteed by the Federal Deposit Insurance Corporation up to a maximum of $250,000. The Partnership has not experienced any losses in such accounts. 9. Owners’ Equity Owner’s equity is composed of Class A units which represent limited partner interests in us. The holders of our Class A units are entitled to participate in our distributions (to the extent distributions are made) and are entitled to exercise the rights and privileges available to limited partners under our partnership agreement. No other class of units is issued and outstanding as of December 31, 2021. In 2019, EPIC Crude Parent, LP, sold: (i) a 10% equity stake in the Partnership to Rattler Midstream, LLC, (ii) a 30% equity stake in the Partnership to Dos Rios Crude Holdings, LLC, and (iii) a 15% equity stake in the Partnership to Altus Midstream Processing, LP. The transactions noted herein reduced EPIC Crude Parent, LP’s overall ownership of the Partnership to 45%. There have been no other equity transactions, other than contributions to the Partnership during 2021, 2020, and 2019 of which all contributions were made in proportion to each limited partner’s ownership noted above. 10. Derivative Financial Instrument Interest Rate Derivative Activities The Company held four interest rate swap contracts in 2021, 2020, and 2019. The interest rate swaps expired in March 2021. The aggregate fair value of the Company’s derivative instruments included in the accompanying balance sheets consists of the following (dollars in thousands):

 

EPIC Crude Holdings, LP and Subsidiaries Notes to the Consolidated Financial Statements Page 20 (Unaudited) December 31, December 31, 2021 2020 Interest rate derivatives Current derivative l iabil ity Designated as hedging instruments -$ (4,197)$ Interest rate derivatives Long-term derivative l iabil ity Designated as hedging instruments -$ -$ Total derivatives -$ (4,197)$ Balance Sheet Location Derivative Designation Total Fair Value Measurement at At December 31, 2021 and 2020, the fair value of derivatives did not include any offsetting amounts in the consolidated balance sheets. The following table details the location of gains (losses) on the Company’s derivatives recognized in the accompanying consolidated statements of comprehensive income (loss) (dollars in thousands): (Unaudited) December 31, December 31, December 31, 2021 2020 2019 Interest rate derivatives Other comprehensive income Designated as hedging instruments 4,197$ 3,484$ (7,681)$ Derivative designation Statement of Comprehensive Income (Loss) Location 11. Major Customers At December 31, 2021, the Partnership’s trade receivables balance was related to over 25 customers. Of those, 4 customers made up approximately 84% of the trade receivables balance as of December 31, 2021 and 59% of total revenues for the year ended December 31, 2021. At December 31, 2020, the Partnership’s trade receivables balance was related to nearly 20 customers. Of those, 5 customers made up approximately 93% of the trade receivables balance as of December 31, 2020 and 83% of total revenues for the year ended December 31, 2020. 12. Revenue Recognition We provide pipeline transportation and terminaling services, which includes product storage and export dock loading, on a firm and interruptible basis. For our firm transportation service, we typically promise to transport on a stand-ready basis the customer’s minimum volume commitment amount. The customer is obligated to pay for its volume commitment amount, regardless of whether the customer flows volumes into our pipeline. The customer pays a transaction price typically based on a per-unit rate for quantities transported, including amounts attributable to deficiency quantities, or can be structured as a purchase and sale that contain fixed differential between the purchase and sale price to capture a margin relative to the service being performed. These transactions are included in our revenues on a net basis. Our firm terminal services generally follow the same recognition principles, however the nature of the contracted service is different in that we are not transporting volume for the customer but are delivering/loading product onto an ocean-going vessel at our waterborne terminal facility or providing crude oil storage. Non-firm transportation and terminaling services are provided to our customers when and to the extent we determine the requested capacity is available in our pipeline system and/or terminal facilities. The

 

EPIC Crude Holdings, LP and Subsidiaries Notes to the Consolidated Financial Statements Page 21 customer pays a per-unit rate for actual quantities of product transported, loaded onto a vessel or stored within our facilities. Firm and interruptible services, ultimately have the same end goal by our customers which is transporting product from origin to destination and loading product across our dock and/or storing volumes for future consumption. We sell crude oil to customers through the normal course of business. These sales are typically to capture a favorable differential between locations or crude grades. Additionally, our pipeline generates contractual crude oil gains that are sold to third party customers at prevailing market rates. Disaggregation of Revenues The following table present our revenues disaggregated by source of revenue for the years ended as indicated (dollars in thousands). (Unaudited) Year ended December 31, 2021 Year ended December 31, 2020 Year ended December 31, 2019 Revenues from contracts with customers Services Pipeline Transportation 128,041$ 142,397$ 39,325$ Terminaling and Storage 11,623 22,650 1,111 Total services revenues 139,664 165,047 40,436 Crude oil sales 25,080 923 320 Total revenues from contracts with customers 164,744$ 165,970$ 40,756$ Other revenues (1) 30 - - Total revenues 164,774$ 165,970$ 40,756$ (1) Amounts recognized as revenue under guidance prescribed in Topics of Accounting Standards Codification other than in Topic 606 and is composed entirely of lease revenues. The Company recorded revenues of $9.0 million, $9.9 million, and $0 associated with minimum volume commitments in which the customer did not fulfill their obligation to transport, load or store the entirety of their reserved capacity during the years ended December 31, 2021, 2020, and 2019, respectively. Of the total minimum volume commitment revenue we recognized minimum volume commitments for pipeline transportation services of $9.0 million and $8.9 million for the years ended December 31, 2021 and 2020, respectively. Contract Balances Contract assets and contract liabilities are the result of timing differences between revenue recognition, invoicing, and cash collections. We recognize contract assets in those instances where billing occurs subsequent to revenue recognition, and our right to invoice the customer is conditioned on something other than the passage of time. Conversely, we recognize contract liabilities when invoicing precedes the recognition of revenue as a future performance obligation exists. As of December 31, 2021 and 2020 we had $0.3 million and $0.7 million, respectively, recorded as deferred revenue for consideration received, or invoiced and due, for which we do have an enforceable obligation to perform in the future.

 

EPIC Crude Holdings, LP and Subsidiaries Notes to the Consolidated Financial Statements Page 22 13. Related Party Transactions The Partnership paid common control and affiliated related parties approximately $6.4 million, $8.4 million, and $16.5 million for certain operating expenses and reimbursement of general and administrative expenses during the years ended December 31, 2021, 2020, and 2019, respectively. The Partnership had approximately $1.3 million and $6.9 million payable to related parties for these expenses as of December 31, 2021 and 2020, respectively. Additionally, the Partnership made $1.3 million in payments to a common control related party to cover future operating and general and administrative expenses during the year ended December 31, 2021, of which $1 million is recorded as Long-term deposits and the remaining $0.3 million is recorded as Prepaid expenses, deposits, and other current assets on the Consolidated Balance Sheet. The Partnership provided $33.5 million, $30.9 million, and $5.1 million transportation and terminaling services to equity partner affiliates which are reflected the Partnership’s revenues for the year ended December 31, 2021, 2020 and 2019, respectively. The Partnership had approximately $1.8 million and $7.1 million due from related parties for these services as of December 31, 2021 and 2020, respectively. The Partnership paid an equity partner affiliate approximately $12.7 million for purchases of crude oil during the year ended December 31, 2021. The Partnership had approximately $1.4 million due to payable due at December 31, 2021 relating to the purchase of the crude oil. There were no purchases of crude oil during the year ended December 31, 2020 or 2019 from related parties. The Partnership paid a common control related party approximately $2.0 million, $82.3 million (as discussed in the paragraphs below), and $108.2 million during 2021, 2020 and 2019 for reimbursement of costs incurred to acquire multi-line rights-of-way easements, land purchases, and certain capital project related property, plant and equipment. Rights-of-way easements were assigned to the Partnership by the related party upon documentation of fully executed and properly recorded easements and submission for reimbursement of costs by the related party. The related party payable was $3.2 million and $0 as of December 31, 2021 and 2020, respectively, related to capital purchases. The Partnership reached an agreement in principle with a common control related party to purchase a section of 16-inch pipeline and paid the related party $82.3 million during 2019. The closing of the transaction occurred on April 30, 2020 and included the following assets, which were recorded as property, plant and equipment at net asset value (in thousands): Office equipment, furniture and fixtures 2,946$ Pipeline 60,507 Machinery, equipment and buildings 1,405 ROW 6,585 Total 71,443$ As the related party that sold the property, plant and equipment is under common control with the Partnership, we did not step-up the basis in the property, plant and equipment and recognized the difference between the purchase price and the net asset value as a distribution, which amounted to $10.9 million during the year ended December 31, 2020.

 

EPIC Crude Holdings, LP and Subsidiaries Notes to the Consolidated Financial Statements Page 23 The Partnership sold $15.7 million of inventory to a common control related party for $5.0 million during the year ended December 31, 2021. As the related party that purchased the inventory is under common control with the Partnership, we did not record a loss on sale of assets and recognized the difference between the sale price and the asset value as a distribution, which amounted to $10.7 million during the year ended December 31, 2021. In August 2019, the Partnership entered into a six-month pipeline capacity lease with a common control related party to utilize an idle pipeline to transport crude oil from Benedum, Texas to Robstown, Texas. This capacity lease allowed the Partnership to connect its West Texas pipeline assets to its Gulf Coast pipeline assets while the 30-inch diameter pipeline remained under construction. Under the terms of the capacity lease, the Partnership paid $13.1 million and $64.9 million for the leased asset to transport crude oil during the years ended December 31, 2020 and 2019, respectively. The capacity lease expired in February 2020. All costs associated with the capacity lease are included in operating expenses on the Consolidated statement of operations. There was no related party payable due at December 31, 2021 or 2020 relating to this transaction. The Partnership made $0 million, $24.7 million, and $43.9 million in payments during 2021, 2020, and 2019 respectively, to and/or on behalf of a common control related party for the construction related activities associated with the leak detection and telecommunication system that is critical to the operational viability of the Partnership’s pipeline system. All costs are reimbursable to the Partnership by the related party, and $44.5 million and $41.8 million remains outstanding and owed to the Partnership as of December 31, 2021 and 2020, respectively, and is recorded as Related party receivable in the Consolidated Balance Sheets. 14. Subsequent Events The Partnership has evaluated subsequent events through February 22, 2022, the date the consolidated financial statements were available to be issued and noted no events that merit disclosure.