10-K

UNITED STATES SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

__________________________________________

FORM 10-K

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

For the fiscal year ended December 31, 2023

Or

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

Commission File Number: 001-40392

DT Midstream, Inc.

Delaware	38-2663964
(State or other jurisdiction of incorporation or organization)	(I.R.S Employer Identification No.)

Registrant's address of principal executive offices: 500 Woodward Ave., Suite 2900, Detroit, Michigan 48226-1279

Registrant's telephone number, including area code: (313) 402-8532

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

Title of Each Class	Trading Symbol	Name of Exchange on which Registered
Common stock, par value $0.01	DTM	New York Stock Exchange

Securities registered pursuant to Section 12(g) of the Exchange 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 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 during the preceding 12 months (or for such shorter period that the registrant was required to submit such files).    Yes ☒    No ☐

Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer, a smaller reporting company, or an emerging growth company. See the definitions of "large accelerated filer," "accelerated filer," "smaller reporting company," and "emerging growth company" in Rule 12b-2 of the Exchange Act.

Large accelerated filer	Accelerated filer	Non-accelerated filer	Smaller reporting company	Emerging growth company
☒	☐	☐	☐	☐

If an emerging growth company, indicate by check mark if the registrant has elected not to use the extended transition period for complying with any new or revised financial accounting standards provided pursuant to Section 13(a) of the Exchange Act. ☐

Indicate by check mark whether the registrant 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 by the registered public accounting firm that prepared or issued its audit report. ☒

If securities are registered pursuant to Section 12(b) of the Exchange Act, indicate by check mark whether the financial statements of the registrant included in the filing reflect the correction of an error to previously issued financial statements. Yes ☐ No ☒

Indicate by check mark whether any of those error corrections are restatements that required a recovery analysis of incentive-based compensation received by any of the registrant’s executive officers during the relevant recovery period pursuant to Section 240.10D-1(b). Yes ☐ No ☒

Indicate by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the Exchange Act).     Yes ☐ No ☒

On June 30, 2023, the aggregate market value of DT Midstream's voting common stock was approximately $4.8 billion (based on the New York Stock Exchange closing price on such date).

Number of shares of common stock outstanding at February 8, 2024:

Description	Shares
Common stock, par value $0.01	96,979,556

DOCUMENTS INCORPORATED BY REFERENCE

Certain information in DT Midstream's definitive Proxy Statement for our 2024 Annual Meeting of Common Shareholders to be held May 10, 2024, which will be filed with the Securities and Exchange Commission pursuant to Regulation 14A, not later than 120 days after the end of the registrant’s fiscal year covered by this report on Form 10-K, is incorporated herein by reference to Part III (Items 10, 11, 12, 13, and 14) of this Form 10-K.

TABLE OF CONTENTS

		Page
	Definitions	1
	Forward-Looking Statements	4
PART I
Items 1. and 2.	Business and Properties	6
Item 1A.	Risk Factors	23
Item 1B.	Unresolved Staff Comments	38
Item 1C.	Cybersecurity	38
Item 3.	Legal Proceedings	38
Item 4.	Mine Safety Disclosures	38
PART II
Item 5.	Market for Registrant’s Common Equity, Related Stockholder Matters, and Issuer Purchases of Equity Securities	39
Item 7.	Management’s Discussion and Analysis of Financial Condition and Results of Operations	41
Item 7A.	Quantitative and Qualitative Disclosures About Market Risk	51
Item 8.	Financial Statements	52
Item 9.	Changes in and Disagreements with Accountants on Accounting and Financial Disclosure	87
Item 9A.	Controls and Procedures	87
Item 9B.	Other Information	87
Item 9C.	Disclosure Regarding Foreign Jurisdictions that Prevent Inspections	87
PART III
Item 10.	Directors, Executive Officers, and Corporate Governance	88
Item 11.	Executive Compensation	88
Item 12.	Security Ownership of Certain Beneficial Owners and Management and Related Stockholder Matters	88
Item 13.	Certain Relationships and Related Transactions, and Director Independence	88
Item 14.	Principal Accountant Fees and Services	88
PART IV
Item 15.	Exhibits and Financial Statement Schedules	89
Item 16.	Form 10-K Summary	90
	Signatures	91

DEFINITIONS

Unless the context otherwise requires, references to "we," "us," "our," "Registrant," or the "Company" and words of similar importance refer to DT Midstream and, unless otherwise specified, our consolidated subsidiaries and our unconsolidated joint ventures. As used in this Form 10-K, the terms and definitions below have the following meanings:

Appalachia Gathering	A 149-mile gathering system delivering Marcellus shale natural gas to the Texas Eastern Pipeline and Stonewall
ASC 606	The Accounting Standards Codification of Revenue from Contracts with Customers issued by the FASB
ASU	Accounting Standards Update issued by the FASB
Bcf	Billion cubic feet of natural gas
Bcf/d	Billion cubic feet of natural gas per day
Birdsboro	A 14-mile interstate pipeline transporting gas supply to a gas-fired power plant in Pennsylvania
Bluestone	A 65-mile lateral pipeline and two compression facilities delivering Marcellus shale natural gas to Millennium and the Tennessee Pipeline
Blue Union Gathering	A 420-mile gathering system delivering shale natural gas from the Haynesville formation of Louisiana to markets in the Gulf Coast region
CERCLA	Comprehensive Environmental Response, Compensation, and Liability Act
CFTC	Commodity Futures Trading Commission
Columbia Pipeline	Columbia Gas Transmission, LLC, owned by TC Energy Corporation and Global Infrastructure Partners
COVID-19	Coronavirus disease of 2019
Credit Agreement	DT Midstream's credit agreement provides for the Term Loan Facility and Revolving Credit Facility
Distribution	Pro rata distribution to DTE Energy shareholders of all the outstanding common stock of DT Midstream upon the Separation
DEI	Diversity, equity, and inclusion
DTE Energy	DTE Energy Company, the consolidating entity of DT Midstream prior to the Separation
DT Midstream	DT Midstream, Inc. and our consolidated subsidiaries
EPA	U.S. Environmental Protection Agency
EPAct 2005	Energy Policy Act of 2005
ESA	The U.S. federal Endangered Species Act
ESG	Environmental, social and corporate governance
FASB	Financial Accounting Standards Board
FERC	Federal Energy Regulatory Commission
GAAP	Generally Accepted Accounting Principles in the United States
Generation	A 25-mile intrastate transportation pipeline located in northern Ohio and owned by NEXUS
GHG	Greenhouse gas
Gillis Access Project	A new pipeline system in Louisiana owned by TC Energy Corporation
Haynesville System	Pipeline and gathering system which is comprised of LEAP, Blue Union Gathering, and associated facilities
HCA	High consequence area
Inflation Reduction Act	The Inflation Reduction Act of 2022 (H.R. 5374)

1

DEFINITIONS

LEAP	Louisiana Energy Access Project, a 209-mile lateral pipeline delivering Haynesville shale natural gas to markets in the Gulf Coast region
LIBOR	London Inter-Bank Offered Rates
LNG	Liquefied natural gas
Michigan System	A 335-mile pipeline system in northern Michigan
Millennium	Millennium Pipeline Company, LLC, a joint venture that owns a 263-mile interstate transportation pipeline and compression facilities serving markets in the northeast and supply from the northeast Marcellus region, in which DT Midstream owns a 52.5% interest
MVCs	Minimum volume commitments
National Grid	National Grid Millennium LLC
NEPA	National Environmental Policy Act
NEXUS	NEXUS Gas Transmission, LLC, a joint venture that owns (i) a 256-mile interstate pipeline and three compression facilities transporting Utica and Marcellus shale natural gas to Ohio, Michigan and Ontario market centers and (ii) Generation, in which DT Midstream owns a 50% interest
NGA	Natural Gas Act
NGPA	Natural Gas Policy Act
NWP 12	The U.S. Army Corps of Engineers Clean Water Act Section 404 Nationwide Permit 12
NYSE	New York Stock Exchange
Ohio Utica Gathering	A 20-mile gathering system, including compression and dehydration facilities, to deliver Utica shale gas from producer wells to a nearby processing plant
OSHA	The U.S. federal Occupational Safety and Health Act
PHMSA	Pipeline and Hazardous Materials Safety Administration
RCRA	Resource Conservation and Recovery Act
Revolving Credit Facility	DT Midstream's secured revolving credit facility issued under the Credit Agreement
SEC	Securities and Exchange Commission
Separation	The separation and spin-off of DT Midstream from DTE Energy, effective July 1, 2021
Separation and Distribution Agreement	The Separation and Distribution Agreement with DTE Energy was established before the Distribution to set forth DT Midstream's agreements with DTE Energy regarding the principal actions to be taken in connection with the Separation, as well as other agreements that govern aspects of DT Midstream's relationship with DTE Energy following the Separation
SOFR	Secured Overnight Financing Rate
South Romeo	South Romeo Gas Storage Company, LLC, a joint venture which owns the Washington 28 Storage Complex, in which DT Midstream owns a 50% interest
Southwestern Energy	Southwestern Energy Company and/or its affiliates
Stonewall	Stonewall Gas Gathering Lateral Pipeline, a 68-mile pipeline delivering Marcellus and Utica shale natural gas to the Columbia Pipeline, in which DT Midstream owns an 85% interest
Susquehanna Gathering	A 198-mile gathering system delivering Marcellus shale natural gas to Bluestone
Tax Matters Agreement	The agreement that governs the respective rights, responsibilities and obligations of DTE Energy and DT Midstream after the Separation with respect to all tax matters
Tennessee Pipeline	Tennessee Gas Pipeline Company, LLC, owned by Kinder Morgan, Inc.
Term Loan Facility	DT Midstream's term loan facility issued under the Credit Agreement

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DEFINITIONS

Texas Eastern Pipeline	Texas Eastern Transmission, LP, owned by Enbridge Inc.
Tioga Gathering	A 3-mile gathering system delivering shale natural gas to the Dominion Transmission interconnect
U.S.	United States of America
USD	United States Dollar ($)
Vector	Vector Pipeline LP, a joint venture that owns a 348-mile interstate transportation pipeline and five compression facilities connecting Illinois, Michigan, and Ontario market centers, in which DT Midstream owns a 40% interest
VIE	Variable Interest Entity
Washington 10 Storage Complex	An interstate storage system located in Michigan with 94 Bcf of storage capacity and associated compression facilities, in which DT Midstream owns a 91% interest
WOTUS	Navigable Waters Protection Rule under the U.S. federal Clean Water Act
2020 PIPES Act	Protecting Our Infrastructure of Pipelines and Enhancing Safety Act of 2020
2029 Notes	Senior unsecured notes of $1.1 billion in aggregate principal amount due June 2029
2031 Notes	Senior unsecured notes of $1.0 billion in aggregate principal amount due June 2031
2032 Notes	Senior secured notes of $600 million in aggregate principal amount due April 2032

3

FORWARD-LOOKING STATEMENTS

Certain information presented herein includes "forward-looking statements" within the meaning of the Private Securities Litigation Reform Act of 1995 with respect to the financial condition, results of operations, and businesses of DT Midstream. Words such as "believe," "expect," "expectations," "plans," "strategy," "prospects," "estimate," "project," "target," "anticipate," "will," "should," "see," "guidance," "outlook," "confident," and other words of similar meaning in connection with a discussion of future operating or financial performance may signify forward-looking statements. Forward-looking statements are not guarantees of future results and conditions, but rather are subject to numerous assumptions, risks, and uncertainties that may cause actual future results to be materially different from those contemplated, projected, estimated, or budgeted. Many factors may impact forward-looking statements of DT Midstream including, but not limited to, the following:

•changes in general economic conditions, including increases in interest rates and associated Federal Reserve policies, a potential economic recession, and the impact of inflation on our business;

•industry changes, including the impact of consolidations, alternative energy sources, technological advances, infrastructure constraints and changes in competition;

•global supply chain disruptions;

•actions taken by third-party operators, processors, transporters and gatherers;

•changes in expected production from Southwestern Energy and other third parties in our areas of operation;

•demand for natural gas gathering, transmission, storage, transportation and water services;

•the availability and price of natural gas to the consumer compared to the price of alternative and competing fuels;

•our ability to successfully and timely implement our business plan;

•our ability to complete organic growth projects on time and on budget;

•our ability to finance, complete, or successfully integrate acquisitions;

•the price and availability of debt and equity financing;

•restrictions in our existing and any future credit facilities and indentures;

•the effectiveness of the Company's information technology and operational technology systems and practices to detect and defend against evolving cyber attacks on United States critical infrastructure;

•changing laws regarding cybersecurity and data privacy, and any cybersecurity threat or event;

•operating hazards, environmental risks and other risks incidental to gathering, storing and transporting natural gas;

•geologic and reservoir risks and considerations;

•natural disasters, adverse weather conditions, casualty losses and other matters beyond our control;

•the impact of outbreaks of illnesses, epidemics and pandemics, and any related economic effects;

•the impacts of geopolitical events, including the conflicts in Ukraine and the Middle East;

•labor relations and markets, including the ability to attract, hire and retain key employee and contract personnel;

•large customer defaults;

•changes in tax status, as well as changes in tax rates and regulations;

•the effects and associated cost of compliance with existing and future laws and governmental regulations, such as the Inflation Reduction Act;

•changes in environmental laws, regulations or enforcement policies, including laws and regulations relating to climate change and GHG emissions;

4

FORWARD-LOOKING STATEMENTS

•ability to develop low carbon business opportunities and deploy GHG reducing technologies;

•changes in insurance markets impacting costs and the level and types of coverage available;

•the timing and extent of changes in commodity prices;

•the success of our risk management strategies;

•the suspension, reduction or termination of our customers’ obligations under our commercial agreements;

•disruptions due to equipment interruption or failure at our facilities, or third-party facilities on which our business is dependent; and

•the effects of future litigation.

The above list of factors is not exhaustive. New factors emerge from time to time. We cannot predict what factors may arise or how such factors may cause actual results to vary materially from those stated in forward-looking statements. Any forward-looking statements speak only as of the date on which such statements are made. We are under no obligation to, and expressly disclaim any obligation to, update or alter our forward-looking statements, whether as a result of new information, subsequent events or otherwise.

5

PART I

Items 1. and 2. Business and Properties

General

DT Midstream was incorporated in the state of Delaware in 2021. Our annual reports on Form 10-K, quarterly reports on Form 10-Q, current reports on Form 8-K, proxy statements, and all amendments to such reports are available free of charge through the Investors Relations page of DT Midstream's website: www.dtmidstream.com, as soon as reasonably practicable after they are filed with or furnished to the SEC. Additionally, the public may read and copy any materials that we file electronically with the SEC at www.sec.gov.

The DT Midstream Code of Conduct, Board of Directors' Code of Business Conduct and Ethics, Board of Directors' Governance Guidelines, Board of Directors' Committee Charters, and Categorical Standards for Director Independence are also posted on DT Midstream's website. The information on DT Midstream's website is not part of this report or any other report that DT Midstream files with, or furnishes to, the SEC.

Business Overview

We are an owner, operator, and developer of an integrated portfolio of natural gas midstream assets. We provide multiple, integrated natural gas services to customers through our interstate pipelines, intrastate pipelines, storage systems, lateral pipelines including related treatment plants and compression and surface facilities, and gathering systems including related treatment plants, and compression and surface facilities. We also own joint venture interests in equity method investees which own and operate interstate pipelines that connect to our wholly owned assets.

Our core assets strategically connect key demand centers in the Midwestern U.S., Eastern Canada and Northeastern U.S. regions to the premium production areas of the Marcellus/Utica natural gas formation in the Appalachian Basin and connect key demand centers and LNG export terminals in the Gulf Coast region to premium production areas of the Haynesville natural gas formation.

We have an established history of stable, long-term growth with contractual cash flows from customers that include natural gas producers, local distribution companies, electric power generators, industrials, and national marketers.

We believe that our properties are generally in good condition, well-maintained and suitable and adequate to carry on our business at capacity for the foreseeable future.

The Separation

On July 1, 2021, DT Midstream completed the Separation from DTE Energy and became an independent public company. See Note 1, "Description of the Business and Basis of Presentation" to the Consolidated Financial Statements under Part II, Item 8 of this Form 10-K.

6

2023 Executive Summary

During the year ended December 31, 2023, DT Midstream's accomplishments and business developments included:

•Attained Net Income Attributable to DT Midstream of $384 million;

•Declared total cash dividends of $2.76 per common share;

•Completed the conversion of the Michigan System from gathering to dry gas transmission service and began providing services under a new long-term dry gas transmission contract;

•Placed the LEAP phase 1 and phase 2 expansions into service early;

•Continued construction of the LEAP phase 3 expansion;

•Executed a commercial agreement and completed construction of a new gathering trunkline for Ohio Utica Gathering;

•Completed construction of 0.4 Bcf/d of new treating capacity for Blue Union Gathering;

•Continued construction of the Appalachia Gathering phase 2 expansion;

•Began construction of a new 1.0 Bcf/d LEAP interconnect with the Gillis Access Project, which will provide access to the Louisiana industrial and LNG corridor;

•Began construction on a new 0.4 Bcf/d supply interconnect with a third-party processing plant in Blue Union Gathering;

•Published our second annual Corporate Sustainability Report in the second quarter 2023. The information in our Corporate Sustainability Report is not incorporated by reference into this Form 10-K; and

•Advanced the carbon capture and sequestration project in Louisiana through filing the Class V test well permit application with the Louisiana Department of Natural Resources; the permit was received in January 2024.

7

Our Strategy

Our principal business objective is to safely and reliably operate and develop natural gas assets across our premier footprint. Our proven leadership and highly engaged employees have an excellent track record. Prospectively, we intend to continue this track record by executing on our natural gas-centric business strategy focused on disciplined capital deployment and supported by a flexible, well capitalized balance sheet. Additionally, we intend to develop low carbon business opportunities and deploy GHG reducing technologies as part of our goal of being leading environmental stewards in the midstream industry. We are executing on a plan to achieve net zero carbon emissions by 2050.

Our strategy is premised on the following principles:

•Operate our assets in a sustainable and responsible manner. We believe that consistently serving our communities, customers, team members, and stakeholders is foundational.

•Provide exceptional service to our customers. We will continue to provide safe, highly reliable, timely and cost-competitive service, which is a key distinguishing competitive advantage.

•Disciplined capital deployment in assets supported by strong fundamentals. New capital spending will continue to go through a rigorous review process to ensure that it is accretive and deployed to assets serving high quality, low cost resources with proximity to strong demand centers, meeting our strategic criteria and expected returns.

•Capitalize on asset integration and utilization opportunities. We intend to leverage the scale and scope of our large asset platforms, our services, and our capabilities to increase efficiency across our portfolio and in the strategically situated natural gas basins in which we operate.

•Pursue economically attractive opportunities. We intend to pursue economically attractive expansion opportunities that leverage our current asset footprint and strategic relationships with our customers.

•Grow cash flows supported by long-term firm service revenue contracts. We will continue pursuing opportunities that increase the demand-based component of our contract portfolio and will focus on obtaining additional long-term firm service commitments from customers, which may include fixed demand charges, MVCs and acreage dedications.

8

Our Operations and Business Segments

DT Midstream sets strategic goals, allocates resources, and evaluates performance based on the following two segments: Pipeline and Gathering. For financial information by segment for the last three years, see Note 14, "Segment and Related Information," to the Consolidated Financial Statements under Part II, Item 8 of this Form 10-K.

Southwestern Energy accounted for approximately 60% of our operating revenues for the year ended December 31, 2023. Our operating revenues do not include revenues of unconsolidated joint ventures accounted for as equity method investments.

Pipeline Segment

Description

Our Pipeline segment includes our interstate pipelines, intrastate pipelines, storage systems, lateral pipelines including related treatment plants and compression and surface facilities. The Pipeline segment also includes joint venture interests in equity method investees which own and operate interstate pipelines that connect to our wholly owned assets. Our subsidiary companies own and operate these types of assets across multiple states and eastern Canada.

Our interstate pipelines are FERC-regulated assets that transport natural gas from interconnected pipelines to power plants, local distribution companies and industrial end users, as well as interconnected pipelines for delivery to additional markets. Our intrastate pipelines are typically state-regulated assets that transport natural gas from interconnected pipelines to power plants, local distribution companies and industrial end users. Our lateral pipelines are assets that gather natural gas for our customers from multiple central delivery points within a basin and redeliver that natural gas to interstate pipelines, intrastate pipelines, and LNG export terminals for further downstream transportation and, accordingly, perform a gathering function not subject to FERC jurisdiction. Our storage systems provide natural gas storage services for customers, subject to FERC jurisdiction.

Revenues and Earnings from Equity Method Investees

DT Midstream primarily provides two types of pipeline and storage services: firm service and interruptible service. Firm service revenue contracts are typically long-term and structured using fixed demand charges or MVCs with fixed deficiency fee rates. This provides for fixed revenue commitments regardless of actual volumes of natural gas that flow, which leads to more stable operating performance, revenues and cash flows and limits our exposure to natural gas price fluctuations. For the year ended December 31, 2023, approximately 84% of our Pipeline revenue was generated under firm service revenue contracts and approximately 95% of the revenue of our unconsolidated joint ventures was generated under firm service revenue contracts. The earnings of our unconsolidated joint ventures are included in earnings from equity method investees in our Consolidated Statements of Operations. Interruptible service revenue contracts typically contain fixed rates, with total consideration dependent on actual natural gas volumes that flow.

For the year ended December 31, 2023, revenue from the Pipeline segment accounted for approximately 41% of our consolidated revenue. The cash flows from our Pipeline operations can be impacted in the short term by seasonality, weather fluctuations and the financial condition of our customers.

Competition

Our Pipeline operations compete for customers primarily based on geographic location, which determines connectivity and proximity to supply sources and end users, as well as price, operating reliability and flexibility, available capacity, and service offerings. Our primary competitors in the natural gas interstate pipelines and transmission market and in the lateral pipelines market include major interstate pipelines and midstream companies that can transport and gather natural gas volumes between interstate systems and between central delivery points within a basin, respectively.

9

Properties

The following table presents certain information concerning our principal properties included in the Pipeline segment:

Property Classification	% Owned	Operator	Capacity (Bcf/d)	Compression Horsepower	Description	Location
Pipeline
FERC-Regulated Interstate Pipelines
NEXUS (a)	50%	No	1.4	99,137	A joint venture that owns a 256-mile pipeline and three compression facilities transporting Utica and Marcellus shale natural gas to Ohio, Michigan and Ontario market centers and Generation	OH and MI
Vector (a)	40%	No	2.8	120,000	A joint venture that owns a 348-mile pipeline and five compression facilities connecting Illinois, Michigan and Ontario market centers	IL, IN, MI and Ontario
Millennium (a)	52.5%	No	1.9	84,389	A joint venture that owns a 263-mile pipeline and compression facilities serving markets in the northeast and supply from the northeast Marcellus region	NY
Birdsboro	100%	Yes	0.2	—	A 14-mile pipeline transporting gas supply to a gas-fired power plant in Pennsylvania	PA
Intrastate Pipelines
Generation	50%	No	0.4	—	A 25-mile pipeline located in northern Ohio and owned by NEXUS	OH
FERC-Regulated Storage System
Washington 10 Storage Complex (b)	91%	Yes	N/A	26,205	An interstate storage system with 94 Bcf of storage capacity and associated compression facilities	MI
Lateral Pipelines
Bluestone	100%	Yes	1.2	36,720	A 65-mile pipeline and two compression facilities delivering Marcellus shale natural gas to Millennium and the Tennessee Pipeline	PA and NY
LEAP	100%	Yes	1.7	18,000	A 209-mile pipeline delivering Haynesville shale natural gas to markets in the Gulf Coast region	LA
Stonewall	85%	Yes	1.5	—	A 68-mile pipeline delivering Marcellus and Utica shale natural gas to the Columbia Pipeline	WV
Michigan System	100%	Yes	0.8	2,400	A 335-mile pipeline system in northern Michigan	MI

__________________________________

(a)We account for our ownership interest in these joint venture properties as equity method investments in accordance with GAAP. See Note 1, "Description of the Business and Basis of Presentation" to the Consolidated Financial Statements under Part II, Item 8 of this Form 10-K.

(b)The Washington 10 Storage Complex includes 16 Bcf of leased capacity from the Washington 28 Storage Complex, which is held by a joint venture, South Romeo, in which DT Midstream owns a 50% interest.

Business Updates

During the three months ended March 31, 2023, DT Midstream completed the conversion of the Michigan System from gathering to dry gas transmission service and began providing services under a new long-term dry gas transmission contract. For the year ended December 31, 2023, the Michigan System financial results are presented in the Pipeline segment. The prior years' comparative activity was for gathering services and therefore was not revised from presentation in the Gathering segment.

In August 2023, we placed the LEAP phase 1 expansion into service early; and, in January 2024, we placed the LEAP phase 2 expansion into service early. During the year ended December 31, 2023, we continued the LEAP phase 3 expansion, which will increase the capacity to 1.9 Bcf/d and will provide additional access to LNG export terminals. Additionally, during the year ended December 31, 2023, we began construction of a new 1.0 Bcf/d LEAP interconnect with the Gillis Access Project, which will provide access to the Louisiana industrial and LNG corridor and is expected to be placed into service in the second quarter 2024.

10

Capital expenditure investments for these expansion projects are contemplated in our forecasted capital expenditures discussed under Part II, Item 7 Management’s Discussion and Analysis of Financial Condition and Results of Operations—Capital Investments of this Form 10-K.

In May 2023, NEXUS closed on the sale of $750 million of senior unsecured notes with a weighted-average coupon rate of 5.52%. DT Midstream received a distribution from NEXUS of $371 million, net of fees and expenses, which reduced our investment balance under the equity method of accounting. DT Midstream used the proceeds from the distribution to repay borrowings outstanding under our Revolving Credit Facility. See Note 1, "Description of the Business and Basis of Presentation" to the Consolidated Financial Statements under Part II, Item 8 of this Form 10-K.

Gathering Segment

Description

Our Gathering segment includes gathering systems, related treatment plants, and compression and surface facilities. Our subsidiary companies own and operate these types of assets across multiple states.

Our natural gas gathering systems primarily consist of networks of pipelines that collect natural gas from points at or near our customers’ wells for delivery to plants for treating, to gathering pipelines for further gathering, or to pipelines for transportation. Natural gas is moved from the receipt points to the central delivery points on our gathering systems. We provide other ancillary services within our Gathering segment, including compression, dehydration, gas treatment, water impoundment, water transportation, water disposal, and sand mining. Our gathering systems provide a gathering function and are therefore not subject to FERC jurisdiction. Our gathering business has significant infrastructure within our customers' production acreage that is contractually dedicated to DT Midstream to provide gathering services.

Revenues

Our Gathering segment typically has firm revenue contracts that are long-term and structured using fixed demand charges or MVCs with fixed deficiency fee rates. This provides for fixed revenue commitments regardless of actual volumes of natural gas that flow, which leads to more stable operating performance, revenues and cash flows and limits our exposure to natural gas price fluctuations. Additional revenues are generated from proved developed producing reserves connected to our assets, which we refer to as "flowing gas." For the year ended December 31, 2023, 58% and 25% of our Gathering segment revenue was generated under firm revenue contracts and flowing gas, respectively.

For the years ended December 31, 2023 and 2022, average throughput from the Gathering segment was 3.0 Bcf/d and 3.1 Bcf/d, respectively. For the year ended December 31, 2023, revenue from the Gathering segment accounted for approximately 59% of our consolidated revenue.

Competition

Our Gathering operations compete for customers based on reputation, operating reliability and flexibility, price and service offerings, including interconnectivity to producer-desired takeaway options (i.e., processing facilities and pipelines). We mitigate the risk of competition by signing acreage dedications, entering firm revenue contracts, expanding treating capacity and expanding our systems to desirable production basins. Competition customarily is impacted by the level of drilling activity in a particular geographic region. Our primary competitors include other independent midstream companies with gathering operations and producer owned systems.

11

Properties

The following table presents certain information concerning our principal properties included in the Gathering segment:

Property Classification	% Owned	Operator	Capacity (Bcf/d)	Compression Horsepower	Description	Location
Gathering
Susquehanna Gathering	100%	Yes	1.4	97,005	A 198-mile gathering system delivering Marcellus shale natural gas to Bluestone	PA
Blue Union Gathering	100%	Yes	2.6	78,000	A 420-mile gathering system delivering shale natural gas from the Haynesville formation of Louisiana to markets in the Gulf Coast region; ancillary services include water impoundment, water transportation, water disposal, and sand mining	LA and TX
Appalachia Gathering	100%	Yes	1.0	81,305	A 149-mile gathering system delivering Marcellus shale natural gas to the Texas Eastern Pipeline and Stonewall	PA and WV
Tioga Gathering	100%	Yes	0.1	—	A 3-mile gathering system delivering shale natural gas to Eastern Gas Transmission and Storage	PA
Ohio Utica Gathering	100%	Yes	0.1	10,000	A 20-mile gathering system, including compression and dehydration facilities, to deliver Utica shale gas from producer wells to a nearby processing plant	OH

Business Updates

During the year ended December 31, 2023, DT Midstream executed a commercial agreement and completed construction of the trunkline of Ohio Utica Gathering. The initial portions of the system were placed into service in the fourth quarter 2023, and future facilities are expected to be placed into service in the first half of 2024. Additionally, we added 0.4 Bcf/d of new treating capacity to Blue Union Gathering. We also began construction on a new 0.4 Bcf/d supply interconnect with a third-party processing plant to Blue Union Gathering, which is expected to be placed into service in the second quarter 2024. During the year ended December 31, 2023, we also continued the expansion of Appalachia Gathering.

Capital expenditure investments for these expansion projects are contemplated in our forecasted capital expenditures discussed under Part II, Item 7 Management’s Discussion and Analysis of Financial Condition and Results of Operations—Capital Investments of this Form 10-K.

Pipeline and Gathering Rights-of-Way

We obtain satisfactory title to the properties we own and use in our businesses, subject to liens for current taxes, liens incident to minor encumbrances, and easements and restrictions, which do not materially detract from the value of such property, the interests in those properties or the use of such properties in our businesses. Our storage facilities, treating and processing plants, compressor stations, offices and related facilities are located on real property owned or leased by us. In some cases, the real property we lease is on federal, state or local government land.

We typically obtain and maintain rights to construct and operate the pipelines on other people’s land under agreements that are perpetual or provide for renewal rights. Our pipelines are constructed on rights-of-way granted by the current record owners of such property. In many instances, lands over which rights-of-way have been obtained are subject to prior liens that have not been subordinated to the rights-of-way grants. All record owners have joined in the rights-of-way grants and signatures have been obtained, except in unusual cases where title is unclear and requires additional investigation.

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Human Capital Resources

DT Midstream recognizes that being innovative is necessary for our continued growth. We currently employ 402 employees, all of whom are employed full-time, exclusive of our student intern program. All of our employees are in the U.S., with our headquarters in Detroit, Michigan and office locations in Michigan, Pennsylvania, Ohio, West Virginia, Louisiana, and Texas. None of our employees are covered by collective bargaining agreements. We believe that our employee relations are good.

Diversity, Equity, and Inclusion

DT Midstream is committed to building a diverse, empowered, and engaged team that delivers safe and reliable service to our customers. Rather than having DEI solely as a stand-alone program, we integrate these practices into our overall operating model. We review DEI performance in several ways:

•Diversity of interviewees, hires, high potential talent, and leadership promotions;

•Workforce representation of women, minorities, and employees with disabilities based on voluntary self-identification information; and

•Employee engagement, including specific programs focused on a culture of belonging.

Health and Safety

The health and safety of people, including our employees, contractors, customers, and the communities we serve is our top priority. Our safety culture is maintained and strengthened by our safety team, which monitors events, compliance, and training activities.

We monitor our safety performance with leading and lagging indicators, such as safety observations, near-misses and the OSHA recordable injury metrics.

Compensation and Benefits Description

Our human capital resources objectives include recruiting, incentivizing, fostering belonging, and retaining top talent. To achieve this, we offer our employees competitive compensation packages, annual and long-term incentive programs, defined contribution retirement savings plans and an employer contribution match, as well as paid time off, medical, dental, vision and other employee benefits. We review our compensation practices annually to ensure that pay is fair and internally equitable. For additional information on the metrics used in our incentive plans, please see "Annual and Long-Term Incentives" in the Compensation Discussion and Analysis section of our Proxy Statement.

For additional information on our approach to managing our human capital resources, see our 2023 Corporate Sustainability Report on our website. The information in our Corporate Sustainability Report is not incorporated by reference into this Form 10-K.

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Regulatory Environment

Our operations and investments are subject to extensive regulation by United States federal, state and local authorities. In addition, NEXUS and Vector are subject to applicable laws, rules, and regulations in Canada. Failure to comply with federal, state or local regulations may result in the imposition of administrative, civil and/or criminal remedies. We cannot predict whether a regulatory complaint or proceeding will be filed against us in the future or how a regulator may rule on any such complaint. We are not aware of any pending proceedings or complaints at this time.

Additional rules and legislation pertaining to these matters are considered and adopted from time to time. We cannot predict whether any such additional rules or legislation will be promulgated or enacted, or what effect, if any, such changes might have on our operations, however the industry could be required to incur additional capital expenditures and increased costs depending on future legislative and regulatory changes.

Federal Interstate Transportation & Storage Regulation

Many of our business operations are subject to extensive regulation by FERC under the NGA, the NGPA and regulations, rules and policies promulgated under those and other statutes. Specifically, Vector, Millennium, Birdsboro, NEXUS, and the Washington 10 Storage Complex are subject to FERC's NGA authority and provide interstate natural gas transportation or storage services in accordance with their FERC-approved tariffs. Notwithstanding the regulatory discussion below, we believe the regulatory burden does not currently affect our competitive condition.

Generally, FERC’s authority with respect to natural gas extends to:

•rates and charges for interstate pipelines and storage facilities as well as intrastate pipelines and storage facilities providing service in interstate commerce;

•terms and conditions of services and service contracts with customers;

•certification and construction of new interstate pipelines and storage services and facilities and expansion of such facilities;

•abandonment of interstate pipelines and storage services and facilities;

•maintenance of accounts and records;

•relationships between pipelines and certain affiliates;

•depreciation and amortization rates and policies;

•facility replacements and upgrades; and

•acquisitions and dispositions of interstate pipelines and storage facilities.

Under the NGA, rates charged by interstate pipelines must be just, reasonable, and not unduly discriminatory or preferential. The recourse rate is the maximum rate an interstate pipeline may charge for its services under its tariff. It is established through FERC’s cost-of-service ratemaking process. Generally, such recourse rates are based on the cost of providing service, including recovery of and a return on the pipeline’s cost of capital. Key determinants in the ratemaking process include the costs of providing service, the volumes of gas being transported, the rate design, the allocation of costs between services, the capital structure, the depreciation rate and the rate of return a natural gas company is permitted to earn. The maximum applicable recourse rates and terms and conditions for service on an interstate natural gas pipeline are set forth in the pipeline’s FERC-approved tariff unless market-based rates have been approved by FERC. Rate design and the allocation of costs also can affect a pipeline’s profitability. While the ratemaking process establishes the recourse rate, interstate pipelines such as some of our pipelines and storage systems are permitted to charge discounted rates, which are lower than the recourse rates, without further FERC authorization down to the minimum rate set forth in the tariff for the applicable service. If a pipeline company desires to change its recourse rates or terms and conditions of service, including pro forma contracts, then it must propose such changes to FERC in a filing made pursuant to Section 4 of the NGA. Such changes may be challenged by intervening parties, including customers and state agencies, and such proposed changes may ultimately be rejected by FERC. Existing rates or terms and conditions of service and contracts also may be challenged by a complaint filed by interested persons, including customers, state agencies or FERC, under Section 5 of the NGA. Rate increases proposed by a pipeline may

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be allowed to become effective subject to refund and/or a period of suspension, while rates or terms and conditions of service that are the subject of a complaint under Section 5 of the NGA are subject only to prospective change by FERC. Any successful challenge against existing or proposed rates charged for our pipelines and storage services could materially adversely affect our business, financial condition and results of operations.

In addition, our interstate pipelines may also charge negotiated rates that may be above or below the recourse rate or that are subject to a different rate design than the rates specified in our interstate pipeline tariffs, provided that the pipeline has appropriate language in its tariff permitting negotiated rates, that affected customers are willing to agree to such rates rather than recourse rates, and that FERC has approved the negotiated rate agreement. A prerequisite for allowing the negotiated rates is that negotiated rate customers must have had the option to take service under the pipeline’s recourse rates. Some negotiated rate transactions are designed to fix the negotiated rate for the term of the firm transportation agreement and the fixed rate is generally not subject to adjustment for increased or decreased costs occurring during the contract term or for changes in the recourse rate during the contract term.

Interstate transportation and storage service agreements are required to conform, in all material respects, with the form of service agreements set forth in the pipeline’s FERC-approved tariff. Non-conforming agreements must be filed with, and accepted by, FERC. If FERC finds that an agreement is materially non-conforming, in whole or in part, it could reject, or require us to seek modification of, the agreement, or alternatively require us to modify our tariff so that the non-conforming provisions are generally available to all customers or class of customers.

Failure of an interstate pipeline to comply with its obligations under the NGA could result in the imposition of civil and criminal penalties. The EPAct 2005 amended the NGA to give FERC authority to impose civil penalties for violations of the NGA up to $1,544,521 per violation per day (as adjusted for inflation for 2024), and violators may be subject to criminal penalties of up to $1 million per violation per day and five years in prison.

To the extent that an intrastate pipeline system transports natural gas in interstate commerce, the rates, terms and conditions of such interstate transportation service are subject to FERC rules and regulations under Section 311 of the NGPA. Non-compliance with FERC’s rules and regulations established under Section 311 of the NGPA could result in the imposition of civil and criminal penalties. The EPAct 2005 also amended the NGPA to give FERC authority to impose civil penalties for violations of the NGPA up to $1,544,521 per violation per day (as adjusted for inflation for 2024), and violators may be subject to criminal penalties of up to $1 million per violation and five years in prison.

State Intrastate Transportation Regulation

Many state agencies possess the authority to review and authorize natural gas transportation transactions and the construction, acquisition, abandonment and interconnection of physical facilities for intrastate pipelines. State agencies also may regulate transportation rates, service terms, and conditions and contract pricing. Other state regulations may not directly apply to our business but may nonetheless affect the availability of natural gas for purchase, compression and sale. Regulations within a particular state generally will affect all intrastate pipeline operators within the state on a comparable basis; thus, we believe that the regulation of intrastate transportation in any state in which we operate will not disproportionately affect our operations.

Gathering Pipeline Regulation

Section 1(b) of the NGA exempts natural gas gathering facilities from regulation by FERC. We believe that our gathering systems meet the traditional tests FERC has used to establish a pipeline’s status as an exempt gatherer not subject to regulation as a FERC-jurisdictional natural gas company. If FERC were to consider the status of an individual facility and determine that the facility is not a gathering pipeline and the pipeline provides interstate transmission service, the rates for, and terms and conditions of, services provided by such facility would become subject to regulation by FERC under the NGA or the NGPA. Such regulation could decrease revenue, increase operating costs, and, depending upon the facility in question, adversely affect our business, financial condition and results of operations. In addition, if any of our facilities were found to have provided services or otherwise operated in violation of the NGA or NGPA, this could result in the imposition of civil penalties as well as a requirement to disgorge charges collected for such service in excess of the rate established by FERC.

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Our gathering assets may be subject to the rules and regulations of various state utility commissions. State regulation of gathering facilities generally includes various safety, environmental and, in some circumstances, nondiscriminatory take requirements and complaint-based rate regulation. States in which we operate may adopt ratable take and common purchaser statutes, which would require our gathering pipelines to take natural gas without undue discrimination in favor of one producer over another producer or one supply source over another similarly situated supply source. The regulations under these statutes may impose some restrictions on our ability as an owner of gathering facilities to decide with whom we contract to gather natural gas. States in which we operate may also adopt a complaint-based regulation of natural gas gathering activities, which allows natural gas producers and shippers to file complaints with state regulators in an effort to resolve grievances relating to gathering access and rate discrimination.

Our gathering operations could be adversely affected should they be subject in the future to different application of state regulation of rates and services. Our gathering operations also may be, or become, subject to additional safety and operational regulations relating to the design, installation, testing, construction, operation, replacement, and management of gathering facilities.

The EPAct 2005 amended the NGA and NGPA to prohibit fraud and manipulation in natural gas markets, and FERC issued a final rule making it unlawful for any entity, in connection with the purchase or sale of natural gas or transportation service subject to FERC’s jurisdiction, to defraud, make an untrue statement or omit a material fact, or engage in any practice, act or course of business that operates or would operate as a fraud. FERC’s anti-manipulation rules apply to interstate gas pipeline and storage companies and intrastate gas pipeline and storage companies that provide interstate services, such as Section 311 service, as well as otherwise non-jurisdictional entities to the extent the activities are conducted "in connection with" gas sales, purchases or transportation subject to FERC jurisdiction. The anti-manipulation rules apply to intrastate sales and gathering activities only to the extent that there is a "nexus" to FERC-jurisdictional transactions. The EPAct 2005 also provided FERC with the authority to impose civil penalties, which, as adjusted for inflation for 2024, is currently up to a maximum of $1,544,521 per violation per day.

In addition, the CFTC is directed under the Commodities Exchange Act to prevent price manipulations for the commodity and futures markets, including the energy futures markets. Pursuant to the Dodd-Frank Act and other authority, the CFTC has adopted anti-market manipulation regulations that prohibit fraud and price manipulation in the commodity and futures markets. The CFTC also has statutory authority to seek civil penalties of up to the greater of approximately $1.4 million (as adjusted for inflation for 2024) or triple the monetary gain to the violator for violations of the anti-market manipulation sections of the Commodities Exchange Act.

Pipeline Safety and Maintenance Regulation

Our natural gas pipeline assets are subject to the pipeline safety regulations implemented by PHMSA. PHMSA establishes and implements minimum federal safety standards and reporting requirements applicable to gas pipeline facilities, including associated underground natural gas storage. These standards include requirements that apply to the design, installation, testing, construction, operation and maintenance, operator qualification as well as requirements for integrity management on certain pipelines. The integrity management programs apply to gas transmission line segments located in HCAs and require operators to perform periodic risk-based assessments in addition to the minimum required inspections and other preventative and mitigation measures. Notwithstanding the investigatory and preventative maintenance costs incurred in our performance of customary pipeline management activities, we may incur significant additional expenses if anomalous pipeline conditions are discovered or additional preventative and mitigation measures need to be implemented.

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PHMSA often issues new or amended safety standards and reporting requirements for gas pipeline facilities. For example, the "Safety of Gas Transmission Pipelines: MAOP Reconfirmation, Expansion of Assessment Requirements, and Other Related Amendments" rule, which became effective July 1, 2020, requires operators of certain gas transmission pipelines to reconfirm maximum allowable operating pressure and establishes new "Moderate Consequence Areas" for determining regulatory requirements for gas transmission pipeline segments outside of HCAs. The rule also establishes new requirements for conducting baseline assessments and incorporates industry standards and guidelines as well as new requirements for integrity management programs. In August 2022, PHMSA published the "Safety of Gas Transmission Pipelines: Repair Criteria, Integrity Management Improvements, Cathodic Protection, Management of Change, and Other Related Amendments" rule, effective May 24, 2023, which increases gas integrity management and corrosion control requirements and establishes repair criteria for pipelines outside of HCAs, among other things. We have revised our operating and inspection procedures to address these requirements and have implemented these changes as required by the rules. We may incur additional expenses related to compliance activities associated with this rule but do not expect these expenses to be material or our operations to be affected any differently than other similarly situated midstream companies.

In November 2021, PHMSA issued another final rule, entitled "Safety of Gas Gathering Pipelines: Extension of Reporting Requirements, Regulation of Large, High-Pressure Lines, and Other Related Amendments," effective May 16, 2022, that established new safety standards and reporting requirements for certain historically unregulated onshore gas gathering lines. The final rule created a new Type C category of regulated onshore gas gathering lines in Class 1 locations that are subject to PHMSA’s safety standards and reporting requirements and required operators to comply with certain regulatory requirements applicable to newly designated Type C gas gathering lines by May 16, 2023. The final rule also created a new Type R category of reporting-only onshore gas gathering pipelines that are subject to PHMSA’s incident and annual reporting requirements. We have revised our operating and maintenance procedures to address these requirements and have implemented these changes. We may incur additional expenses related to compliance activities but do not expect these expenses to be material or our operations to be affected any differently than similarly situated midstream companies.

Additionally, in April 2022, PHMSA published the "Pipeline Safety: Requirement of Valve Installation and Minimum Rupture Detection Standard" rule, effective October 5, 2022, which required installation of remote control or automatic shut-off valves (or alternative equivalent technology) on certain newly constructed or replaced gas transmission pipelines. The final rule also imposed minimum performance standards for operation of those valves. We may incur additional expenses related to the requirements imposed by this rule, but do not expect these expenses to be material or our operations to be affected any differently than similarly situated midstream companies.

PHMSA is in the process of developing other regulations to address congressional mandates set forth in the 2020 PIPES Act and for other purposes. For example, in May 2023, PHMSA issued a Notice of Proposed Rulemaking, entitled "Gas Pipeline Leak Detection and Repair," that proposes amendments to implement a congressional mandate in the 2020 PIPES Act and impose leak detection and repair criteria applicable to gas pipelines and underground natural gas storage facilities. PHMSA is also in the process of developing inspection and maintenance requirements for idled pipelines and revising regulations applicable to requirements for operators in response to certain class location changes. Congress was due to reauthorize the Pipeline Safety Act in 2023, but that process has been delayed until 2024. Through reauthorization of the Pipeline Safety Act, Congress may pass a bill that mandates other statutory changes or directs PHMSA to develop additional rulemaking. The adoption of these new PHMSA rules could impact our pipeline assets and operations by requiring the installation of new or modified safety controls and the implementation of new capital projects or accelerated maintenance programs, all of which could require us to incur increased operational costs that could be significant. We may also be affected by lost cash flows resulting from shutting down our pipelines during the pendency of any repairs and any testing, maintenance, and repair of pipeline facilities downstream from our own facilities.

Every state in which we operate is certified by PHMSA to regulate the safety of intrastate gas pipeline facilities consistent with the federal safety standards, and some of these states apply additional or more stringent safety standards or reporting requirements to intrastate gas pipeline facilities in their respective jurisdictions. We may incur significant costs and liabilities associated with repair, remediation, preventive or mitigation measures associated with complying with these additional or more stringent state requirements, including for certain gas gathering lines or other pipeline facilities that are not currently subject to PHMSA’s regulations. The costs, if any, for repair, remediation, preventive or mitigating actions that may be determined to be necessary, as well as lost cash flows resulting from shutting down our pipelines during the pendency of such actions, could be material.

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We incur significant costs in complying with U.S. federal and state pipeline safety laws and regulations and otherwise administering our pipeline safety program, but we do not believe such costs of compliance will materially adversely affect our business, financial condition and results of operations. While we cannot predict the outcome of pending or future legislative or regulatory initiatives, we anticipate that pipeline safety requirements will continue to become more stringent over time. As a result, we may incur significant additional costs to comply with the new pipeline safety regulations, the pending pipeline safety regulations, and any new pipeline safety laws and regulations associated with our pipeline facilities, which could materially adversely affect our business, financial condition and results of operations.

Should we fail to comply with PHMSA regulations, we could be subject to penalties and fines. PHMSA has the statutory authority to impose civil penalties for pipeline safety violations up to a maximum of approximately $266,000 per day for each violation and approximately $2.66 million for a related series of violations (as adjusted for inflation in 2024). This maximum penalty authority established by statute will continue to be adjusted periodically to account for inflation.

We believe that our operations are in substantial compliance with all existing U.S. federal, state and local pipeline safety laws and regulations. However, the adoption of new laws and regulations, such as those proposed by PHMSA, could result in significant added costs or delays in service or the termination of projects, which could have a material adverse effect on us in the future.

In the course of operating our pipeline facilities, we may experience a leak or a rupture on our system. These leaks and ruptures may cause explosions, fire, damage to the environment, damage to property, personal injury and/or death. Depending on the circumstances of the leak or rupture, PHMSA or the state agent may require that certain pipeline assets remain out of service and/or operate at a significantly reduced operating pressure until certain corrective measures are performed and a return to normal operation is approved by PHMSA or the state agent. In addition to any regulatory fines or corrective measures, we may be sued for any damages. Depending upon the facts and circumstances of a particular incident, state and federal regulatory authorities may also seek civil and/or criminal fines and penalties.

Natural Gas Storage Regulation

We operate natural gas storage facilities in Michigan as interstate facilities regulated by PHMSA and provide interstate storage and related services pursuant to a FERC-approved tariff. As such, our natural gas storage facilities are required to meet the federal safety standards as required by 49 C.F.R. §192.12, Underground natural gas storage facilities.

We believe that our operations are in substantial compliance with 49 C.F.R. §192.12, Underground natural gas storage facilities. However, the adoption of new laws and regulations could result in significant added costs or delays in service or the termination of projects, which could have a material adverse effect on us in the future.

Environmental and Occupational Health and Safety Regulations

General. Our operations are subject to U.S. federal, state and local environmental laws and regulations relating to air quality, water quality, waste management, wildlife conservation, natural resources and worker health and safety. These laws and regulations require the acquisition of and compliance with permits and the installation of pollution control equipment or replacement of aging pipelines and other facilities; limit or prohibit construction activities in sensitive areas such as wetlands, wilderness or areas that provide habitat for endangered or threatened species; require investigatory and remedial actions to mitigate or eliminate pollution conditions caused by our operations or attributable to former operations; and apply health and safety criteria addressing worker protections.

In addition, our operations and construction activities are subject to county and local ordinances that restrict the time, place or manner in which those activities may be conducted to reduce or mitigate nuisance-type conditions, such as, for example, excessive levels of dust or noise or increased traffic congestion.

Failure to comply with these laws and regulations may result in the assessment of administrative, civil and criminal penalties; the occurrence of delays or cancellations in the permitting or performance or expansion of projects; the denial or termination of project authorizations; the imposition of restrictions or limitations on project authorizations; the addition or removal of conditions or terms in project authorizations; the issuance of injunctions limiting or preventing some or all of our operations in a particular area; and, under certain environmental laws, citizen suits, in which individuals and environmental organizations act in the place of the government and sue operators for alleged violations of environmental law.

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We have implemented programs and policies designed to keep our pipelines and other facilities in compliance with existing environmental laws and regulations, and we incur significant costs in connection with compliance. We also incur, and expect to continue to incur, additional costs with respect to construction as existing environmental laws and regulations impact the cost of planning, design, permitting, installation and start-up, and with respect to capital expenditures for pollution control equipment that is necessary to achieve emission and discharge standards included in our permits.

Moreover, we incur, and expect to continue to incur, additional costs in connection with spill response. Spills can result in significant costs associated with the investigation and remediation of contaminated facilities, and with injury and damage claims arising from releases and related contamination.

The timing and complete extent of future expenditures related to environmental matters is difficult to estimate accurately because, among other things, interpretation and enforcement of environmental laws and regulations are constantly changing, our pollution control and clean-up cost estimates may change, especially when our current estimates are based on preliminary site investigations or agreements, and new contaminated facilities and sites may be found, or what we know about existing sites and facilities could change.

We do not believe that our compliance with environmental legal requirements will materially adversely affect our business, financial condition and results of operations. Nonetheless, the trend in environmental regulation is to place more restrictions and limitations on activities that may affect the environment. Thus, there can be no assurance as to the amount or timing of future expenditures for environmental compliance or remediation, and actual future expenditures may be significantly in excess of the amounts we currently anticipate. For example, we try to anticipate future regulatory requirements that might be imposed and plan accordingly to remain in compliance with changing environmental laws and regulations and to minimize the costs of such compliance. While we believe that we are in substantial compliance with existing environmental laws and regulations, additional, unplanned measures and expenditures may be required to maintain compliance in the future.

The following is a discussion of several of the principal environmental laws and regulations, as amended from time to time, which relate to our business.

Hazardous Substances and Waste. CERCLA and comparable state laws impose liability, without regard to fault or the legality of the original conduct, on current and prior owners or operators of the sites where a release of hazardous substances occurred or extends and companies that transported, disposed or arranged for the transportation or disposal of the hazardous substances released. Under CERCLA, these "responsible parties" may be subject to strict and joint and several liability for the costs of cleaning up the hazardous substances that have been released into the environment, for damages to natural resources, and for the costs of certain health studies. CERCLA also authorizes the EPA and, in some instances, third parties to act in response to threats to the public health or the environment and to seek to recover from the responsible parties the costs they incur. It is not uncommon for neighboring landowners and other third parties to file claims for personal injury and property damage allegedly caused by hazardous substances or other pollutants released into the environment. We generate materials in the course of our ordinary operations that are regulated as "hazardous substances" under CERCLA or similar state laws and, as a result, may be jointly and severally liable under CERCLA, or such laws, for all or part of the costs required to clean up sites at which these hazardous substances have been released into the environment.

In the ordinary course of our operations, we generate solid wastes and in some instances hazardous wastes, which are subject to the requirements of RCRA and comparable state statutes. While RCRA regulates both solid and hazardous wastes, it imposes strict requirements on the generation, storage, treatment, transportation and disposal of hazardous wastes. While certain petroleum production wastes are excluded from RCRA’s hazardous waste regulations, it is possible that these wastes will in the future be designated as "hazardous wastes" and be subject to more rigorous and costly disposal requirements, which could have a material adverse effect on our maintenance capital expenditures and operating expenses.

We own, lease or operate properties where hydrocarbons are being or have been handled for many years, by us and by former owners or operators, and we send hydrocarbons and wastes to third-party sites for treatment or disposal. Under CERCLA, RCRA and analogous state laws, we could be required to remove or remediate previously disposed or released wastes (including wastes disposed of or released by prior owners or operators), to clean up contaminated property (including contaminated groundwater) or to perform remedial operations to prevent future contamination, as well as to reimburse for or contribute to the remediation of third-party disposal and treatment sites. We are not currently aware of any facts, events or conditions relating to the application of such requirements that could reasonably materially adversely affect our business, financial condition and results of operations.

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Air Emissions. The U.S. federal Clean Air Act and comparable state laws and regulations restrict the emission of air pollutants from various industrial sources, including our compressor stations, and also impose various pre-construction, operational, monitoring and reporting requirements. Such laws and regulations may require that we obtain pre-approval for the construction or modification of certain projects or facilities, obtain and strictly comply with air permits containing various emissions and operational limitations, and utilize specific emission control technologies to limit emissions. Our failure to comply with these requirements could subject us to monetary penalties, injunctions, conditions or restrictions on operations and, potentially, criminal enforcement actions. We may be required to incur certain capital expenditures in the future for air pollution control equipment in connection with obtaining and maintaining permits and approvals for air emissions. Compliance with these requirements may require modifications to certain of our operations, including the installation of new equipment to control emissions from our compressors that could result in significant costs, increased capital expenditures and operating costs, and could adversely affect our business. Further, the permitting, regulatory compliance and reporting programs, taken as a whole, increase the costs and complexity of oil and gas operations with potential to adversely affect the cost of doing business for our customers resulting in reduced demand for our gas processing and transportation services. Although we can give no assurances, we believe such requirements will not materially adversely affect our business, financial condition and results of operations, and the requirements are not expected to be more burdensome to us than to any similarly situated midstream company.

Climate Change. Legislative and regulatory measures to address climate change and GHG emissions are in various phases of discussion or implementation. The EPA regulates GHG emissions from new and modified facilities that are potential major sources of criteria pollutants under the Clean Air Act’s Prevention of Significant Deterioration and Title V programs and has adopted regulations that require, among other things, preconstruction and operating permits for certain large stationary sources and the monitoring and annual reporting of GHGs from certain onshore oil and natural gas production sources. On December 2, 2023, the EPA published a final rule to regulate GHG emissions (in the form of methane limitations, as well as design, equipment, work practice, and operational standards) and volatile organic compound emissions from crude oil and natural gas production, processing, transmission, and storage. The final rule includes standards of performance for new, modified, and reconstructed sources and emission guidelines for existing sources. Additionally, the U.S. Congress, along with U.S. federal and state agencies, has considered measures to reduce the emissions of GHGs. On August 16, 2022, the U.S. Congress enacted the Inflation Reduction Act. Beginning in calendar year 2024, the statute authorizes the EPA to impose and collect a charge on methane emissions that exceed certain thresholds from offshore and onshore petroleum and natural gas production, onshore natural gas processing, onshore natural gas transmission compression, certain kinds of natural gas and LNG storage, and onshore petroleum and natural gas gathering and boosting. Legislation or regulation that levies a charge related to our GHG emissions or that restricts GHG emissions could increase our cost of environmental compliance by requiring us to install new equipment to reduce emissions from larger facilities; purchase emission allowances; administer and manage a GHG emissions program; and otherwise increase the costs of our operations, including costs to operate and maintain our facilities.

FERC does not directly regulate GHG emissions. However, on February 17, 2022, FERC issued two policy statements providing guidance on its consideration of GHG emissions and other factors when reviewing proposed projects under the NGA. These policy statements have been the subject of public comments and remain under consideration by FERC. If the policy statements come into effect as written, GHG emissions and climate-related considerations could play a more significant role in FERC’s analysis of projects under its jurisdiction, including projects that do or would supply gas to the Company’s facilities.

The effect of climate change legislation or regulation on our business is currently uncertain. If we incur additional costs to comply with such legislation or regulations, we may not be able to pass on the higher costs to our customers or recover all the costs related to complying with such requirements, and any such recovery may depend on events beyond our control, including the outcome of future rate proceedings before FERC or state regulatory agencies and the provisions of any final legislation or implementing regulations. Our future business, financial condition and results of operations could be adversely affected if such costs are not recovered through regulated rates or otherwise passed on to our customers. Additionally, our customers or suppliers may also be affected by legislation or regulation, which may adversely impact their drilling schedules and production volumes and reduce the volumes delivered to us and demand for our services.

Climate change and GHG legislation or regulation could also delay or otherwise negatively affect efforts to obtain permits and other regulatory approvals with regard to existing and new facilities or impose additional monitoring and reporting requirements. The effect of any new legislative or regulatory measures on us will depend on the particular provisions that are ultimately adopted.

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Water Discharges. The U.S. federal Clean Water Act and analogous state laws impose restrictions and strict controls regarding the discharge of pollutants or dredged and fill material into state waters as well as WOTUS, including adjacent wetlands. The discharge of pollutants into regulated waters is prohibited, except in accordance with the terms of permits issued by the EPA, the U.S. Army Corps of Engineers, and/or an analogous state agency. The definition of WOTUS has been the subject of multiple regulatory interpretations and judicial decisions in recent years. In May 2023, the U.S. Supreme Court issued its decision in Sackett v. Environmental Protection Agency, which adopted a narrower test for wetlands covered under the Clean Water Act; and, in August 2023, the EPA and the U.S. Army Corps of Engineers promulgated final rule amendments for a new WOTUS definition that conformed to the Supreme Court's Sackett decision. Despite these recent changes, the definition remains subject to litigation, with opponents arguing it is not sufficiently narrow. While recent changes to the definition may ease permitting in certain circumstances, continued controversy over the WOTUS definition may result in costs and delays with respect to obtaining permits for activities in jurisdictional waters, including wetlands.

Spill prevention, control and countermeasure requirements of U.S. federal laws require appropriate containment berms and similar structures to help prevent the contamination of regulated waters in the event of a hydrocarbon spill, rupture or leak. In addition, the Clean Water Act and analogous state laws require individual permits or coverage under general permits for discharges of storm water runoff from certain types of facilities. These permits may require us to monitor and sample the storm water runoff from some of our facilities. The Clean Water Act and regulations implemented thereunder also prohibit discharges of dredged and fill material in wetlands and other waters of the U.S. unless authorized by an appropriately issued permit. Some states also maintain groundwater protection programs that require permits for discharges or operations that may impact groundwater conditions. U.S. federal and state regulatory agencies can impose administrative, civil and criminal penalties for non-compliance with discharge permits or other requirements of the Clean Water Act and analogous state laws. We believe that compliance with existing permits and foreseeable new permit requirements will not materially adversely affect our business, financial condition and results of operations.

National Environmental Policy Act. The construction of interstate natural gas transportation pipelines pursuant to the NGA requires authorization from FERC. Certain FERC actions relating to such pipelines are subject to NEPA, which requires U.S. federal agencies, such as FERC, to evaluate major U.S. federal actions having the potential to significantly affect the environment. During such evaluations, an agency will prepare a detailed Environmental Impact Statement unless it has found on the basis of an environmental assessment that no significant effect is likely. Such NEPA analyses have the potential to significantly delay or limit, and significantly increase the cost of, development of midstream infrastructure. On April 20, 2022, the White House Council on Environmental Quality (the "Council") published a final rule amending its existing regulations governing the implementation of NEPA by federal agencies. The amendments principally address definitions relating to environmental effects and alternatives that require agency consideration. On January 9, 2023, the Council published interim guidance, effective immediately, that addresses how federal agencies should consider GHG emissions and climate change when conducting reviews under NEPA. The interim guidance recommends that agencies quantify GHG emissions and then use an algorithm to translate the emissions into an expected social cost. On June 3, 2023, the federal government enacted the Fiscal Responsibility Act of 2023, which includes amendments to NEPA concerning the scope and scientific basis of impact analysis, the duration of impact reviews, and other matters. On July 31, 2023, the Council published a second proposed rule, further amending its NEPA implementing regulations. This regulatory proposal addresses a wide range of topics, including the implementation of the statutory amendments passed in 2023 and the replacement of numerous regulatory measures adopted during the prior presidential administration. The Council’s rulemaking and policy efforts, including the 2023 proposed rule if finalized, could permit or require agencies to undertake more searching inquiries during their NEPA reviews of new projects that require federal permits.

Hydraulic Fracturing. We do not operate any assets that conduct hydraulic fracturing. However, our customers’ natural gas production is developed from unconventional sources that require hydraulic fracturing as part of the completion process. Hydraulic fracturing involves the injection of water, sand and chemicals under pressure into the formation to fracture the surrounding rock and stimulate crude oil and natural gas production. The process is regulated by state agencies, typically the state’s commission that regulates oil and gas production. A number of U.S. federal agencies, including the EPA and the U.S. Department of Energy, have analyzed, or have been requested to review, a variety of environmental issues associated with hydraulic fracturing. For example, the EPA finalized regulations under the Clean Water Act in June 2016 prohibiting wastewater discharges from hydraulic fracturing and certain other natural gas operations to publicly owned wastewater treatment plants. In addition, some states have adopted, and other states are considering adopting, regulations that could impose more stringent disclosure and/or well construction requirements on hydraulic fracturing operations.

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Certain state and U.S. federal regulatory agencies are also focused on a possible connection between hydraulic fracturing-related activities, including wastewater disposal, and the increased occurrence of seismic activity. When caused by human activity, such events are called induced seismicity. In a few instances, operators of injection disposal wells in the vicinity of seismic events have been ordered by regulatory agencies to reduce injection volumes or suspend operations. Additionally, some state regulatory agencies have modified their regulations or issued orders to restrict disposal wells or enhance well construction and monitoring requirements.

These developments could result in additional regulation and restrictions on the use of injection disposal wells and hydraulic fracturing. The adoption of new laws, regulations or ordinances at the U.S. federal, state or local levels imposing more stringent restrictions on hydraulic fracturing or wastewater disposal could make it more difficult for our customers to complete natural gas wells, increase customers’ costs of compliance and doing business, and otherwise adversely affect the hydraulic fracturing services they perform, which could negatively impact demand for our services.

Endangered Species Act. The ESA restricts activities that may adversely affect endangered and threatened species or their habitats and it makes illegal the "take" of any protected species. U.S. federal agencies are required to ensure that any action authorized, funded or carried out by them is not likely to jeopardize the continued existence of listed species or modify their critical habitat. While some of our facilities are located in areas that are designated as habitats for endangered or threatened species, we have not incurred any material costs to comply or restrictions on our operations and we believe that we are in substantial compliance with the ESA. The designation of previously unprotected species as being endangered or threatened, or the designation of previously unprotected areas as a critical habitat for such species, could cause us to incur additional costs, result in delays in construction of pipelines and facilities, cause us to become subject to operating restrictions in areas where the species are known to exist or could result in limitations on our customers’ exploration and production activities that could have an adverse impact on demand for our services. For example, the U.S. Fish and Wildlife Service has received hundreds of petitions to consider listing additional species as endangered or threatened and is being regularly sued or threatened with lawsuits to address these petitions. Compliance with all applicable laws providing special protection for designated species has not posed a material cost on our business and operations to date.

Employee Health and Safety. We are subject to a number of U.S. federal and state laws and regulations, including OSHA, and comparable state statutes, whose purpose is to protect the health and safety of workers. In addition, the OSHA hazard communication standard, the EPA community "right-to-know" regulations, and comparable state laws and regulations require that information be maintained concerning hazardous materials used or produced in our operations and that this information be provided to employees, state and local government authorities and citizens. We are also subject to OSHA Process Safety Management regulations, which are designed to prevent or minimize the consequences of catastrophic releases of toxic, reactive, flammable or explosive chemicals. We are also subject to the EPA Risk Management Program, which addresses the prevention of chemical accidents and preparedness for emergencies. In August 2022, the EPA issued a proposed rule to amend the Risk Management Program's implementing regulations. The final rule, if issued, may impose new requirements that increase our cost of compliance or require changes to our internal programs and policies to comply with the Risk Management Program.

We believe that we are in substantial compliance with all applicable laws and regulations relating to worker health and safety. Historically, worker safety and health compliance costs have not materially adversely affected our business, financial condition and results of operations; however, there can be no assurance that such costs will not be material in the future or that such future compliance will not materially adversely affect our business, financial condition and results of operations. While we may increase future expenditures to comply with higher industry and regulatory safety standards, such increases in costs of compliance, and the extent to which they might be recoverable through our rates, cannot be estimated at this time.

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Item 1A. Risk Factors

You should carefully consider the following risks and other information in this Form 10-K. Any of the following risks and uncertainties could materially adversely affect our business, financial condition and results of operations.

Risks Relating to Our Business

Operational Risks

Any significant decrease in demand or in production of natural gas in our asset footprint could materially adversely affect our business, financial condition and results of operations.

Our business is dependent on the continued availability of and demand for natural gas in our areas of operation, which include the Midwestern U.S., Eastern Canada, Northeastern U.S. and Gulf Coast regions. A reduction in the natural gas volumes supplied by producers could result in reduced throughput on our systems and corresponding service revenues. The primary factors affecting our ability to obtain sources of natural gas include (i) the level of successful drilling activity near our systems, (ii) our ability to compete for volumes from successful new wells and (iii) our ability to compete successfully for volumes from sources connected to other pipelines.

To maintain or increase the contracted capacity or the volume of natural gas gathered, transported and stored on our systems and cash flows associated therewith, our customers must continually obtain adequate supplies of natural gas. If new supplies of natural gas are not obtained to replace the natural decline in volumes from existing supply basins in our areas of operation, or if natural gas supplies are diverted to serve other markets, the overall volume of natural gas gathered, transported and stored on our systems would decline, which could materially adversely affect our business, financial condition and results of operations.

We have several customers with one being a key customer, Southwestern Energy. The loss of, or reduction in volumes from, this customer could result in a decline in demand for our services and materially adversely affect our business, financial condition and results of operations.

Southwestern Energy accounted for approximately 60% of our operating revenues for the year ended December 31, 2023. Our operating revenues do not include revenues of unconsolidated joint ventures accounted for as equity method investments. The loss of all or even a portion of the contracted volumes of this or other customers, the failure to extend or replace customer contracts, or the extension or replacement of customer contracts on less favorable terms, as a result of competition, creditworthiness, reduced natural gas production or otherwise, could materially adversely affect our business, financial condition and results of operations.

We may be unable to renew or replace expiring contracts at favorable rates or on a long-term basis.

One of our exposures to market risk occurs when our existing contracts, including both our contracts with customers and our contracts with suppliers and other counterparties, expire and are subject to renegotiation and renewal. The majority of our customer contracts are firm service revenue contracts. Firm service revenue contracts are typically long-term and structured using fixed demand charges or MVCs with fixed deficiency fee rates. This provides for fixed revenue commitments regardless of actual volumes of natural gas that flow, which leads to more stable operating performance, revenues and cash flows and limits our exposure to natural gas price fluctuations. We may be unable to renew or replace these contracts at expiration, and our efforts to negotiate for similar fixed revenue commitments may be unsuccessful, which could cause our exposure to natural gas price risk to change or adversely affect the stability of our cash flows.

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If third-party pipelines and other facilities interconnected to our assets become unavailable to transport natural gas, it could materially adversely affect our business, financial condition and results of operations.

We depend upon third-party pipelines and other facilities that provide receipt and delivery options to and from our assets. For example, our pipelines interconnect with multiple interstate pipelines in the Midwestern U.S., Eastern Canada, Northeastern U.S. and Gulf Coast regions and a significant number of intrastate pipelines. Because we do not own these third-party pipelines or facilities, their continuing operation is not within our control. If these pipeline connections become unavailable for current or future volumes of natural gas due to testing, turnarounds, repairs, maintenance, damage, reduced operating pressure, lack of capacity, regulatory requirements or any other reason, our ability to operate efficiently and continue shipping natural gas to end markets could be restricted, thereby reducing our revenues. Any temporary or permanent interruption at any key pipeline interconnect or other downstream facility utilized to move our customers’ product to their end destination that causes a material reduction in volumes transported on our pipelines could materially adversely affect our business, financial condition and results of operations.

In addition, the rates charged by treating plants, pipelines and other facilities interconnected to our assets affect the utilization and value of our services. Significant changes in the rates charged by these third parties, or the rates charged by the third parties that own "downstream" assets required to move commodities to their final destinations, could materially adversely affect our business, financial condition and results of operations.

Our operations are subject to operational hazards, unforeseen interruptions and damage caused by third parties and natural events. If a significant accident or event occurs that results in a business interruption or damage to our pipelines, storage and gathering systems, the facilities of our customers or other interconnected pipelines and facilities, it could materially adversely affect our business, financial condition and results of operations.

Our operations, our customers’ operations and other interconnected pipelines and facilities are subject to many operational hazards, including (i) damage to pipelines, facilities, equipment, environmental controls and surrounding properties, including damage resulting from landslide and ground movement slippage; (ii) leaks, migrations or losses of natural gas and other hydrocarbons, water, brine, other fluids and hazardous chemicals that we handle in our treating and other operations; (iii) inadvertent damage from third parties, including from construction, farm and utility equipment; (iv) uncontrolled releases of natural gas and other hydrocarbons; (v) ruptures, fires and explosions; (vi) product and waste spills and unauthorized discharges of products, wastes and other pollutants; (vii) pipeline freeze-offs due to cold weather; (viii) operator error; (ix) aging infrastructure, mechanical or other performance problems; (x) damages to and loss of availability of interconnecting third-party pipelines, railroads and terminals; (xi) disruption or failure of information technology systems and network infrastructure; (xii) floods; (xiii) severe weather; (xiv) lightning and (xv) terrorism.

These risks could result in loss of human life, personal injuries, significant property damage, environmental pollution, impairment of our operations, regulatory investigations and penalties and substantial financial losses. The location of certain segments of our systems in or near populated areas, including residential areas, commercial business centers and industrial sites, could increase the damages resulting from these risks. In spite of any precautions taken, the occurrence of an event such as those described above that is not fully covered by insurance could materially adversely affect our business, financial condition and results of operations. In addition, these risks could materially impact or completely prevent our customers’ from performing their respective obligations under our commercial agreements, which, in turn, could materially adversely affect our business, financial condition and results of operations.

Expansion projects or acquisitions that are expected to be accretive may nevertheless reduce our cash from operations and could materially adversely affect our business, financial condition and results of operations.

Even if we complete expansion projects or acquisitions that we believe will be accretive, these expansion projects or acquisitions may nevertheless reduce our cash from operations and could materially adversely affect our business, financial condition and results of operations. Any expansion project or acquisition involves potential risks, including, among other things: (i) service interruptions or increased downtime associated with our projects; (ii) a decrease in our liquidity; (iii) an inability to complete expansion projects or acquisitions on schedule or within the budgeted cost; (iv) the assumption of unknown liabilities when making acquisitions for which we are not indemnified or for which our indemnity is inadequate; (v) the diversion of our management’s attention from other business concerns; (vi) mistaken assumptions about the overall costs of equity or debt, demand for our services, supply volumes, reserves, revenues and costs, synergies and potential growth; (vii) an inability to secure adequate customer commitments to use the expanded or acquired systems or facilities; (viii) an inability to successfully integrate the businesses we build or acquire; (ix) an inability to receive cash flows from a newly built asset until it is operational; and (x) unforeseen difficulties operating in new service areas or new geographic areas.

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We have entered into joint ventures, and may in the future enter into additional or modify existing joint ventures, which might restrict our operational and corporate flexibility. In addition, these joint ventures are subject to most of the same operational risks to which we are subject.

We conduct a meaningful portion of our operations through joint ventures with third parties, including through our interests in Vector, Millennium, NEXUS and Generation, and we may enter into additional joint venture arrangements in the future. Generally, we do not operate the assets owned by these joint ventures and our control over their operations is limited by the applicable governing provisions of such joint venture agreements. In certain cases, we could have limited ability to influence or control certain day-to-day activities affecting the operations, the amount of capital expenditures that we may be required to fund with respect to these operations and the amount of cash we will receive from the joint venture. We also could be dependent on our joint venture partners to fund their required share of capital expenditures and be exposed to third party credit risk through our contractual arrangements with our joint venture partners. Additionally, we may be subject to restrictions or limitations on our ability to sell or transfer our interests in the jointly owned assets, and we may be required to offer business opportunities to the joint venture, or rights of participation to other joint venture partners or participants in certain areas of mutual interest.

In addition, our joint venture arrangements may involve risks not otherwise present when operating assets directly. We may incur liabilities as a result of an action taken by our joint venture partners and may be required to devote significant management time to the requirements of and matters relating to the joint ventures. Our joint venture partners may be in a position to take actions contrary to our instructions or requests, or contrary to our policies or objectives. Any disputes between us and our joint venture partners may result in delays, litigation or operational impasses.

The risks described above or the failure to continue our joint ventures or to resolve disagreements with our joint venture partners could adversely affect our ability to conduct business that is the subject of a joint venture, which could in turn materially adversely affect our business, financial condition and results of operations. In addition, these joint ventures are subject to most of the same operational risks to which we are subject and the impact of any of these operational risks on our joint ventures’ respective business, financial condition or results of operations could in turn materially adversely affect our business, financial condition and results of operations.

We do not own the majority of the land on which our assets are located, which could disrupt our current and future operations.

We do not own the majority of the land on which our assets are located, and we are therefore subject to the possibility of more onerous terms and increased costs or delays to retain necessary land use rights required to conduct our operations if we do not have valid rights-of-way, if such rights-of-way lapse or terminate or if our facilities are not properly located within the boundaries of such rights-of-way. If we were to be unsuccessful in negotiating or renegotiating rights-of-way, we might have to institute condemnation proceedings on our FERC regulated assets or relocate our facilities for non-regulated assets. Restrictions on our ability to use our rights-of-way, through our inability to renew right-of-way contracts or otherwise, or a relocation could materially adversely affect our business, financial condition and results of operations. Additionally, even when we own an interest in the land on which our assets are located, agreements with correlative rights owners may require us to relocate pipelines and facilities, shut in storage facilities to facilitate the development of the correlative rights owners’ estate or pay the correlative rights owners the lost value of their estate if they are not willing to accommodate development.

We face and will continue to face opposition to the development or operation of our assets from various groups.

We face and will continue to face opposition to the development or operation of our assets from environmental groups, landowners, local and national groups, activists and other advocates. Such opposition could take many forms, including organized protests, attempts to block, vandalize or sabotage our development or operations, intervention in regulatory or administrative proceedings involving our assets directly or indirectly, lawsuits, legislation or other actions designed to prevent, disrupt or delay the development or operation of our assets and business. Any such event that delays or interrupts the revenues generated, or expected to be generated, by our operations, or which causes us to make significant expenditures not covered by insurance, could materially adversely affect our business, financial condition and results of operations.

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The expansion of our existing assets and construction of new assets is subject to economic, market, regulatory, environmental, political, and legal risks, which could materially adversely affect our business, financial condition and results of operations. If we are unable to complete expansion projects, our future growth may be limited.

We may be unable to complete successful, accretive expansion projects for many reasons, including economic and market risks such as an inability to identify attractive expansion projects; an inability to successfully integrate the infrastructure we build; an inability to raise financing for expansion projects on economically acceptable terms; and because some of our competitors may be better positioned to compete for certain expansion projects that we believe would be accretive. In addition, the construction of additions or modifications to our existing energy infrastructure assets, and the construction of other new energy infrastructure assets, involve numerous regulatory, environmental, political and legal uncertainties beyond our control. The development and construction of pipeline and gathering infrastructure and storage facilities expose us to construction risks such as: (i) the failure of third parties to meet their contractual requirements; (ii) environmental hazards; (iii) adverse weather conditions; (iv) the performance of third-party contractors; and (v) the lack of available skilled labor, equipment and materials.

Certain of our internal growth projects may require regulatory approval from U.S. federal and state authorities and Canadian authorities prior to construction. The approval process for storage and transportation projects located in the Northeast has become increasingly challenging, due in part to state and local concerns related to unregulated exploration and production and gathering activities in new production areas, including the Marcellus/Utica formations. In addition, FERC is considering modifying its policy governing the issuance of interstate natural gas pipeline authorizations, in part to address concerns about climate change. Policy and regulatory changes relating to the implementation of NEPA may increase scrutiny of environmental impacts associated with our projects. Authorizations required for our projects under existing or future agency policies may not be granted or, if granted, such authorization may include burdensome or expensive conditions.

Failure to retain and attract key executives and other skilled professional and technical employees could materially adversely affect our business, financial condition and results of operations.

Our business is dependent on our ability to attract, retain and motivate employees. We rely on our management team, which has significant experience in the midstream industry, to manage our day-to-day affairs and establish and execute our strategic and operational plans. The loss of any of our key executives or the failure to fill new positions created by expansion, turnover or retirement could adversely affect our ability to implement our business strategy. In addition, our operations require engineers, operational and field technicians and other highly skilled employees. The competition for talent has become increasingly intense, and we may experience increased employee turnover, increased wage inflation or an impediment of our ability to execute certain key strategic initiatives due to a tightening labor market and skilled labor shortages. Failure to successfully attract and retain an appropriately qualified workforce could materially adversely affect our business, financial condition and results of operations.

The lack of diversification of our assets and geographic locations could materially adversely affect our business, financial condition and results of operations.

We rely primarily on revenues generated from our pipeline, storage and gathering systems, substantially all of which are located in the Midwestern U.S., Eastern Canada, Northeastern U.S. and Gulf Coast regions. Due to our lack of diversification in assets and geographic location, an adverse development in these businesses or our areas of operations, including adverse developments due to catastrophic events, weather, regulatory action, state and local political activities, availability of equipment and personnel, local prices, producer liquidity and decreases in demand for natural gas could have a more significant impact on our business, financial condition and results of operations than if we maintained more diverse assets and locations.

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Liquidity, Credit and Financial Risks

We may not have access to additional financing sources on favorable terms, or at all, which could materially adversely affect our business, financial condition and results of operations, and independent third parties determine our credit ratings outside of our control.

The cost of capital for our business depends, in part, on our credit ratings; general market conditions; the market’s perception of our business risk and growth potential; our current debt levels; interest rate changes; our current and expected future earnings; our cash flow; and the market price per share of our common stock. In part based on our current credit ratings, potential lenders may be unwilling or unable to provide us with financing that is attractive to us, may increase collateral requirements or may charge us prohibitively high fees in order to obtain financing. Consequently, our ability to access the credit market in order to attract financing on reasonable terms may be adversely affected. Depending on market conditions at the relevant time, we may have to rely more heavily on additional equity financings or on less efficient forms of debt financing that require a larger portion of our cash flow from operations, thereby reducing funds available for our operations, future business opportunities and other purposes. We may not have access to such equity or debt capital on favorable terms, at the desired times, or at all. In addition, declines in our credit ratings may influence our suppliers’ and customers’ willingness to transact with us, and we may be required to make prepayments or provide security to satisfy credit concerns.

Fluctuations in energy prices could materially adversely affect our business, financial condition and results of operations.

Fluctuations in energy prices can greatly affect the development of new natural gas reserves. Drilling and production activity generally decreases as commodity prices decrease. In general terms, the prices of natural gas, oil and other hydrocarbon products fluctuate in response to changes in supply and demand, market uncertainty and a variety of additional factors that are beyond our control. These factors include (i) worldwide political and economic conditions; (ii) weather conditions and seasonal trends; (iii) the levels of domestic production and consumer demand; (iv) the availability of imported and exported natural gas, LNG and other commodities; (v) the ability to export LNG; (vi) the availability of transportation systems with adequate capacity; (vii) the volatility and uncertainty of regional pricing differentials and premiums; (viii) the price and availability of alternative fuels; (ix) the effect of energy conservation measures; and (x) governmental regulation and taxation.

Prices of natural gas have been historically volatile, and we expect this volatility to continue. Consequently, even if new natural gas reserves are discovered in areas served by our assets, producers may choose not to develop those reserves. Sustained declines in natural gas prices could have a negative impact on exploration, development and production activity and could lead to a material decrease in such activity, which could result in reduced throughput on our systems and materially adversely affect our business, financial condition and results of operations. See also "—Any significant decrease in demand or in production of natural gas in our asset footprint could materially adversely affect our business, financial condition and results of operations".

We are exposed to our customers’ credit risk and our credit risk management and contractual terms may be inadequate to protect against such risk.

We are subject to the risk of loss resulting from nonpayment or nonperformance by our customers in the ordinary course of our business. While some of our customers are rated investment grade, others have sub-investment grade ratings (including our key customer, Southwestern Energy). These customers are otherwise considered creditworthy or are required to make prepayments or provide security to satisfy credit concerns. However, our credit procedures and policies may not be adequate to fully eliminate customer credit risk. If we fail to adequately assess the creditworthiness of existing or future customers, the unanticipated deterioration in their creditworthiness and any resulting increase in nonpayment or nonperformance by them could materially adversely affect our business, financial condition and results of operations.

Our existing and future level of debt may limit our flexibility to obtain additional financing and to pursue other business opportunities.

As of December 31, 2023, we had outstanding approximately $2.1 billion of senior notes, $600 million of senior secured notes, $399 million of indebtedness under our Term Loan Facility and $165 million of borrowings under our Revolving Credit Facility. Our existing and future level of debt could have important consequences to us, including the following: (i) our ability to obtain additional financing, if necessary, for working capital, capital expenditures, acquisitions or other purposes may be impaired, or such financing may not be available on favorable terms; (ii) the funds that we have available for operations and payment of dividends to shareholders will be reduced by that portion of our cash flow required to make principal and interest payments on outstanding debt; and (iii) our debt level could make us more vulnerable to competitive pressures than competitors with less debt or to a downturn in our business or the economy generally.

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Our ability to service our debt will depend upon, among other things, our future financial and operating performance, which will be affected by prevailing economic conditions and financial, business, regulatory and other factors, some of which are beyond our control. In addition, our ability to service debt under our Revolving Credit Facility, our Term Loan Facility and other debt facilities with floating rate terms will depend on market interest rates, since we anticipate that the interest rates applicable to our borrowings will fluctuate with movements in interest rate markets. If our operating results are not sufficient to service our current or future indebtedness, we will be forced to take actions such as reducing dividends, reducing or delaying our business activities, acquisitions, investments or capital expenditures, selling assets, restructuring or refinancing our debt, or seeking additional equity capital. We may not be able to effect any of these actions on satisfactory terms, or at all.

Increases in interest rates could increase our interest expense and may adversely affect our cash flows, our ability to service our indebtedness and our ability to pay dividends to our shareholders.

Our Term Loan Facility and borrowings under our Revolving Credit Facility have, and we may in the future enter into debt instruments with, variable interest rates. Beginning early in 2022, in response to growing signs of inflation, the Federal Reserve has increased interest rates rapidly. Increases in interest rates on variable rate debt will increase our interest expense unless we make arrangements to hedge the risk of rising interest rates. These increased costs could reduce our profitability, reduce our credit availability, limit our ability to pursue growth opportunities, impair our ability to meet our debt obligations, increase the cost of financing, place us at a competitive disadvantage and materially adversely affect our business, financial condition, cash flows and results of operations. An increase in interest rates also could limit our ability to refinance existing debt upon maturity or cause us to pay higher rates upon refinancing.

Restrictions under our existing or any future credit facilities, indentures and senior notes could adversely affect our business, financial condition, results of operations and ability to pay dividends to our shareholders.

Our existing Revolving Credit Facility and the indenture governing our senior notes limit our ability to, and any future credit facility or indenture we may enter into might limit our ability to, among other things: (i) incur additional indebtedness or guarantee other indebtedness; (ii) grant liens or make certain negative pledges; (iii) make certain dividends or investments; (iv) engage in transactions with affiliates; (v) transfer, sell or otherwise dispose of all or substantially all of our assets; or (vi) enter into a merger, consolidate, liquidate, wind up or dissolve.

Furthermore, our existing Revolving Credit Facility contains, or any future credit facility or indenture we may enter into may also contain, covenants requiring us to maintain certain financial ratios and tests. If we violate any of the restrictions, covenants, ratios or tests in the applicable credit facility or indentures, the lenders thereunder will be able to accelerate the maturity of all borrowings under the credit facility and demand repayment of amounts outstanding, and our lenders’ commitment to make further loans to us may terminate. We might not have, or be able to obtain, sufficient funds to make these accelerated payments. Any subsequent replacement of our Revolving Credit Facility or any new indebtedness could have similar or greater restrictions. For more information, see the section entitled "Management’s Discussion and Analysis of Financial Condition and Results of Operations—Capital Resources and Liquidity".

Continuing inflation and cost increases may impact our sales margins and profitability.

Inflationary pressure could adversely impact our profitability. Our operating costs have increased with the market and may continue to increase, due to the recent growth in inflation which has impacted product costs, labor rates, and domestic transportation. We may not be able to fully offset these inflation increases by raising prices for our services, which could result in downward pressure on our results of operations.

If our intangible assets or goodwill become impaired, we may be required to record a charge to earnings.

We annually review the carrying value of goodwill associated with business combinations we have made for impairment. Our intangible assets and goodwill are also reviewed whenever events or circumstances indicate that the carrying value of these assets may not be recoverable. Factors that may be considered for purposes of this analysis include a decline in stock price and market capitalization, slower industry growth rates, changes in cost of capital or material changes with customers or contracts that could negatively impact future cash flows. We cannot predict the timing, strength or duration of such changes or any subsequent recovery. If the carrying value of any of our intangible assets or goodwill is determined to be not recoverable, we may take a non-cash impairment charge, which could materially adversely affect our business, financial condition and results of operations.

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Regulatory Risks

The adoption of legislation and introduction of regulations relating to hydraulic fracturing and the enactment of new or increased severance taxes and impact fees on natural gas production could cause our current and potential customers to reduce the number of future wells or curtail production of existing wells. If reductions are significant for those or other reasons, the reductions could materially adversely affect our business, financial condition and results of operations.

The U.S. Congress has from time to time considered the adoption of legislation to provide for U.S. federal regulation of hydraulic fracturing, while a growing number of states, including some of those in which we operate, have adopted, and other states are considering adopting, regulations that could impose more stringent disclosure and/or well construction requirements on hydraulic fracturing operations. Some states, such as Pennsylvania, have imposed fees on the drilling of new unconventional oil and gas wells. Also, certain local governments have adopted, and additional local governments may further adopt, ordinances within their jurisdictions regulating the time, place and manner of drilling activities in general or hydraulic fracturing activities in particular. Further, several U.S. federal governmental agencies, including the EPA and the U.S. Department of Energy, have conducted or are conducting reviews and studies on the environmental aspects of hydraulic fracturing. These completed, ongoing or proposed studies on the environmental aspects of hydraulic fracturing, depending on their degree of pursuit and any meaningful results obtained, could spur initiatives to further regulate hydraulic fracturing or other regulatory mechanisms.

Certain state and U.S. federal regulatory agencies are also focused on a possible connection between hydraulic fracturing-related activities and the increased occurrence of seismic activity. In a few instances, operators of injection disposal wells in the vicinity of seismic events have been ordered to reduce injection volumes or suspend operations. These developments could result in additional regulation and restrictions on the use of injection disposal wells and hydraulic fracturing. The adoption of new laws, regulations or ordinances at the U.S. federal, state or local levels imposing more stringent restrictions on hydraulic fracturing could make it more difficult for our customers to complete natural gas wells, increase customers’ costs of compliance and doing business, and otherwise adversely affect the hydraulic fracturing services they perform, which could negatively impact demand for our services.

Furthermore, the tax laws, rules and regulations that affect our customers are subject to change. For example, Pennsylvania’s former governor has historically proposed legislation to impose a state severance tax on the extraction of natural resources, including natural gas produced from the Marcellus/Utica formations, either in replacement of or in addition to the existing state impact fee. Pennsylvania’s legislature has not thus far advanced any of the governor’s severance tax proposals; however, severance tax legislation may continue to be proposed in future legislative sessions. Any such tax increase or change could adversely impact the earnings, cash flows and financial position of our customers and cause them to reduce their drilling in the areas in which we operate.

Risks related to climate change could materially adversely affect our business, financial condition, results of operations, cash flow, access to and cost of capital or insurance, reputation, and business strategies.

Our business is subject to physical risks and transition risks related to climate change. Physical risks may arise from more frequent or severe weather events such as floods, landslides, storms, rising water levels, and changes in established weather patterns that cause damage to our assets or to portions of the country’s natural gas infrastructure upon which we or our customers rely. Physical risks from climate change may reduce our ability to operate reliably, safely, and economically and may cause significant insured or uninsured losses that affect our cash flows. In addition to physical risks, our business is subject to transition risks arising from efforts to address climate change through legislation and policies and through market preferences that disfavor fossil fuels and related businesses. State and federal governments, as well as foreign governments and international governing bodies such as the United Nations, continue to develop laws, policies, and goals to reduce carbon emissions, foster a lower-carbon economy, and transition away from fossil fuels. While these efforts are diverse and frequently change, they may impose additional compliance costs and may reduce market interest in our business. Changing customer behaviors may lead to less demand for our services, less favorable pricing for our services, inefficient utilization of our assets, and diminished reputation. Our ability to comply with laws and avoid or mitigate physical and transition risks related to climate change may be limited, insufficient, or dependent on technological developments (such as lower-emission equipment) that we do not control or that require substantial additional investments and increase our cost of doing business. If we are unable to implement business strategies that address the physical risks of climate change and that meet the changing expectations of regulators or investors concerning climate change, we may experience a material adverse effect on our business.

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Our operations are subject to environmental laws and regulations that may expose us to significant costs and liabilities and changes in these laws and regulations could materially adversely affect our business, financial condition and results of operations.

Our natural gas transmission, storage and gathering activities are subject to stringent and complex U.S. federal, state and local environmental laws and regulations relating to air quality, water quality, waste management, wildlife conservation, natural resources and worker health and safety. As with the industry generally, compliance with current and anticipated environmental laws and regulations increases our overall cost of conducting business, including our capital costs to construct, maintain and upgrade pipelines and other facilities, or may even cause us not to pursue a project. For instance, we may be required to obtain and maintain permits and other approvals issued by various U.S. federal, state and local governmental authorities; monitor for, limit or prevent releases of materials from our operations in accordance with these permits and approvals; install pollution control equipment or replace aging pipelines and other facilities; limit or prohibit construction activities in sensitive areas such as wetlands, wilderness or areas that provide habitat for endangered or threatened species; incur potentially substantial new obligations or liabilities for any pollution or contamination that may result from our operations; and apply health and safety criteria addressing worker protections. Failure to comply with environmental laws and regulations, or the permits issued under them, may result in the assessment of administrative, civil and criminal penalties, the imposition of investigatory, remedial or corrective action obligations or the incurrence of capital expenditures, the occurrence of delays in the permitting or performance or expansion of projects, the issuance of injunctions limiting or preventing some or all of our operations in a particular area, and private party claims for personal injuries or property damage.

Moreover, environmental laws, regulations and enforcement policies tend to become more stringent over time. New, modified or stricter environmental laws, regulations or enforcement policies, including climate change laws and regulations restricting emissions of GHGs could be implemented that significantly increase our compliance costs, pollution mitigation costs, or the cost of any necessary remediation of environmental contamination. For example, in April 2020 the U.S. federal district court for the district of Montana issued a broad order vacating NWP 12, a general permit issued by the U.S. Army Corps of Engineers relied upon by industry for expedited permitting of oil and gas pipelines, for alleged failure to comply with consultation requirements under the ESA. While the U.S. Supreme Court ultimately stayed the vacatur of NWP 12, the District Court’s action temporarily caused uncertainty and disruption in the industry. A challenge to the 2021 reissuance of NWP 12 (re-issued on a five-year schedule) is pending in the federal district court in Washington, D.C. after the case was transferred from federal court in Montana. The NWP 12 reissuance was among the agency actions listed for review in accordance with the January 20, 2021 Executive Order ("Protecting Public Health and the Environment and Restoring Science to Tackle the Climate Crisis"); and, in 2022 the U.S. Army Corps of Engineers sought public comment on the potential to revise NWP 12 in response to objections to the use of NWP 12 related, primarily, to environmental justice, public participation, and climate change. Any disruption in our ability to obtain coverage under NWP 12 or other general permits may result in increased costs and project delays if we are forced to seek individual permits from the U.S. Army Corps of Engineers. Our compliance with changing legal requirements could result in our incurring significant additional expenses and operating restrictions with respect to our operations, which may not be fully recoverable from customers and, thus, could materially adversely affect our business, financial condition and results of operations.

Our customers may similarly incur increased costs or restrictions that may limit or decrease those customers’ operations and have an indirect material adverse effect on our business, financial condition and results of operations. For example, an Executive Order was issued on January 27, 2021 ("Tackling the Climate Crisis at Home and Abroad") that included provisions directing the Secretary of the Interior to pause approval of new oil and natural gas leases on public lands pending completion of a comprehensive review and reconsideration of U.S. federal oil and gas permitting and leasing practices and directing the heads of U.S. federal agencies to take steps to ensure that, to the extent consistent with applicable law, federal funding is not directly subsidizing fossil fuels. In July 2021, however, a Federal Court in Louisiana granted a nationwide preliminary injunction against enforcement of the moratorium. On appeal, the injunction was overturned. However, a short time later, the Federal Court in Louisiana issued a nationwide permanent injunction against enforcement of the moratorium. Litigation related to the moratorium continues in various courts. While lease sales continue to some extent, they have been scaled back and are subject to challenge by environmental groups. On November 26, 2021 the Department of the Interior issued a report calling for an increase in royalty payments for new oil and gas leases on federal lands and other measures. Royalty rates have been increased for new leases. In November 2022, the Department of the Interior issued a proposed rule that would strictly limit releases of methane from oil and gas drilling on public lands. This could lead to increased costs for producers and increased need for pipeline capacity as operators would be required to have a plan to reduce venting and flaring as a predicate to approval of production of federal minerals. On January 26, 2024, the federal government announced a temporary pause on the authorization of new LNG terminals. During this pause, the U.S. Department of Energy will update the underlying analyses for LNG export authorizations. The pause could delay approximately a dozen LNG projects that are pending or in various stages of planning. Moreover, a number of state and regional legal initiatives, including climate change laws, have emerged in recent years that

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seek to reduce GHGs emissions and the EPA, based on its findings that emissions of GHGs present a danger to public health and the environment, has adopted regulations under existing provisions of the U.S. federal Clean Air Act that, among other things, restrict emissions of GHGs and require the monitoring and reporting of GHG emissions from specified onshore and offshore production sources and onshore treating sources in the U.S. on an annual basis. In addition, some communities and cities have banned new natural gas hook-ups or are expected to enact similar electrification measures in response to climate change concerns. Other actions that could be pursued by the current Administration may include the imposition of more restrictive requirements for the establishment of pipeline infrastructure, or the extension of the current pause on new LNG terminals or the current pause leading to a ban. Such regulations or any new U.S. federal laws restricting emissions of GHGs, such as a carbon tax, from customer operations, or that limit the growth of pipelines and LNG exports from the U.S., could delay or curtail their activities and, in turn, adversely affect our business, financial condition and results of operations.

There is inherent risk of the incurrence of environmental costs and liabilities in our business due to our handling of natural gas and hazardous substances, and historical industry operations and waste management and disposal practices. For example, an accidental release from one of our facilities could subject us to substantial liabilities arising from environmental cleanup and restoration costs, claims made by neighboring landowners and other third parties for personal injury and property damage, governmental claims for natural resource damages or imposing fines or penalties for related violations of environmental laws, permits or regulations. In addition, strict, joint and several liabilities may be imposed under certain environmental laws that govern the investigation and remediation of soil and groundwater contamination, which could cause us to become liable for the contamination caused by others, such as prior operators of our facilities, or for the consequences of our own actions that were in compliance with all applicable laws at the time those actions were taken, such as the historic disposal by us of hazardous substances or wastes at third party sites where contamination is subsequently discovered. Private parties, including the owners of the properties through which our assets pass and facilities where our wastes are taken for reclamation or disposal, may also have the right to pursue legal actions against us to enforce compliance, as well as to seek damages for non-compliance, with environmental laws and regulations or for personal injury or property damage that may result from environmental and other impacts of our operations. We may not be able to recover some or any of these costs through insurance or increased revenues, which could materially adversely affect our business, financial condition and results of operations. For more information, see the section entitled "Items 1. and 2. Business and Properties—Regulatory Environment—Environmental and Occupational Health and Safety Regulations".

Our natural gas transportation and storage operations are subject to extensive regulation by FERC and state regulatory authorities and changes in FERC or state regulation could materially adversely affect our business, financial condition and results of operations.

Our business operations are subject to extensive regulation by FERC, and state regulatory authorities. Generally, FERC’s authority extends to rates and charges for interstate pipelines and storage facilities as well as intrastate pipelines and storage facilities providing service in interstate commerce; terms and conditions of services and service contracts with customers; certification and construction of new interstate pipelines and storage services and facilities and expansion of such facilities; abandonment of interstate pipelines and storage services and facilities; maintenance of accounts and records; relationships between pipelines and certain affiliates; depreciation and amortization rates and policies; facility replacements and upgrades; and acquisitions and dispositions of interstate pipelines and storage facilities.

While FERC may exercise jurisdiction over the rates and terms of service for certain of the services provided by our intrastate pipelines providing service in interstate commerce, such assets are not subject to FERC’s certification and construction authority. Prior to commencing construction of new or expanded existing interstate pipelines and storage facilities, an interstate pipeline must obtain a certificate from FERC authorizing the construction, either by filing a new certificate application or filing to amend its existing certificate. In reviewing certificate applications or amendments, FERC applies its Certificate Policy Statement, which FERC is considering revising, in part to address the consideration of climate change when acting on such applications. A revised Certificate Policy Statement could result in more stringent review of future projects within FERC’s jurisdiction.

FERC regulations also extend to the terms and conditions set forth in agreements for our transportation and storage services executed between interstate transportation and storage service providers and their customers. These service agreements are required to conform, in all material respects, with the forms of service agreements set forth in the interstate company's FERC-approved tariff. Non-conforming agreements must be filed with, and accepted by, FERC. In the event that FERC finds that an agreement is materially non-conforming, in whole or in part, it could reject or require us to seek modification of the agreement, or alternatively require us to modify our tariff so that the non-conforming provisions are generally available to all customers or similarly-situated customers. Vector, Millennium, Birdsboro, NEXUS, and the Washington 10 Storage Complex provide interstate services in accordance with their FERC-approved tariffs.

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Compliance with these requirements can be time-consuming, costly and burdensome and FERC action in any of these areas could adversely affect our ability to compete for business, construct new facilities, offer new services or recover the full cost of operating our pipelines. This regulatory oversight can result in longer lead times to develop and complete any future project than competitors that are not subject to FERC’s regulations. Furthermore, should FERC or state regulatory authorities find that we have failed to comply with all applicable FERC or state-administered statutes, rules, regulations and orders, or the terms of our tariffs on file with FERC, we could be subject to administrative and criminal remedies and substantial civil penalties and fines. We cannot give any assurance regarding the likely future regulations under which we will operate our assets or the effect such regulation could have on our business, financial condition and results of operations.

Any changes to the policies of FERC or state regulatory authorities regarding the natural gas industry may have an impact on us, including FERC’s approach as it considers policies affecting the establishment and modification of interstate pipeline rates and terms and conditions of service, policies that may affect rights of access to natural gas transmission capacity and policies that govern FERC's authorization of new or expanded pipeline and storage infrastructure. FERC is currently considering modifications to its long-standing Certificate Policy Statement that currently governs its granting of certificate authority for the construction of proposed interstate natural gas infrastructure, whether new or expanded. In addition, future U.S. federal, state or local legislation or regulations under which we will operate our assets could materially adversely affect our business, financial condition and results of operations.

We are exposed to costs associated with lost and unaccounted-for volumes.

A certain amount of natural gas is inherently lost and unaccounted-for in connection with meter differences and movement across a pipeline or storage system, and under our contractual arrangements with our customers we are entitled to retain a specified volume of natural gas in order to compensate us for such volumes as well as the natural gas used to operate our compressor stations, which we refer to as "fuel usage." The level of fuel usage and lost and unaccounted-for volumes on our transportation, storage and gathering systems may exceed the natural gas volumes retained from our customers as compensation for such volumes. In addition, our gathering systems have contracts that provide for specified levels of fuel retainage. As such, we need to purchase natural gas in the market to make up for any of these differences, which exposes us to natural gas price risk. Future exposure to the volatility of natural gas prices as a result of gas imbalances on our transportation, storage and gathering systems could materially adversely affect our business, financial condition and results of operations.

A change in the jurisdictional characterization of our gathering assets may result in increased regulation by FERC, which could cause our revenues to decline and operating expenses to increase and could materially adversely affect our business, financial condition and results of operations.

We believe that our non-jurisdictional natural gas gathering facilities, including those which we refer to as "lateral pipelines," meet the traditional tests FERC has used to establish a pipeline’s status as an exempt gatherer not subject to regulation as a FERC-jurisdictional natural gas company under the NGA, although FERC has not made a formal determination with respect to the jurisdictional status of those facilities. FERC regulation nonetheless affects our businesses and the markets for products derived from our gathering businesses. FERC’s policies and practices across the range of its gas regulatory activities, including, for example, its policies on certification of new interstate natural gas facilities, open access transportation, rate making, terms and conditions of service, capacity release and market center promotion, indirectly affect intrastate markets. We have no assurance that FERC will continue its current policies as it considers matters such as certification of new interstate natural gas facilities, pipeline rates and rules and policies that may affect rights of access to natural gas transportation capacity. In addition, the distinction between FERC-regulated transmission services and federally unregulated gathering services is regularly the subject of substantial litigation in the industry. Consequently, the classification and regulation of some of our gathering operations could change based on future determinations by FERC, the courts or the U.S. Congress. If our gathering operations become subject to FERC jurisdiction, the result may adversely affect the rates we are able to charge and the services we currently provide and may include the potential for a termination of certain gathering agreements, which could materially adversely affect our business, financial condition and results of operations.

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State and local legislative and regulatory initiatives relating to gas operations could adversely affect our services and customers’ production and therefore, materially adversely affect our business, financial condition and results of operations.

State and municipal regulations also impact our business. Common purchaser statutes generally require gatherers to gather or provide services without undue discrimination as to source of supply or producer; as a result, these statutes restrict our right to decide whose production we gather or transport. U.S. federal law leaves any economic regulation of natural gas gathering to the states. Some of the states in which we currently operate have adopted complaint-based regulation of gathering activities, which allows gas producers and shippers to file complaints with state regulators in an effort to resolve access and rate grievances. Other state and municipal regulations may not directly regulate our gathering business but may nonetheless affect the availability of natural gas for purchase, treating and sale, including state regulation of production rates and maximum daily production allowable from gas wells. While our gathering lines currently are subject to limited state regulation, there is a risk that state laws will be changed, which may give producers a stronger basis to challenge the rates, terms and conditions of their gathering lines.

Certain states in which we operate have adopted or are considering adopting measures that could impose new or more stringent requirements on gas exploration and production activities. For example, the potential for adverse impacts to our business is present where state or local governments have enacted ordinances directly regulating production rates and maximum daily production allowable from gas wells, and private individuals have sponsored and may in the future sponsor citizen initiatives to limit hydraulic fracturing, increase mandatory setbacks of oil and gas operations from occupied structures and achieve more restrictive state or local control over such activities.

In the event state or local restrictions or prohibitions are adopted in our areas of operations, our customers may incur significant compliance costs or may experience delays or curtailment in the pursuit of their exploration, development or production activities, and possibly be limited or precluded in the drilling of certain wells altogether. Any adverse impact on our customers’ activities would have a corresponding negative impact on our throughput volumes. In addition, while the general focus of debate is on upstream development activities, certain proposals may, if adopted, directly impact our ability to competitively locate, construct, maintain and operate our own assets. Accordingly, such restrictions or prohibitions could materially adversely affect our business, financial condition and results of operations.

Changes in tax laws or regulations may have a material adverse effect on our business, cash flow, financial condition or results of operations.

New income, sales, use or other tax laws, statutes, rules, regulations or ordinances could be enacted at any time, which could adversely affect our business operations and financial performance. Further, existing tax laws, statutes, rules, regulations or ordinances could be interpreted, changed, modified or applied adversely to us. For example, significant changes to the U.S. tax laws have been proposed, including, among others, an increase in the corporate tax rate and the imposition of a tax on the fair market value of stock that is repurchased by certain corporations. It cannot be predicted whether or when tax laws, statutes, rules, regulations or ordinances may be enacted, issued, or amended. Changes to existing tax laws or the enactment of future reform legislation could have a material impact on our financial condition, results of operations and ability to pay dividends to our shareholders.

Some of our operations cross the U.S./Canada border and are subject to cross-border regulation.

Our cross-border activities subject us to regulatory matters, including import and export licenses, tariffs, Canadian and U.S. customs and tax issues, and toxic substance certifications. Such regulations include the "Short Supply Controls" of the Export Administration Act, the United States-Mexico-Canada Agreement and the Toxic Substances Control Act. Violations of these licensing, tariff and tax-reporting requirements could result in the imposition of significant administrative, civil and criminal penalties, which could, in turn, materially adversely affect our business, financial condition and results of operations.

Pipeline Safety and Maintenance Risks

We may incur significant costs and liabilities to maintain our pipeline integrity management program and related testing, pipeline repair, and preventative or remedial measures, as well as other operational and maintenance requirements and assessments.

The U.S. Department of Transportation, through PHMSA, has adopted regulations requiring pipeline operators to develop integrity management programs for transportation pipelines located where a leak or rupture could do the most harm in a high consequence area, referred to as an HCA. The regulations require operators to: (i) perform ongoing assessments of pipeline integrity; (ii) identify and characterize applicable threats to pipeline segments that could impact an HCA; (iii) improve data collection, integration and analysis; (iv) repair and remediate the pipeline as necessary; and (v) implement preventive and

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mitigating actions. PHMSA regulations also require assessment and repairs outside of HCAs in what are referred to as moderate consequence areas or MCAs.

Additionally, while states are preempted by U.S. federal law from regulating pipeline safety for interstate lines, most are certified by PHMSA to assume responsibility for enforcing U.S. federal intrastate pipeline regulations and inspection of intrastate pipelines. In practice, states can adopt stricter standards for intrastate pipelines than those imposed by PHMSA for interstate pipelines, and states vary considerably in their authority and capacity to address pipeline safety. Accordingly, midstream operators of pipeline and associated storage facilities may be required to make operational changes or modifications at their facilities to meet standards beyond current federal requirements, where such changes or modifications may result in additional capital costs, possible operational delays and potentially significant increased costs of operations.

Failure to comply with PHMSA or state pipeline safety regulations could result in a number of consequences which may have an adverse effect on our operations. We incur significant costs in complying with existing PHMSA and state pipeline safety regulations, but we do not believe such costs of compliance will materially adversely affect our business, financial condition and results of operations. We may incur significant costs associated with repair, remediation, preventive and mitigation measures associated with our integrity management programs and may be required to comply with new safety regulations and make additional maintenance capital expenditures in the future for similar regulatory compliance initiatives that are not reflected in our forecasted maintenance capital expenditures.

Certain portions of our pipelines, storage and gathering infrastructure are aging, which could materially adversely affect our business, financial condition and results of operations.

Certain portions of our systems, particularly our Northern Michigan assets and our storage assets, have been in operation for many years, with some portions being more than 40 years old. In some cases, certain portions may have been in service for many years prior to our purchase of the relevant systems or have been operated by third parties not under our control and consequently, there may be historical occurrences or latent issues regarding our pipeline systems that management may be unaware of and that could materially adversely affect our business, financial condition and results of operations. Certain portions of our pipeline systems are located in or near areas determined to be HCAs, which are areas where a leak or rupture could have the most significant adverse consequences. The age and condition of these systems could result in increased maintenance or repair expenditures, and any downtime associated with increased maintenance and repair activities could materially reduce our revenue. If, due to their age, certain pipeline sections were to become unexpectedly unavailable for current or future volumes of natural gas because of repairs, maintenance, damage, spills or leaks, or any other reason, it could materially adversely affect our business, financial condition and results of operation.

Our insurance policies do not cover all losses, costs or liabilities that we may experience, and there is no assurance that we will be able to purchase cost effective insurance in the future.

We are not fully insured against all risks inherent in our business, including environmental accidents that might occur as well as cyberattacks. In addition, we do not maintain business interruption insurance of the types and in amounts necessary to cover all possible risks of loss, like project delays caused by governmental action or inaction. The occurrence of any operating risk events not fully covered by insurance could materially adversely affect our business, financial condition and results of operations.

As a result of market conditions, premiums and deductibles for certain of our insurance policies may substantially increase. In some instances, certain insurance could become unavailable or available only for reduced coverage amounts. If significant changes in the number or financial solvency of insurance underwriters for the energy industry occur, we may be unable to obtain and maintain adequate insurance at a reasonable cost. The unavailability of full insurance coverage or our inability to maintain or obtain insurance of the type and amount we desire at reasonable rates to cover events in which we suffer significant losses could materially adversely affect our business, financial condition and results of operations.

A terrorist attack or armed conflict event, or the threat of them, could harm our business.

The U.S. Department of Homeland Security has continued to issue public warnings that indicated that pipelines and other energy assets might be specific targets of terrorist organizations. Potential targets include our pipelines, storage and gathering systems and may affect our ability to operate or control our assets or utilize our customer service systems. Destructive forms of protests and opposition by extremists, and other disruptions, including acts of sabotage or eco-terrorism, against oil and natural gas development and production or midstream treating or transportation activities could potentially result in damage or injury to persons, property or the environment or lead to extended interruptions of our or our customers’ operations. The threat or occurrence of any of these events could cause a substantial decrease in revenues; increased costs or other financial losses;

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exposure or loss of customer information; damage to our reputation or business relationships; increased regulation or litigation; disruption of our operations; and inaccurate information reported from our operations.

Other Business Risks

Customers’, legislators’ or regulators’ perceptions of us are affected by many factors, including environmental and safety concerns, pipeline reliability, protection of customer information, media coverage, and public sentiment. Customers’, legislators’ or regulators’ negative opinion of us could materially adversely affect our business, financial condition and results of operations.

Many factors can affect customers’, legislators’ or regulators’ perceptions of us, including: safety concerns due to potential natural disasters, the rupture of pipelines, or other causes and our ability to promptly respond to such issues; our ability to safeguard sensitive customer information; media coverage, including the proliferation of social media, which may include factual and nonfactual information that could damage the public sentiment and perception of our company and the midstream industry.

If customers, legislators or regulators have or develop a negative opinion of us and our services, or of fossil fuels as an energy source generally, this could hinder our ability to achieve favorable legislative or regulatory outcomes. Negative opinions could also result in sales volumes reductions, increased use of alternative forms of energy, reduced access to capital markets, or greater challenges in developing or operating our assets.

In addition, in recent years, increasing attention has been given to corporate activities related to ESG matters in public discourse and the investment community. Investor advocacy groups, proxy advisory firms, certain institutional investors and lenders, investment funds and other influential investors and rating agencies are increasingly focused on climate change, societal expectations on companies to address climate change, investor and societal expectations regarding voluntary ESG disclosures, and consumer demand for alternative forms of energy. Increasing attention to climate change and environmental conservation may result in increased costs, reduced access to insurance at reasonable rates, reduced demand for our services, reduced profits, negative impacts on our stock price, reduced access to capital markets, and governmental investigations and private litigation against us or our customers. To the extent that societal pressures or political or other factors are involved, it is possible that a liability could be imposed without regard to our causation of or contribution to the asserted damage, or to other mitigating factors. While we may participate in various voluntary frameworks and certification programs to improve the ESG profile of our operations and products, we cannot guarantee that such participation or certification will have the intended results on our ESG profile.

A number of advocacy groups have campaigned for governmental and private action to promote change at public companies related to ESG matters, including increasing attention and demands for action related to climate change, promoting the use of alternative forms of energy, and encouraging the divestment of companies in the fossil fuel industry. Some organizations that provide corporate governance and related information to investors have developed ratings systems for evaluating companies on their approach to ESG matters. Unfavorable ESG ratings may lead to increased negative investor and bank financing sentiment toward us and our industry and to the diversion of investment to other companies or industries, which could adversely affect the demand for our services, our stock price, our access to and costs of capital and, in turn, materially adversely affect our business, financial condition and results of operations.

We published our second annual Corporate Sustainability Report in the second quarter 2023, which detailed how we seek to manage our operations responsibly and ethically, as well as strategies and goals associated with reducing our environmental impact. The Corporate Sustainability Report included our policies and practices on a variety of social and ethical matters, including, but not limited to, corporate governance, environmental compliance, employee health and safety practices, human capital management and workforce inclusion and diversity. We believe providing more expansive disclosure on these topics in our Corporate Sustainability Report increases our transparency to our stakeholders and complements the disclosures regarding our contributions to sustainable development in this Form 10-K. It is possible that stakeholders may not be satisfied with our ESG practices or the speed of their adoption. We could also incur additional costs and require additional resources to monitor, report and comply with various ESG practices. Also, our failure, or perceived failure, to meet the standards set forth in the Corporate Sustainability Report could negatively impact our reputation, employee retention, and the willingness of our customers and suppliers to do business with us. Any of these consequences could materially adversely affect our business, financial condition and results of operations.

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We are subject to cybersecurity and data privacy laws, regulations, litigation and directives relating to our processing of personal data.

Our business involves collection, uses and other processing of personal data of our employees, contractors, suppliers and service providers. Governmental standards and commonly accepted frameworks for the protection of computer-based systems and technology from cyber threats and attacks have been adopted. New data privacy and cybersecurity laws add additional complexity, requirements, restrictions and potential legal risk, and compliance programs may require additional investment in resources, and could impact strategies and availability of previously useful data. Any failure by us or one of our technology service providers to comply with such laws and regulations could result in reputational harm, penalties, regulatory scrutiny, liabilities, legal claims, and/or mandated changes in our business practices.

A cyberattack or threat could harm our business.

We have become increasingly dependent on digital information technologies, including computer-based systems, infrastructure, and cloud applications, to conduct almost all aspects of our business. These include operating our pipeline, storage and gathering assets, recording commercial transactions, communicating with employees supporting our operations and our customers or other business partners, and reporting financial information. We also collect and store sensitive data in the ordinary course of our business, including personally identifiable information of our employees, as well as our proprietary business information and that of our vendors, customers and other business partners. We depend on both our own systems, networks and technology, as well as the systems, networks and technology of our vendors, customers, and other business partners, including our joint venture partners. The secure processing, maintenance and transmission of this information is critical to our operations.

Our increasing reliance on digital technologies puts us at risk for system failures, disruptions, incidents, data breaches and cyberattacks, which could significantly impair our ability to conduct our business. Cyberattacks are becoming more sophisticated and include, but are not limited to, ransomware, credential stuffing, spear phishing, social engineering and other attempts to gain unauthorized access to data for purposes of extortion or malfeasance. The methodologies used by attackers change frequently and may not be recognized until such attack is underway. In April 2022, the cybersecurity authorities of the United States, Australia, Canada, New Zealand, and the United Kingdom issued a joint cybersecurity advisory warning of the increased risks of Russian state-sponsored cyberattacks following the international response to Russia’s invasion of Ukraine. We expect to continue to be targeted by cyberattacks as a critical infrastructure company.

We may not be able to anticipate, detect or prevent all cyberattacks, and the threat or occurrence of a cyberattack affecting our information technology systems or the information technology systems of our counterparties, depending on the extent or duration of the event, could materially adversely affect us, including by leading to corruption, misappropriation or loss of our proprietary and sensitive data, delays (which could be significant) in the performance of services for our customers, difficulty in completing and settling transactions, challenges in maintaining our books and records, communication interruptions, environmental damage, regulatory scrutiny, personal injury or death, property damage and other operational disruptions, as well as damage to our reputation, financial condition and cash flows and potential legal claims and liabilities.

A pandemic, epidemic or outbreak of an infectious disease, such as the COVID-19 pandemic, could materially adversely affect our business, financial condition and results of operations.

A global or national public health crisis may cause disruptions to our business and operational plans. Some factors from a health crisis that could materially adversely affect our business, financial condition and results of operations include: third-party effects, including contractual and counterparty risk; litigation risk and possible loss contingencies; employee matters and insurance arrangements; supply/demand market and macroeconomic forces; lower commodity prices; unavailable storage capacity and operational effects; decreased utilization and rates for our assets and services; impact on liquidity and access to capital markets; our ability to comply with our covenants and other restrictions in agreements governing our debt; workforce reductions and furloughs; cybersecurity threats; operational, health or safety-related incidents; global supply chain disruptions; and U.S. federal, state and local actions.

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Risks Related to the Separation

We could have an indemnification obligation to DTE Energy in accordance with the terms of the Tax Matters Agreement if the Distribution were determined not to qualify for non-recognition treatment for U.S. federal tax purposes.

If it were determined that the Distribution did not qualify as a distribution to which Section 355(a), Section 355(c) and Section 361 of the Internal Revenue Code apply, we could, under certain circumstances, be required to indemnify DTE Energy for the resulting taxes and related expenses.

In addition, Section 355(e) of the Internal Revenue Code generally creates a presumption that the Distribution would be taxable to DTE Energy, but not to shareholders, if we or our shareholders were to engage in transactions that result in a 50% or greater change by vote or value in the ownership of our common stock during the four-year period beginning on the date that begins two years before the date of the Distribution, unless it were established that such transactions and the Distribution were not part of a plan or series of related transactions giving effect to such a change in ownership. If the Distribution were taxable to DTE Energy due to such a 50% or greater change in ownership of our stock, DTE Energy would recognize a gain equal to the excess of the fair market value of our common stock distributed to DTE Energy shareholders over DTE Energy’s tax basis in our common stock, and we generally would be required to indemnify DTE Energy for the tax on such gain and related expenses. Any such indemnification obligation could materially adversely affect our business, financial condition and results of operations.

We agreed to numerous restrictions to preserve the non-recognition treatment of the Distribution, which may reduce our strategic and operating flexibility.

We agreed in the Tax Matters Agreement to covenants and indemnification obligations that address compliance with Section 355(e) of the Internal Revenue Code. These covenants and indemnification obligations may limit our ability to pursue strategic transactions or engage in new businesses that may otherwise maximize the value of our Company and might discourage or delay a strategic transaction that our shareholders may consider favorable.

The Separation may expose us to potential liabilities arising out of state and U.S. federal fraudulent conveyance laws and legal dividend requirements.

If DTE Energy files for bankruptcy or is otherwise determined or deemed to be insolvent under U.S. federal bankruptcy laws, a court could deem the Separation or certain internal restructuring transactions undertaken by DTE Energy in connection with the Separation to be a fraudulent conveyance or transfer. Fraudulent conveyances or transfers are defined to include transfers made or obligations incurred with the actual intent to hinder, delay or defraud current or future creditors, or transfers made or obligations incurred for less than a reasonably equivalent value when the debtor was insolvent, or that rendered the debtor insolvent, inadequately capitalized or unable to pay its debts as they become due. A court could void the transactions or impose substantial liabilities upon us, which could materially adversely affect our business, financial condition and results of operations. Among other things, a court could require our shareholders to return to DTE Energy some or all of the shares of our common stock issued in the Separation or require us to fund liabilities of other companies involved in the restructuring transactions for the benefit of creditors. The distribution of our common stock is also subject to review under state corporate distribution statutes. Although DTE Energy intended to make a lawful distribution of our common stock, we cannot assure you that a court will not later determine that some or all of the Distribution to DTE Energy shareholders was unlawful.

After the Separation, certain members of management and directors may face actual or potential conflicts of interest.

Following the Separation, the management and directors of each of DTE Energy and DT Midstream own common stock in both companies. Robert Skaggs, Jr., who is the chairman of the Board of Directors for DT Midstream, also serves on the board of directors of DTE Energy and may be required to recuse himself from deliberations relating to arrangements between us and DTE Energy. This ownership and directorship overlap could create, or appear to create, potential conflicts of interest when the management and directors of one company face decisions that could have different implications for themselves and the other company. For example, potential conflicts of interest could arise in connection with the resolution of any dispute regarding the terms of the agreements governing our relationship with DTE Energy. These agreements include the Separation and Distribution Agreement, the Transition Services Agreement, the Tax Matters Agreement, the Employee Matters Agreement and any commercial agreements between the parties or their affiliates. Potential conflicts of interest may also arise out of any commercial arrangements that we or DTE Energy may enter into in the future.

For more information on the Separation and Distribution, see Note 1, "Description of the Business and Basis of Presentation" to the Consolidated Financial Statements under Part II, Item 8 of this Form 10-K.

37

Item 1B. Unresolved Staff Comments

None.

Item 1C. Cybersecurity

Cybersecurity Risk Management and Strategy

To identify and manage the material risks of cybersecurity threats to our business, operations and control environments, we have made investments in our technology and have implemented policies, programs and controls, with a focus on cybersecurity incident prevention and mitigation. Our cybersecurity program is integrated into our risk management process and is managed by a dedicated cybersecurity team that is responsible for leading enterprise-wide cybersecurity strategy, policy, standards, architecture, and processes. The program is aligned with industry standards and best practices, such as the National Institute of Standards and Technology Cybersecurity Framework. As part of our cybersecurity process, we engage external experts and consultants to assess our cybersecurity program and compliance with applicable practices and standards.

The Company mitigates risks from cybersecurity incidents using a multifaceted approach which includes, but is not limited to: establishing information security policies, implementing information protection processes and technologies, assessing cybersecurity risk, implementing cybersecurity training, monitoring our information technology systems, and collaborating with public and private organizations on best practices. The Company is currently in material compliance with relevant information privacy and cybersecurity governmental standards with which it is required to comply.

The Company has not experienced a material cybersecurity incident during the year ended December 31, 2023. For more information on how material cybersecurity incidents may impact our business, see Part I, Item 1A. "Risk Factors— Other Business Risks—"A cyberattack or threat could harm our business" of this Form 10-K.

Cybersecurity Governance

On July 26, 2023, the SEC adopted a final rule requiring, among other things, registrants to disclose certain information regarding cybersecurity risk management, strategy and governance annually and certain information about material cybersecurity incidents within four business days of the incident. The final rule became effective on September 5, 2023.

The Director of Cybersecurity has over 20 years of relevant experience and is responsible for managing our cybersecurity program and team, which monitors the day-to-day risks using the approach described above. Material near-term and long-term risks are communicated with senior management and the Board of Directors. The Company's Board of Directors is engaged in overseeing and reviewing the Company’s strategic direction and objectives, taking into account, among other considerations, the Company’s risk profile and exposures. While the Board of Directors retains oversight over policy and strategy related to cybersecurity, it has delegated the responsibility for the oversight of the Company’s cybersecurity program to the Audit Committee. The Audit Committee is responsible for reviewing and discussing the Company’s policies regarding risk assessment and risk management, major accounting risk exposures and the implementation and effectiveness of risk management protocols with respect to information technology security and cybersecurity risks, as well as reviewing material breaches and attacks, as applicable.

Item 3. Legal Proceedings

For information on legal proceedings and matters related to DT Midstream, see Note 12, "Commitments and Contingencies" to the Consolidated Financial Statements under Part II, Item 8 of this Form 10-K.

Item 4. Mine Safety Disclosures

Our sand mining facility in Louisiana is subject to regulation by the Mine Safety and Health Administration under the Federal Mine Safety and Health Act of 1977. Information concerning mine safety violations or other regulatory matters required by section 1503(a) of the Dodd-Frank Wall Street Reform and Consumer Protection Act and Item 104 of Regulation S-K is filed as Exhibit 95.1 to this Annual Report on Form 10-K.

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PART II

Item 5. Market for Registrant’s Common Equity, Related Stockholder Matters, and Issuer Purchases of Equity Securities

DT Midstream's common stock is listed under the ticker symbol "DTM" on the NYSE, which is the principal market for such stock. As of December 31, 2023, there were 96,971,021 shares of DT Midstream common stock issued and outstanding. These shares were held by a total of 39,293 shareholders of record.

We expect to pay regular cash dividends to DT Midstream common stockholders in the future. Any payment of future dividends is subject to approval by the Board of Directors and may depend on our future earnings, cash flows, capital requirements, financial condition, and the effect a dividend payment would have on our compliance with relevant financial covenants. Over the long-term, we expect to grow our dividend 5% to 7% annually. For information on DT Midstream's dividend restrictions, see Note 10, "Debt" to the Consolidated Financial Statements under Part II, Item 8 of this Form 10-K. There were no sales of unregistered equity securities during the past three years.

Securities Authorized for Issuance Under Equity Compensation Plans

DT Midstream's Long-Term Incentive Plan was approved by shareholders as an equity compensation plan that provides for the annual awarding of stock-based compensation. For additional detail, see Note 13, "Stock-Based Compensation and Defined Contribution Plans" to the Consolidated Financial Statements under Part II, Item 8 of this Form 10-K.

See the following table for information as of December 31, 2023:

	Number of Securities to be Issued Upon Exercise of Outstanding Options, Warrants, and Rights (a)	Weighted-Average Exercise Price of Outstanding Options, Warrants, and Rights		Number of Securities Remaining Available for Future Issuance Under Equity Compensation Plans
DT Midstream, Inc. Long-Term Incentive Plan	974,733	$	—	5,229,267

_____________________________________

(a)Includes 417,294 Restricted Stock Units and 557,439 Performance Share Awards

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COMPARISON OF CUMULATIVE TOTAL RETURN

Total Return to DT Midstream Investors

The graph below shows the cumulative total shareholder return assuming the investment of $100, including the reinvestment of dividends, on July 1, 2021 in our common stock, the Standard & Poor’s 500 (“S&P 500”) Index, and the Alerian Midstream Energy (“AMNA”) Index. We believe the AMNA Index is meaningful because it is an independent, objective view of the performance of similarly-sized midstream energy companies.

	Base Period	Indexed Returns
Company/Index	July 1, 2021	December 31, 2021	December 31, 2022	December 31, 2023
DT Midstream	100.00	117.18	141.56	148.29
S&P 500 Index	100.00	111.07	90.94	114.82
Alerian Midstream Energy Index	100.00	97.63	118.56	136.19

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Item 7. Management’s Discussion and Analysis of Financial Condition and Results of Operations

This discussion contains forward-looking statements that involve risks and uncertainties. The forward-looking statements are not historical facts, but rather are based on current expectations, estimates, assumptions and projections about the midstream industry and our business and financial results. Our actual results could differ materially from the results contemplated by these forward-looking statements due to a number of factors, including those discussed in the sections entitled "Forward-Looking Statements" and "Risk Factors."

OVERVIEW

Our Business

We are an owner, operator, and developer of an integrated portfolio of natural gas midstream assets. We provide multiple, integrated natural gas services to customers through our Pipeline segment, which includes interstate pipelines, intrastate pipelines, storage systems, and lateral pipelines, and through our Gathering segment. We also own joint venture interests in equity method investees which own and operate interstate pipelines that connect to our wholly owned assets.

Our core assets strategically connect key demand centers in the Midwestern U.S., Eastern Canada and Northeastern U.S. regions to the premium production areas of the Marcellus/Utica natural gas formation in the Appalachian Basin and connect key demand centers and LNG export terminals in the Gulf Coast region to premium production areas of the Haynesville natural gas formation.

We have an established history of stable, long-term growth with contractual cash flows from customers that include natural gas producers, local distribution companies, electric power generators, industrials, and national marketers.

On July 1, 2021, DT Midstream completed the Separation from DTE Energy and became an independent public company. See Note 1, "Description of the Business and Basis of Presentation" to the Consolidated Financial Statements under Part II, Item 8 of this Form 10-K.

Our Strategy

See discussion of our strategy under Part I, Items 1. and 2. "Business and Properties—Our Strategy" of this Form 10-K.

RESULTS OF OPERATIONS

Management’s Discussion and Analysis of Financial Condition and Results of Operations includes financial information prepared in accordance with GAAP. The following sections discuss the operating performance and future outlook of our segments. Segment information includes intercompany revenues and expenses, as well as other income and deductions that are eliminated in the Consolidated Financial Statements.

For purposes of the following discussion, any increases or decreases refer to the comparison of the year ended December 31, 2023 to the year ended December 31, 2022, or the year ended December 31, 2022 to the year ended December 31, 2021, as applicable. The following table summarizes our consolidated financial results:

	Year Ended December 31,
	2023		2022		2021
	(millions, except per share amounts)
Operating revenues	$	922	$	920	$	840
Net Income Attributable to DT Midstream	384		370		307
Diluted Earnings per Common Share	$	3.94	$	3.81	$	3.16

	Year Ended December 31,
	2023		2022		2021
	(millions)
Net Income Attributable to DT Midstream by Segment
Pipeline	$	278	$	228	$	178
Gathering	106		142		129
Total	$	384	$	370	$	307

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Pipeline

The Pipeline segment consists of our interstate pipelines, intrastate pipelines, storage systems, lateral pipelines including related treatment plants and compression and surface facilities. This segment also includes our equity method investments. During the three months ended March 31, 2023, we completed the conversion of the Michigan System from gathering to dry gas transmission service and began providing services under a new long-term dry gas transmission contract. For the year ended December 31, 2023, the Michigan System financial results are presented in the Pipeline segment. The prior years' comparative activity was for gathering services and therefore was not revised from presentation in the Gathering segment.

Pipeline results and outlook are discussed below:

	Year Ended December 31,
	2023		2022		2021
	(millions)
Operating revenues	$	377	$	339	$	307
Operation and maintenance	55		54		59
Depreciation and amortization	69		63		63
Taxes other than income	15		14		13
Asset (gains) losses and impairments, net	(4)		(6)		—
Operating Income	242		214		172
Interest expense	55		57		51
Interest income	(1)		(1)		(1)
Earnings from equity method investees	(177)		(150)		(126)
Loss from financing activities	—		6		—
Other (income) and expense	—		—		(3)
Income Tax Expense	75		62		62
Net Income	290		240		189
Less: Net Income Attributable to Noncontrolling Interests	12		12		11
Net Income Attributable to DT Midstream	$	278	$	228	$	178

Operating revenues increased $38 million for the year ended December 31, 2023 primarily due to higher long-term and short-term storage contracting rates at the Washington 10 Storage Complex of $18 million, new transmission service contracts at the Michigan System of $16 million, and new LEAP long-term firm service revenue contracts of $10 million, partially offset by lower volumes at Bluestone of $2 million. Operating revenues increased $32 million for the year ended December 31, 2022 primarily due to higher volumes and rates on LEAP of $21 million, a new customer on Stonewall of $7 million, and higher volumes and rates at the Washington 10 Storage Complex of $4 million.

Operation and maintenance expense increased $1 million for the year ended December 31, 2023 primarily due to new transmission service contracts at the Michigan System, partially offset by increased capitalized labor and overhead. Operation and maintenance expense decreased $5 million for the year ended December 31, 2022 primarily due to lower Separation-related transaction costs of $10 million, partially offset by increased maintenance and labor costs at the Washington 10 Storage Complex of $3 million.

Depreciation and amortization expense increased $6 million for the year ended December 31, 2023 primarily due to new transmission service assets at the Michigan System and new Haynesville System (LEAP) assets placed into service.

Asset (gains) losses and impairments, net increased $6 million for the year ended December 31, 2022 due to a one-time gain realized from a legal settlement with a supplier that occurred in 2022.

Interest expense decreased $2 million for the year ended December 31, 2023 primarily due to higher capitalized interest on higher construction in progress during 2023, partially offset by higher borrowings and rates under the Revolving Credit Facility, higher interest rates on the Term Loan Facility, and a full year of interest expense related to our 2032 Notes. Interest expense increased $6 million for the year ended December 31, 2022 primarily due to higher outstanding borrowings and higher interest rates on our external debt as compared to interest rates on borrowings from DTE Energy prior to the Separation.

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Earnings from equity method investees increased $27 million for the year ended December 31, 2023 primarily due to higher earnings from Millennium of $19 million from our higher ownership percentage and a goodwill impairment at Generation of $7 million in 2022. Additionally, NEXUS had increased contract rates and additional customers offset by higher interest expense from new senior unsecured notes. Earnings from equity method investees increased $24 million for the year ended December 31, 2022 primarily due to the Millennium acquisition of $9 million, higher revenues from increased contract rates and additional customers at NEXUS of $15 million and higher westbound contracted volumes at Vector of $4 million, partially offset by a goodwill impairment at Generation of $7 million. On October 7, 2022, DT Midstream closed on the $552 million purchase of an additional 26.25% ownership interest in Millennium from National Grid. See Note 1, "Description of the Business and Basis of Presentation" to the Consolidated Financial Statements under Part II, Item 8 of this Form 10-K.

Loss from financing activities decreased $6 million for the year ended December 31, 2023 and increased $6 million for the year ended December 31, 2022 due to the partial repayment of our Term Loan Facility that occurred during the three months ended June 30, 2022. See Note 10, "Debt" to the Consolidated Financial Statements under Part II, Item 8 of this Form 10-K for further details.

Income tax expense increased $13 million for the year ended December 31, 2023 primarily due to higher income before income taxes in 2023. Income tax expense for the years ended December 31, 2023 and 2022 include the impacts of net tax benefits related to state tax rate changes. Income tax expense was unchanged for the year ended December 31, 2022 due to increased Income before income taxes, fully offset by state tax rate changes. See Note 7, "Income Taxes" to the Consolidated Financial Statements under Part II, Item 8 of this Form 10-K for further details.

Pipeline Outlook

We believe our long-term agreements with customers and the location and connectivity of our pipeline assets position the business for future growth. We will continue to pursue economically attractive expansion opportunities that leverage our current asset footprint and strategic relationships. These growth opportunities include further expansion at the Haynesville System (LEAP) and Stonewall, new contracts at the Washington 10 Storage Complex, and additional growth related to our equity method investments.

Gathering

The Gathering segment includes gathering systems, related treatment plants and compression and surface facilities. Gathering results and outlook are discussed below:

	Year Ended December 31,
	2023		2022		2021
	(millions)
Operating revenues	$	545	$	581	$	534
Operation and maintenance	190		213		173
Depreciation and amortization	113		107		103
Taxes other than income	13		14		11
Asset (gains) losses and impairments, net	—		(17)		17
Operating Income	229		264		230
Interest expense	95		80		61
Interest income	—		(2)		(3)
Loss from financing activities	—		7		—
Other (income) and expense	(1)		(1)		1
Income Tax Expense	29		38		42
Net Income Attributable to DT Midstream	$	106	$	142	$	129

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Operating revenues decreased $36 million for the year ended December 31, 2023 primarily due to lower Haynesville System (Blue Union Gathering) revenues of $50 million, lower Michigan System gathering services of $6 million, and lower Susquehanna Gathering volumes of $3 million, partially offset by higher Appalachia Gathering volumes of $21 million driven primarily by new contracts resulting from the expansion in 2023. Lower Blue Union Gathering revenues were driven primarily by lower deficiency fees of $23 million, lower recovery of production-related operating expenses of $12 million, lower rates of $9 million and lower production volumes of $5 million. Operating revenues increased $47 million for the year ended December 31, 2022 primarily due to higher Blue Union Gathering revenues of $42 million and higher volumes on Appalachia Gathering of $5 million. Higher Blue Union Gathering revenues were driven by recovery of production-related operating expenses of $25 million and increased gathering volumes primarily from new contracts of $17 million.

Operation and maintenance expense decreased $23 million for the year ended December 31, 2023 primarily due to lower Haynesville System (Blue Union Gathering) expenses of $14 million driven by lower production-related operating expenses, a reduction in Appalachia Gathering environmental contingent liabilities of $6 million, and increased capitalized labor and overhead of $3 million. Operation and maintenance expense increased $40 million for the year ended December 31, 2022 primarily due to higher Blue Union Gathering and Susquehanna Gathering expenses of $46 million and $2 million, respectively, partially offset by lower Appalachia Gathering expenses of $7 million. Higher Blue Union Gathering expenses were driven by planned maintenance and increased production-related operating expenses recovered from customers. Higher public company costs were mostly offset by lower Separation-related transaction costs of $10 million.

Depreciation and amortization expense increased $6 million for the year ended December 31, 2023 primarily due to new Blue Union Gathering and Appalachia Gathering assets placed into service. Depreciation and amortization expense increased $4 million for the year ended December 31, 2022 primarily due to new Blue Union Gathering and Susquehanna Gathering assets placed into service.

Asset (gains) losses and impairments, net decreased $17 million for the year ended December 31, 2023 due to the 2022 one-time gain on sale of certain assets in the Utica Shale region. Asset gains of $17 million for the year ended December 31, 2022 increased as compared to Asset losses and impairments, net of $17 million for the year ended December 31, 2021. The increase was due to the 2022 one-time gain on sale of certain assets in the Utica Shale region of $17 million as compared to the 2021 one-time loss on notes receivable for an investment in certain assets in the Utica Shale region of $19 million, partially offset by a $2 million gain on sale of Michigan System assets. See Note 2, "Significant Accounting Policies" to the Consolidated Financial Statements under Part II, Item 8 of this Form 10-K for further details.

Interest expense increased $15 million for the year ended December 31, 2023 primarily due to higher borrowings and interest rates under the Revolving Credit Facility, higher interest rates on the Term Loan Facility, and a full year of interest expense related to our 2032 Notes, partially offset by higher capitalized interest due to higher construction in progress during 2023. Interest expense increased $19 million for the year ended December 31, 2022 primarily due to higher outstanding borrowings and higher interest rates on our external debt as compared to interest rates on borrowings from DTE Energy prior to the Separation.

Loss from financing activities decreased $7 million for the year ended December 31, 2023 and increased $7 million for the year ended December 31, 2022 due to the partial repayment of our Term Loan Facility that occurred during the three months ended June 30, 2022. See Note 10, "Debt" to the Consolidated Financial Statements under Part II, Item 8 of this Form 10-K for further details.

Income tax expense decreased $9 million for the year ended December 31, 2023 primarily due to lower income before income taxes in 2023. Income tax expense for the years ended December 31, 2023 and 2022 include the impacts of net tax benefits related to state tax rate changes. Income tax expense decreased $4 million for the year ended December 31, 2022 primarily due to state tax rate changes. The decrease was partially offset by an increase in Income before income taxes. See Note 7, "Income Taxes" to the Consolidated Financial Statements under Part II, Item 8 of this Form 10-K for further details.

Gathering Outlook

We believe our long-term agreements with producers and the quality of the natural gas reserves in the Marcellus/Utica and Haynesville formations position the business for future growth. We will continue to pursue economically attractive expansion opportunities that leverage our current asset footprint and strategic relationships. These growth opportunities include further expansion at the Haynesville System (Blue Union Gathering), Appalachia Gathering, Tioga Gathering, and Ohio Utica Gathering.

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ENVIRONMENTAL MATTERS

We are subject to extensive U.S. federal, state, and local environmental regulations. Additional compliance costs may result as the effects of various substances on the environment are studied and governmental regulations are developed and implemented. Actual costs to comply with such regulation could vary substantially from our expectations. Pending or future legislation or regulation could have a material impact on our operations and financial position. Potential impacts include unplanned expenditures for environmental equipment, such as pollution control equipment, financing costs related to additional capital expenditures, and the replacement costs of aging pipelines and other facilities.

For further discussion of environmental matters, see Part I, Items 1. and 2. "Business and Properties—Regulatory Environment—Environmental and Occupational Health and Safety Regulations" and Note 12, "Commitments and Contingencies" to the Consolidated Financial Statements under Part II, Item 8 of this Form 10-K.

CLIMATE CHANGE

We believe we have a responsibility to address climate change and have made consistent, effective environmental policies a priority. Our Board of Directors includes a committee focused on environmental, social and governance initiatives. Our strategy will focus on targeted growth from carbon-reducing technologies associated with our current platforms. We have announced our intent to employ carbon-reducing technologies as part of our goal of being leading environmental stewards in the midstream industry, and we are executing on a plan to achieve net zero carbon emissions by 2050. We established our baseline Scope 1 carbon emissions in 2021 and expect to achieve a 30% reduction from this baseline by 2030.

During 2024, we plan to continue to make progress on opportunities for energy transition advancements leveraging our existing assets, competencies and partnerships. These opportunities include the following:

•Our efforts to advance our Louisiana carbon capture project, as well as other potential carbon capture projects across our geographic regions;

•Our "wellhead to water" expansion proposal of the Haynesville System which offers a carbon neutral pathway for supply to reach LNG markets; and

•Our strategic joint development agreement with Mitsubishi Power Americas, Inc. to advance hydrogen development projects across the United States.

Capital expenditure investments for these projects have been contemplated in our forecasted capital expenditures discussed in the Capital Investments section below.

DT Midstream published our second annual Corporate Sustainability Report in the second quarter 2023. The information in our Corporate Sustainability Report is not incorporated by reference into this Form 10-K.

For discussion of various risks including transitional risks associated with climate change related laws and regulations, reputational risks of climate change, and the physical risks of climate change, see Part I, Item 1A. "Risk Factors—Regulatory Risks—Risks related to climate change could materially adversely affect our business, financial condition, results of operations, cash flow, access to and cost of capital or insurance, reputation, and business strategies." of this Form 10-K. For discussion of recent climate change related laws and regulations, see Part I, Items 1. and 2. "Business and Properties—Regulatory Environment—Environmental and Occupational Health and Safety Regulations—Climate Change" of this Form 10-K.

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CAPITAL RESOURCES AND LIQUIDITY

Cash Requirements

Our principal liquidity requirements are to finance our operations, fund capital expenditures, satisfy our indebtedness obligations, and pay approved dividends. We believe we will have sufficient internal and external capital resources to fund anticipated capital and operating requirements.

	Year Ended December 31,
	2023		2022		2021
	(millions)
Cash and Cash Equivalents at Beginning of Period	$	61	$	132	$	42
Net cash and cash equivalents from operating activities	798		725		572
Net cash and cash equivalents from (used for) investing activities	(351)		(854)		123
Net cash and cash equivalents from (used for) financing activities	(452)		58		(605)
Net Increase (Decrease) in Cash and Cash Equivalents	(5)		(71)		90
Cash and Cash Equivalents at End of Period	$	56	$	61	$	132

For purposes of the following discussion, any increases or decreases refer to the comparison of the year ended December 31, 2023 to the year ended December 31, 2022 and the year ended December 31, 2022 to the year ended December 31, 2021.

Operating Activities

Cash flows from our operating activities can be impacted in the short term by the natural gas volumes gathered or transported through our systems under interruptible service revenue contracts, changing natural gas prices, seasonality, weather fluctuations, dividends received from equity method investees and the financial condition of our customers. Our preference to enter into firm service revenue contracts leads to more stable operating performance, revenues and cash flows and limits our exposure to natural gas price fluctuations.

Net cash and cash equivalents from operating activities increased $73 million for the year ended December 31, 2023 primarily due to a decrease in cash paid for taxes, net changes in working capital, an increase in operating income after adjustment for non-cash items including depreciation and amortization expense, stock-based compensation, amortization of operating lease right-of-use assets, and assets (gains) losses and impairments, and an increase in dividends received from equity method investees. These increases were partially offset by an increase in interest expense.

Net cash and cash equivalents from operating activities increased $153 million for the year ended December 31, 2022 primarily due to net changes in working capital, an increase in operating income after adjustment for non-cash items including depreciation and amortization expense, amortization of operating lease right-of-use assets, and assets (gains) losses and impairments, and an increase in dividends received from equity method investees. These increases were partially offset by an increase in interest expense and an increase in cash paid for income taxes.

Investing Activities

Cash outflows associated with our investing activities are primarily the result of plant and equipment expenditures, acquisitions, and contributions to equity method investees. Cash inflows from our investing activities are generated from proceeds from sale or collection of notes receivable, distributions received from equity method investees, and proceeds from asset sales.

In May 2023, NEXUS closed on the sale of $750 million of senior unsecured notes with a weighted-average coupon rate of 5.52%. We received a distribution from NEXUS of $371 million, net of fees and expenses, which reduced our investment balance.

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Net cash and cash equivalents used for investing activities decreased $503 million for the year ended December 31, 2023 primarily due to the acquisition of an additional 26.25% ownership interest in the Millennium from National Grid in 2022 and higher distributions received from equity method investees in 2023, including the NEXUS distribution noted above. This change was partially offset by an increase in cash used for plant and equipment expenditures for expansions on LEAP, Blue Union Gathering, Appalachia Gathering, and Ohio Utica Gathering, and a decrease in proceeds from the sale of notes receivable.

Net cash and cash equivalents used for investing activities of $854 million for the year ended December 31, 2022 increased as compared to net cash and cash equivalents from investing activities of $123 million for the year ended December 31, 2021. The increase was primarily due to the acquisition of an additional 26.25% ownership interest in the Millennium from National Grid in 2022, cash collection of the Notes receivable from DTE Energy in 2021, and an increase in cash used for plant and equipment expenditures in 2022, partially offset by proceeds from the sale of notes receivable in 2022.

Financing Activities

In April 2022, we issued the 2032 Notes in aggregate principal amount of $600 million. We used the net proceeds from the sale of the 2032 Notes of $593 million to partially repay indebtedness under our Term Loan Facility. See Note 10, "Debt" to the Consolidated Financial Statements under Part II, Item 8 of this Form 10-K.

DT Midstream paid cash dividends on common stock of $263 million, $244 million, and $58 million during the years ended December 31, 2023, 2022 and 2021, respectively. See Note 8, "Earnings Per Share and Dividends" to the Consolidated Financial Statements under Part II, Item 8 of this Form 10-K.

Net cash and cash equivalents used for financing activities of $452 million for the year ended December 31, 2023 increased as compared to net cash and cash equivalents from financing activities of $58 million for the year ended December 31, 2022. The increase was primarily due to higher net repayments of borrowings under the Revolving Credit Facility, higher dividends paid on common stock, and lower proceeds from the issuance of long-term debt. The increase was partially offset by lower repayments of long-term debt.

Prior to the Separation, we relied on short-term borrowings and contributions from DTE Energy. In June 2021, we issued the 2029 Notes and 2031 Notes in aggregate principal amount of $2.1 billion and entered into a $1.0 billion Term Loan Facility. Proceeds were used for the repayment of the short-term borrowings due to DTE Energy, as well as a one-time special dividend provided to DTE Energy.

Net cash and cash equivalents from financing activities of $58 million for the year ended December 31, 2022 increased as compared to net cash and cash equivalents used for financing activities of $605 million for the year ended December 31, 2021. The increase was primarily due to the 2021 Separation-related repayment of short-term borrowings and special dividend to DTE Energy, partially offset by contributions from DTE Energy that did not recur in 2022. Additionally, the increase was driven by higher borrowings under the revolving credit facility in 2022. The increase was partially offset by lower proceeds from the issuance of long-term debt, higher repayment of long-term debt, and higher dividends paid on common stock in 2022.

Outlook

We expect to continue executing on our natural gas-centric business strategy focused on disciplined capital deployment and supported by a flexible, well capitalized balance sheet. Other than the impact of the items discussed below on our debt and equity capitalization, we are not aware of any trends, other demands, commitments, events or uncertainties that are reasonably likely to materially impact our liquidity position.

Our working capital requirements will be primarily driven by changes in accounts receivable and accounts payable. We continue our efforts to identify opportunities to improve cash flows through working capital initiatives and obtaining long-term firm service revenue contracts from customers.

Our sources of liquidity include cash and cash equivalents generated from operating activities and available borrowings under our Revolving Credit Facility. As of December 31, 2023, we had $16 million of letters of credit outstanding and $165 million of borrowings outstanding under our Revolving Credit Facility. We had approximately $875 million of available liquidity as of December 31, 2023, consisting of cash and cash equivalents and available borrowings under our Revolving Credit Facility.

47

We expect to pay regular cash dividends to DT Midstream common stockholders in the future. Any payment of future dividends is subject to approval by the Board of Directors and may depend on our future earnings, cash flows, capital requirements, financial condition, and the effect a dividend payment would have on our compliance with relevant financial covenants. Over the long-term, we expect to grow our dividend 5% to 7% annually.

We believe we will have sufficient operating flexibility, cash resources and funding sources to maintain adequate liquidity amounts and to meet future operating cash, capital expenditure and debt servicing requirements. However, our business is capital intensive, and the inability to access adequate capital could adversely impact future earnings and cash flows.

The Credit Agreement covering the Term Loan Facility and Revolving Credit Facility includes financial covenants that DT Midstream must maintain. See Note 10, "Debt" and Note 12, "Commitments and Contingencies" to the Consolidated Financial Statements under Part II, Item 8 of this Form 10-K.

Credit Ratings

Credit ratings are intended to provide banks and capital market participants with a framework for comparing the credit quality of securities and are not a recommendation to buy, sell, or hold securities. Our credit ratings affect our cost of capital and other terms of financing, as well as our ability to access the credit and commercial paper markets. We believe that the current credit ratings provide sufficient access to capital markets. However, disruptions in the banking and capital markets not specifically related to us may affect our ability to access these funding sources or cause an increase in the return required by investors.

Contractual Obligations

The following table details our contractual obligations due by year as of December 31, 2023:

	2024		2025		2026		2027		2028 and Thereafter
	(millions)
Short-term borrowings (a)	$	165	$	—	$	—	$	—	$	—
Long-Term Debt:
Senior Notes (b)	—		—		—		—		2,100
Senior Secured Notes (c)	—		—		—		—		600
Term Loan Facility (d)	—		—		—		—		399
Letters of credit	—		—		—		—		16
Interest expense (e)	127		125		125		126		342
Operating lease payments	15		9		7		7		6
Purchase commitments	14		13		12		11		53
Total Contractual Obligations	$	321	$	147	$	144	$	144	$	3,516

_____________________________

(a) Short-term borrowings under our Revolving Credit Facility can be extended up to the October 2027 expiration date.

(b) Excludes $23 million of unamortized debt issuance costs.

(c) Excludes $1 million of unamortized debt discount and $5 million of unamortized debt issuance costs.

(d) Excludes $1 million of unamortized debt discount and $4 million of unamortized debt issuance costs.

(e) Represents interest expense related to all Long-Term Debt. The interest expense related to the Term Loan Facility assumes the variable rate is 2.614%.

CAPITAL INVESTMENTS

Capital spending within our Company is primarily for ongoing maintenance and expansion of our existing assets, and if identified, attractive growth opportunities. We have been disciplined in our capital deployment and make growth investments that meet our criteria in terms of strategy, management skills, and identified risks and expected returns. All potential investments are analyzed for their rates of return and cash payback on a risk-adjusted basis. Our total capital expenditures, inclusive of $7 million in contributions to equity method investees, were $779 million for the year ended December 31, 2023. We anticipate total capital expenditures, inclusive of contributions to equity method investees, for the year ended December 31, 2024 of approximately $350 million to $435 million.

48

OFF-BALANCE SHEET ARRANGEMENTS

We are party to off-balance sheet arrangements, which include our equity method investments. See Note 1, "Description of the Business and Basis of Presentation—Principles of Consolidation" to the Consolidated Financial Statements under Part II, Item 8 of this Form 10-K for further discussion of the nature, purpose and other details of such agreements.

Other off-balance sheet arrangements include the Vector line of credit and our surety bonds, which are discussed further in Note 12, "Commitments and Contingencies" to the Consolidated Financial Statements under Part II, Item 8 of this Form 10-K.

INDEMNIFICATION OBLIGATIONS

We could have an indemnification obligation to DTE Energy pursuant to the Tax Matters Agreement and the Separation and Distribution Agreement. See Part I, Item 1A. "Risk Factors—Risks Related to the Separation—We could have an indemnification obligation to DTE Energy in accordance with the terms of the Tax Matters Agreement if the Distribution were determined not to qualify for non-recognition treatment for U.S. federal tax purposes." of this Form 10-K for further details.

CRITICAL ACCOUNTING ESTIMATES

The preparation of our Consolidated Financial Statements in conformity with GAAP requires that management applies accounting policies and makes estimates and assumptions that affect results of operations and the amounts of assets and liabilities reported in the Consolidated Financial Statements. Management believes that the areas described below require significant judgment in the application of the accounting policy or in making estimates and assumptions in matters that are inherently uncertain and that may change in subsequent periods. See additional discussion of our accounting policies in the Notes to Consolidated Financial Statements in Item 8 of this Form 10-K.

Goodwill

We have goodwill that resulted from business combinations. Annually as of October 1st, an impairment test for goodwill is performed which compares the fair value of each reporting unit to its carrying value including goodwill. If the carrying value including goodwill exceeds the fair value of a reporting unit, an impairment loss would be recognized. A goodwill impairment loss is measured as the amount by which a reporting unit’s carrying value exceeds its fair value, not to exceed the carrying amount of goodwill.

The October 1, 2023 fair values for the reporting units were calculated using an income approach. The estimated fair value in our annual goodwill impairment analysis utilizes significant assumptions that require judgement by management. One such significant assumption is the weighted average cost of capital (WACC) which is used to discount estimates of projected future results and cash flows to be generated by each reporting unit. The WACC is based on our cost of debt, which includes U.S. industrial bond spreads, and cost of equity, which consists of U.S. Treasury Rates plus an equity risk premium. Another significant assumption is the terminal value that utilizes an assumed long-term growth rate, which incorporates management’s judgment regarding sustainable long-term growth of the reporting units.

Our annual goodwill impairment analysis included a comparison of the estimated fair value of the Company as a whole to our market capitalization. Management also compared the implied market multiple of the estimated fair value of each reporting unit to midstream industry transaction multiples and considered other market indicators to support the appropriateness of the fair value estimates.

49

We performed our annual impairment test as of October 1, 2023 and determined that the estimated fair value of each reporting unit exceeded its carrying value, and no impairment existed. The results of the impairment test are as follows as of the October 1, 2023 valuation date:

Reporting Unit	Goodwill		Weighted Average Costs of Capital		Fair Value Reduction % (a)		Valuation Methodology (b)
	(millions)
Pipeline	$	53	9.4	%	42	%	DCF
Gathering	420		9.6	%	9	%	DCF
	$	473

_________________________________

(a) Percentage by which the estimated fair value of the reporting unit would need to decline to equal its carrying value including goodwill. The fair value reduction percentage for the Gathering reporting unit increased 1% as compared to the October 1, 2022 annual impairment test, principally due to a slight reduction in the Gathering reporting unit net book value, partially offset by an increased WACC. The WACC increase was driven by the increased U.S. Treasury Rates during 2023.

(b) Discounted cash flows (DCF) incorporated 2023 (fourth quarter) through 2027 projected cash flows plus a calculated terminal value. We calculated the terminal-year cash flows using an estimated long-term growth rate of 2.0%, discounted at the WACC for each of the reporting units.

In between annual impairment tests, we monitor our estimates and assumptions regarding estimated future cash flows, including the impact of movements in market indicators, and will update the impairment analysis if a triggering event occurs. While we believe the estimates and assumptions in the fair value are reasonable, the actual results may differ from projections. To the extent projected results or cash flows are revised downward, the reporting unit may be required to write down all or a portion of its goodwill, which would adversely impact our earnings. If current expectations of future long-term growth are not met or market factors outside of our control change, such as U.S. Treasury Rates or a decline in midstream industry transaction multiples, this may lead to a goodwill impairment in the future. See Part II, Item 7A., "Quantitative and Qualitative Disclosures About Market Risk", in this Form 10-K for more information on our exposure to market risk.

Assessment of Long-Lived Assets for Impairment

We evaluate the carrying value of long-lived assets, excluding goodwill, when circumstances indicate that the carrying value of those assets may not be recoverable. Conditions that could have an adverse impact on the cash flows and fair value of the long-lived assets are a deteriorating business climate, condition of the asset, or plans to dispose of or abandon the asset before the end of its useful life, which could result from the loss of or reduction in volume from our customers. The review of long-lived assets for impairment requires significant assumptions about operating strategies and estimates of future cash flows, which require assessments of current and projected market conditions and anticipated customer revenues. An impairment evaluation is based on an undiscounted cash flow analysis at the lowest level for which independent cash flows of long-lived assets can be identified from other groups of assets and liabilities. Impairment may occur when the carrying value of the asset exceeds the future undiscounted cash flows. When the undiscounted cash flow analysis indicates a long-lived asset is not recoverable, the amount of the impairment loss is determined by measuring the excess of the long-lived asset over its fair value. An impairment would require us to reduce both the long-lived asset and current period earnings by the amount of the impairment, which would adversely impact our earnings. As part of our ongoing reviews of business operations and associated long-lived assets, we did not identify any indicators of impairment that existed during 2023.

Assessment of Equity Method Investments for Impairment

We assess at each balance sheet date whether there is objective evidence that the equity method investment is impaired by completing a quantitative or qualitative analysis of factors impacting the investment. If there is objective evidence of impairment, we determine whether the decline below carrying value is other than temporary. If the decline is determined to be other than temporary, an impairment charge is recorded in earnings with an offsetting reduction to the carrying value of the investment. As part of our ongoing reviews of equity method investment operations, we did not identify any indicators of impairment that existed during 2023.

NEW ACCOUNTING PRONOUNCEMENTS

See Note 3, "New Accounting Pronouncements" to the Consolidated Financial Statements under Part II, Item 8 of this Form 10-K.

50

Item 7A. Quantitative and Qualitative Disclosures About Market Risk

Market Price Risk

Our business is dependent on the continued availability of natural gas production and reserves in our geographical areas of operation. Low prices for natural gas, including those resulting from regional basis differentials, could adversely affect development of additional reserves and future natural gas production that is accessible by our pipeline and storage assets. We manage our exposure through the use of short, medium, and long-term transportation, gathering, and storage contracts. Consequently, our existing operations and cash flows have limited direct exposure to natural gas price risk.

Credit Risk

We are exposed to credit risk, which is the risk of loss resulting from nonpayment or nonperformance under a contract. We manage our exposure to credit risk associated with customers through credit analysis, credit approval, credit limits and monitoring procedures. For certain transactions, we may request letters of credit, cash collateral, prepayments or guarantees as forms of credit support. Our FERC tariffs require tariff customers that do not meet specified credit standards to provide three months of credit support, however, we are exposed to credit risk beyond this three-month period when our tariffs do not require our customers to provide additional credit support. For some long-term contracts associated with gathering system construction or expansion, we have entered into negotiated credit agreements that provide for enhanced forms of credit support if certain customer credit standards are not met.

We depend on a key customer, Southwestern Energy, in the Haynesville formation in the Gulf Coast and in the Utica and Marcellus formations in the Northeastern U.S. for a significant portion of our revenues. The loss of, or reduction in volumes from, this key customer could result in a decline in demand for our services and materially adversely affect our business, financial condition and results of operations.

We engage with customers that are sub-investment grade, including our key customer, Southwestern Energy. These customers are otherwise considered creditworthy or are required to make prepayments or provide security to satisfy credit concerns. We regularly monitor for bankruptcy proceedings that may impact our customers and had no bankruptcy proceedings during the year ended December 31, 2023.

Interest Rate Risk

We are subject to interest rate risk in connection with the issuance of debt. Our exposure to interest rate risk arises primarily from changes in SOFR. As of December 31, 2023, we had floating rate debt of $564 million related to the variable rate Term Loan Facility and borrowings outstanding under our Revolving Credit Facility, and a floating rate debt-to-total debt ratio of 17%. See Note 10, "Debt" to the Consolidated Financial Statements under Part II, Item 8 of this Form 10-K.

We are subject to interest rate risk in connection with our goodwill impairment assessment. See "Critical Accounting Estimates" under Part II, Item 7 of this Form 10-K.

Summary of Sensitivity Analysis

A sensitivity analysis was performed on the fair values of our long-term debt obligations. The sensitivity analysis involved increasing and decreasing interest rates as of December 31, 2023 by a hypothetical 10% and calculating the resulting change in the fair values. The hypothetical losses related to long-term debt would be realized only if we transferred all of our fixed-rate long-term debt to other creditors. The results of the sensitivity analysis are as follows:

	Assuming a 10% Increase in Rates		Assuming a 10% Decrease in Rates		Change in the Fair Value of
Activity	As of December 31, 2023
	(millions)
Interest rate risk	$	(82)	$	85	Long-term debt

51

Item 8. Financial Statements

The following Consolidated Financial Statements are included herein:

	Page
Report of Independent Registered Public Accounting Firm (PCAOB ID 238)	53
Consolidated Statements of Operations	55
Consolidated Statements of Comprehensive Income	56
Consolidated Statements of Financial Position	57
Consolidated Statements of Cash Flows	59
Consolidated Statements of Changes in Stockholders' Equity/Member's Equity	60
Notes to Consolidated Financial Statements	61
Note 1 — Description of the Business and Basis of Presentation	61
Note 2 — Significant Accounting Policies	64
Note 3 — New Accounting Pronouncements	66
Note 4 — Revenue	66
Note 5 — Goodwill	69
Note 6 — Property, Plant, and Equipment and Intangible Assets	69
Note 7 — Income Taxes	70
Note 8 — Earnings Per Share and Dividends	73
Note 9 — Fair Value	74
Note 10 — Debt	75
Note 11 — Leases	77
Note 12 — Commitments and Contingencies	79
Note 13 — Stock-Based Compensation and Defined Contribution Plans	80
Note 14 — Segment and Related Information	83
Note 15 — Related Party Transactions	85
Note 16 — Subsequent Event	86

52

Report of Independent Registered Public Accounting Firm

To the Board of Directors and Stockholders of DT Midstream, Inc.

Opinions on the Financial Statements and Internal Control over Financial Reporting

We have audited the accompanying consolidated statements of financial position of DT Midstream, Inc. and its subsidiaries (the “Company”) as of December 31, 2023 and 2022, and the related consolidated statements of operations, of comprehensive income, of changes in stockholders' equity/member's equity and of cash flows for each of the three years in the period ended December 31, 2023, including the related notes (collectively referred to as the “consolidated financial statements”). We also have audited the Company's internal control over financial reporting as of December 31, 2023, based on criteria established in Internal Control - Integrated Framework (2013) issued by the Committee of Sponsoring Organizations of the Treadway Commission (COSO).

In our opinion, the consolidated financial statements referred to above present fairly, in all material respects, the financial position of the Company as of December 31, 2023 and 2022, and the results of its operations and its cash flows for each of the three years in the period ended December 31, 2023 in conformity with accounting principles generally accepted in the United States of America. Also in our opinion, the Company maintained, in all material respects, effective internal control over financial reporting as of December 31, 2023, based on criteria established in Internal Control - Integrated Framework (2013) issued by the COSO.

Basis for Opinions

The Company's management is responsible for these consolidated financial statements, for maintaining effective internal control over financial reporting, and for its assessment of the effectiveness of internal control over financial reporting, included in Management’s report on internal control over financial reporting appearing under Item 9A. Our responsibility is to express opinions on the Company’s consolidated financial statements and on the Company's internal control over financial reporting 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 audits to obtain reasonable assurance about whether the consolidated financial statements are free of material misstatement, whether due to error or fraud, and whether effective internal control over financial reporting was maintained in all material respects.

Our audits of the consolidated financial statements 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 audits 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. Our audit of internal control over financial reporting included obtaining an understanding of internal control over financial reporting, assessing the risk that a material weakness exists, and testing and evaluating the design and operating effectiveness of internal control based on the assessed risk. Our audits also included performing such other procedures as we considered necessary in the circumstances. We believe that our audits provide a reasonable basis for our opinions.

53

Definition and Limitations of Internal Control over Financial Reporting

A company’s internal control over financial reporting is a process designed to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles. A company’s internal control over financial reporting includes those policies and procedures that (i) pertain to the maintenance of records that, in reasonable detail, accurately and fairly reflect the transactions and dispositions of the assets of the company; (ii) provide reasonable assurance that transactions are recorded as necessary to permit preparation of financial statements in accordance with generally accepted accounting principles, and that receipts and expenditures of the company are being made only in accordance with authorizations of management and directors of the company; and (iii) provide reasonable assurance regarding prevention or timely detection of unauthorized acquisition, use, or disposition of the company’s assets that could have a material effect on the financial statements.

Because of its inherent limitations, internal control over financial reporting may not prevent or detect misstatements. Also, projections of any evaluation of effectiveness to future periods are subject to the risk that controls may become inadequate because of changes in conditions, or that the degree of compliance with the policies or procedures may deteriorate.

Critical Audit Matters

The critical audit matter communicated below is a matter arising from the current period audit of the consolidated financial statements that was communicated or required to be communicated to the audit committee and that (i) relates to accounts or disclosures that are material to the consolidated financial statements and (ii) involved our especially challenging, subjective, or complex judgments. The communication of critical audit matters does not alter in any way our opinion on the consolidated financial statements, taken as a whole, and we are not, by communicating the critical audit matter below, providing a separate opinion on the critical audit matter or on the accounts or disclosures to which it relates.

Equity Method Investments in NEXUS Gas Transmission, LLC and Millennium Pipeline Company, LLC

As described in Note 1 to the consolidated financial statements, non-controlled investments are accounted for using the equity method of accounting when the Company is able to significantly influence the operating policies of the investee. Under the equity method of accounting, investments are recorded at historical cost as an asset and adjusted for capital contributions, dividends and distributions received, and the Company’s share of the investee’s earnings or losses, which are recorded as earnings from equity method investees. The Company’s equity method investments are periodically evaluated for certain factors that may be indicative of other-than-temporary impairment. As of December 31, 2023, the Company’s equity method investment balance in NEXUS Gas Transmission, LLC (“NEXUS”) and Millennium Pipeline Company, LLC (“Millennium”) was $900 million and $727 million, respectively. For the year ended December 31, 2023, earnings from equity method investees were $177 million, of which earnings from NEXUS and Millennium were the majority.

The principal consideration for our determination that performing procedures relating to the equity method investments in NEXUS and Millennium is a critical audit matter is a high degree of auditor effort in performing procedures related to these equity method investments.

Addressing the matter involved performing procedures and evaluating audit evidence in connection with forming our overall opinion on the consolidated financial statements. These procedures included testing the effectiveness of controls relating to equity method investments. These procedures also included, among others, the following, which were performed as of and for the year ended December 31, 2023 for NEXUS and Millennium (collectively “the investees”): (i) vouching capital contributions, dividends and distributions to source documents, (ii) confirming specific unaudited financial information with the investees, (iii) reconciling the investee financial information per Company records to the investees’ independently audited financial statements, (iv) recalculating the Company’s carrying amount of its investments in the investees that exceeded the Company’s share of the underlying equity in the net assets and the related amortization of such differences, (v) performing inquiries with management and investee auditors, and inspecting supporting evidence and documentation, to understand and evaluate management’s consideration of accounting matters, including management’s assertion that there were no indicators of other-than-temporary impairment, and (vi) performing procedures to evaluate subsequent events impacting the investees.

/s/ PricewaterhouseCoopers LLP

Detroit, Michigan

February 16, 2024

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

54

DT Midstream, Inc.

Consolidated Statements of Operations

	Year Ended December 31,
	2023		2022		2021
	(millions, except per share amounts)
Revenues
Operating revenues	$	922	$	920	$	840
Operating Expenses
Operation and maintenance	245		267		231
Depreciation and amortization	182		170		166
Taxes other than income	28		28		24
Asset (gains) losses and impairments, net	(4)		(23)		17
Operating Income	471		478		402
Other (Income) and Deductions
Interest expense	150		137		112
Interest income	(1)		(3)		(4)
Earnings from equity method investees	(177)		(150)		(126)
Loss from financing activities	—		13		—
Other (income) and expense	(1)		(1)		(2)
Income Before Income Taxes	500		482		422
Income Tax Expense	104		100		104
Net Income	396		382		318
Less: Net Income Attributable to Noncontrolling Interests	12		12		11
Net Income Attributable to DT Midstream	$	384	$	370	$	307
Basic Earnings per Common Share
Net Income Attributable to DT Midstream	$	3.97	$	3.83	$	3.17
Diluted Earnings per Common Share
Net Income Attributable to DT Midstream	$	3.94	$	3.81	$	3.16
Weighted Average Common Shares Outstanding
Basic	96.9		96.7		96.7
Diluted	97.5		97.2		96.9

See Notes to Consolidated Financial Statements

55

DT Midstream, Inc.

Consolidated Statements of Comprehensive Income

	Year Ended December 31,
	2023		2022		2021
	(millions)
Net Income	$	396	$	382	$	318
Foreign currency translation and unrealized gain on derivatives, net of tax	2		—		1
Other comprehensive income	2		—		1
Comprehensive income	398		382		319
Less: Comprehensive income attributable to noncontrolling interests	12		12		11
Comprehensive Income Attributable to DT Midstream	$	386	$	370	$	308

See Notes to Consolidated Financial Statements

56

DT Midstream, Inc.

Consolidated Statements of Financial Position

	December 31,
	2023		2022
	(millions)
ASSETS
Current Assets
Cash and cash equivalents	$	56	$	61
Accounts receivable (net of $— allowance for expected credit loss for each period end)	154		161
Deferred property taxes	31		22
Taxes receivable	15		—
Prepaid expenses and other	16		18
	272		262
Investments
Investments in equity method investees	1,762		2,200
Property
Property, plant, and equipment	5,282		4,534
Accumulated depreciation	(848)		(728)
	4,434		3,806
Other Assets
Goodwill	473		473
Long-term notes receivable — related party	4		4
Operating lease right-of-use assets	38		31
Intangible assets, net	1,968		2,025
Other	31		32
	2,514		2,565
Total Assets	$	8,982	$	8,833

See Notes to Consolidated Financial Statements

57

DT Midstream, Inc.

Consolidated Statements of Financial Position

	December 31,
	2023		2022
	(millions, except shares)
LIABILITIES AND EQUITY
Current Liabilities
Accounts payable	$	94	$	119
Short-term borrowings	165		330
Operating lease liabilities	13		16
Dividends payable	67		62
Interest payable	10		10
Property taxes payable	34		29
Accrued compensation	18		20
Contract liabilities	18		4
Other	15		24
	434		614
Long-Term Debt, net	3,065		3,059
Other Liabilities
Deferred income taxes	1,031		923
Operating lease liabilities	27		19
Contract liabilities	111		28
Other	34		36
	1,203		1,006
Total Liabilities	4,702		4,679
Commitments and Contingencies (Note 12)
Stockholders' Equity
Preferred stock ($0.01 par value, 50,000,000 shares authorized, and no shares issued or outstanding as of December 31, 2023 and 2022)	—		—
Common stock ($0.01 par value, 550,000,000 shares authorized, and 96,971,021 and 96,754,549 shares issued and outstanding as of December 31, 2023 and 2022, respectively)	1		1
Additional paid-in capital	3,485		3,469
Retained earnings	661		547
Accumulated other comprehensive income (loss)	(8)		(10)
Total DT Midstream Equity	4,139		4,007
Noncontrolling interests	141		147
Total Equity	4,280		4,154
Total Liabilities and Equity	$	8,982	$	8,833

See Notes to Consolidated Financial Statements

58

DT Midstream, Inc.

Consolidated Statements of Cash Flows

	Year Ended December 31,
	2023		2022		2021
	(millions)
Operating Activities
Net Income	$	396	$	382	$	318
Adjustments to reconcile Net Income to Net cash and cash equivalents from operating activities:
Depreciation and amortization	182		170		166
Stock-based compensation	20		17		12
Amortization of operating lease right-of-use assets	18		19		18
Deferred income taxes	110		70		104
Earnings from equity method investees	(177)		(150)		(126)
Dividends from equity method investees	196		181		129
Asset (gains) losses and impairments, net	—		(17)		17
Loss from financing activities	—		13		—
Changes in assets and liabilities:
Accounts receivable, net	7		8		(43)
Accounts payable — third party	(5)		7		4
Accounts payable — related party	—		—		(10)
Contract liabilities	97		3		6
Other current and noncurrent assets and liabilities	(46)		22		(23)
Net cash and cash equivalents from operating activities	798		725		572
Investing Activities
Plant and equipment expenditures	(772)		(338)		(140)
Proceeds from sale of notes receivable	—		22		—
Distributions from equity method investees	427		17		9
Contributions to equity method investees	(7)		(5)		(11)
Acquisition of additional interest in equity method investee	—		(552)		—
Notes receivable repaid by DTE Energy	—		—		263
Other investing activities	1		2		2
Net cash and cash equivalents from (used for) investing activities	(351)		(854)		123
Financing Activities
Issuance of long-term debt, net of discount and issuance costs	—		591		3,047
Repayment of long-term debt	—		(596)		(5)
Repayment of short-term borrowings from DTE Energy	—		—		(3,175)
Borrowings under the Revolving Credit Facility	540		370		25
Repayment of borrowings under the Revolving Credit Facility	(705)		(40)		(25)
Payment of Revolving Credit Facility issuance costs	—		(3)		(7)
Repurchase of common stock	—		(3)		—
Distributions to noncontrolling interests	(18)		(14)		(16)
Dividends paid on common stock	(263)		(244)		(58)
Dividend to DTE Energy	—		—		(501)
Contributions from DTE Energy	—		—		110
Other financing activities	(6)		(3)		—
Net cash and cash equivalents from (used for) financing activities	(452)		58		(605)
Net Increase (Decrease) in Cash and Cash Equivalents	(5)		(71)		90
Cash and Cash Equivalents at Beginning of Period	61		132		42
Cash and Cash Equivalents at End of Period	$	56	$	61	$	132
Supplemental disclosure of cash information
Cash paid for:
Interest, net of interest capitalized	$	140	$	125	$	103
Income taxes	22		24		3
Supplemental disclosure of non-cash investing and financing activities
Plant and equipment expenditures in accounts payable and other accrued liabilities	$	80	$	99	$	10

See Notes to Consolidated Financial Statements

59

DT Midstream, Inc.

Consolidated Statements of Changes in Stockholders' Equity/Member's Equity

				Additional Paid-In Capital		Retained Earnings		Accumulated Other Comprehensive Income (Loss)		Noncontrolling Interests
	Common Stock
	Shares	Amount										Total
	(dollars in millions, shares in thousands)
Balance, December 31, 2020	—	$	—	$	3,333	$	751	$	(11)	$	155	$	4,228
Net Income	—	—		—		307		—		11		318
Reorganization to C Corporation(a)	1	—		—		—		—		—		—
Issuance of common shares to DTE Energy(b)	96,731	1		—		—		—		—		1
Dividend to DTE Energy	—	—		—		(501)		—		—		(501)
Dividends declared on common stock ($1.20 per common share)	—	—		—		(116)		—		—		(116)
Distributions to noncontrolling interests	—	—		—		—		—		(16)		(16)
Stock-based compensation	2	—		8		—		—		—		8
Taxes and other adjustments	—	—		109		(10)		—		(1)		98
Other comprehensive income, net of tax	—	—		—		—		1		—		1
Balance, December 31, 2021	96,734	$	1	$	3,450	$	431	$	(10)	$	149	$	4,021
Net Income	—	—		—		370		—		12		382
Dividends declared on common stock ($2.56 per common share)	—	—		—		(248)		—		—		(248)
Distributions to noncontrolling interests	—	—		—		—		—		(14)		(14)
Stock-based compensation	78	—		17		(2)		—		—		15
Repurchase of common stock	(57)	—		—		(3)		—		—		(3)
Taxes and other adjustments	—	—		2		(1)		—		—		1
Balance, December 31, 2022	96,755	$	1	$	3,469	$	547	$	(10)	$	147	$	4,154
Net Income	—	—		—		384		—		12		396
Dividends declared on common stock ($2.76 per common share)	—	—		—		(268)		—		—		(268)
Distributions to noncontrolling interests	—	—		—		—		—		(18)		(18)
Stock-based compensation and other	216	—		16		(2)		—		—		14
Other comprehensive income, net of tax	—	—		—		—		2		—		2
Balance, December 31, 2023	96,971	$	1	$	3,485	$	661	$	(8)	$	141	$	4,280

_____________________________________

(a)Issuance of common shares at $0.01 par value upon conversion to C Corporation from a single member LLC.

(b)Issuance of common shares to DTE Energy in anticipation of the Separation.

See Notes to Consolidated Financial Statements

60

DT Midstream, Inc.

Notes to Consolidated Financial Statements

NOTE 1 — DESCRIPTION OF THE BUSINESS AND BASIS OF PRESENTATION

Description of the Business

DT Midstream is an owner, operator, and developer of an integrated portfolio of natural gas midstream assets. We provide multiple, integrated natural gas services to customers through two segments: (i) Pipeline, which includes interstate pipelines, intrastate pipelines, storage systems, lateral pipelines including related treatment plants and compression and surface facilities, and (ii) Gathering, which includes gathering systems, related treatment plants, and compression and surface facilities. Our Pipeline segment also includes joint venture interests in equity method investees which own and operate interstate pipelines that connect to our wholly owned assets.

Our core assets strategically connect key demand centers in the Midwestern U.S., Eastern Canada and Northeastern U.S. regions to the premium production areas of the Marcellus/Utica natural gas formation in the Appalachian Basin, and connect key demand centers and LNG export terminals in the Gulf Coast region to premium production areas of the Haynesville natural gas formation.

In connection with the Separation from DTE Energy, on January 13, 2021, DTE Gas Enterprises, LLC, and its consolidated subsidiaries converted into a Delaware corporation pursuant to a statutory conversion and changed its name to DT Midstream, Inc. ("DT Midstream"). At the conversion, DT Midstream issued 1,000 shares of common stock at $0.01 par value to its parent, a subsidiary of DTE Energy. As DT Midstream was a single member LLC as of December 31, 2020, and a corporation with stockholders' equity as of December 31, 2023, 2022 and 2021, Consolidated Statements of Changes in Stockholders' Equity/Member's Equity are presented as of December 31, 2023, 2022, and 2021. In June 2021, the DT Midstream Board of Directors authorized the issuance of an additional 96,731,466 common shares in anticipation of the Separation, for a total of 96,732,466 common shares issued and outstanding. DT Midstream is authorized to issue 50,000,000 shares of preferred stock at $0.01 par value. No preferred stock was issued or outstanding as of December 31, 2023 and 2022.

On July 1, 2021, DTE Energy completed the Separation through the distribution of 96,732,466 shares of DT Midstream common stock to DTE Energy shareholders. Following the Separation on July 1, 2021, DT Midstream became an independent public company listed under the symbol "DTM" on the NYSE. DTE Energy did not retain ownership in DT Midstream.

Basis of Presentation

The Consolidated Financial Statements and Notes to Consolidated Financial Statements as of and for the periods presented subsequent to July 1, 2021, the date of the Separation, reflect the consolidated financial position, results of operations and cash flows for DT Midstream as an independent company. Prior to the Separation, we operated as a consolidated entity of DTE Energy and not as a standalone company. For the periods prior to the Separation, the Consolidated Financial Statements and Notes to Consolidated Financial Statements were prepared on a carve-out basis using the consolidated financial statements and accounting records of DTE Energy. The carve-out basis financial statements represent our historical financial position, results of operations, and cash flows as they were historically managed in accordance with GAAP and reflect significant assumptions and allocations. The carve-out financial statements may not include all expenses that would have been incurred had we existed as a standalone entity.

GAAP requires management to use estimates and assumptions that impact reported amounts of assets, liabilities, revenues and expenses, and the disclosure of contingent assets and liabilities. Actual results may differ from our estimates. We believe the assumptions underlying these financial statements are reasonable.

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DT Midstream, Inc.

Notes to Consolidated Financial Statements

Cash Management

Our sources of liquidity include cash generated from operations and available borrowings under our Revolving Credit Facility.

Prior to the Separation, our sources of liquidity included cash generated from operations and loans obtained through DTE Energy’s corporate-wide cash management program, including a working capital loan agreement. Cash was managed centrally, with certain net earnings reinvested in, and working capital requirements met from, existing liquid funds. Effective July 1, 2021, we no longer participated in the cash management program and the working capital loan was terminated.

Principles of Consolidation

We consolidate all majority-owned subsidiaries and investments in entities in which we have a controlling influence. Non-controlled investments are accounted for using the equity method of accounting when we are able to significantly influence the operating policies of the investee. When we do not influence the operating policies of an investee, the equity investment is measured at fair value, if readily determinable, or if not readily determinable, at cost less impairment, if applicable. We eliminate all intercompany balances and transactions.

We evaluate whether an entity is a VIE whenever reconsideration events occur. We consolidate VIEs for which we are the primary beneficiary. If we are not the primary beneficiary and an ownership interest is held, the VIE is accounted for under the equity method of accounting. When assessing the determination of the primary beneficiary, we consider all relevant facts and circumstances, including: the power, through voting or similar rights, to direct the activities of the VIE that most significantly impact the VIE's economic performance and the obligation to absorb the expected losses and/or the right to receive the expected returns of the VIE. We perform ongoing reassessments of all VIEs to determine if the primary beneficiary status has changed.

We own an 85% interest in the Stonewall VIE and are the primary beneficiary, therefore Stonewall is consolidated. We own a 50% interest in the South Romeo VIE and are the primary beneficiary, therefore South Romeo is consolidated.

The following table summarizes the major line items in the Consolidated Statements of Financial Position for consolidated VIEs as of December 31, 2023 and 2022. All assets and liabilities of a consolidated VIE are included in the table when it has been determined that a consolidated VIE has either (1) assets that can be used only to settle obligations of the VIE or (2) liabilities for which creditors do not have recourse to the general credit of the primary beneficiary. The assets and liabilities of consolidated VIEs that meet the definition of a business and whose assets can be used for purposes other than the settlement of the VIEs' obligations have been excluded from the table below.

	December 31,
	2023		2022
	(millions)
ASSETS (a)
Cash	$	13	$	27
Accounts receivable	10		9
Other current assets	2		3
Intangible assets, net	483		498
Property, plant and equipment, net	391		403
Goodwill	25		25
	$	924	$	965
LIABILITIES (a)
Accounts payable and other current liabilities	$	4	$	4
Other noncurrent liabilities	3		4
	$	7	$	8

_____________________________________

(a)Amounts shown are 100% of the consolidated VIEs' assets and liabilities.

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DT Midstream, Inc.

Notes to Consolidated Financial Statements

We had a variable interest in an investment in certain assets in the Utica Shale region that was accounted for as a Note receivable — third party. We did not have an ownership interest in the entity and were not the primary beneficiary. This investment was sold during the second quarter 2022. See Note 2, "Significant Accounting Policies – Financing Receivables" to the Consolidated Financial Statements for additional discussion.

Related Parties

Transactions between DT Midstream and DTE Energy prior to the Separation, as well as transactions between us and our equity method investees, have been presented as related party transactions in the accompanying Consolidated Financial Statements. See Note 15, "Related Party Transactions" to the Consolidated Financial Statements.

Equity Method Investments

Non-controlled investments are accounted for using the equity method of accounting when we are able to significantly influence the operating policies of the investee. Under the equity method of accounting, investments are recorded at historical cost as an asset and adjusted for capital contributions, dividends and distributions received, and our share of the investee's earnings or losses, which are recorded as earnings from equity method investees on the Consolidated Statements of Operations. Our equity method investments are periodically evaluated for certain factors that may be indicative of other-than-temporary impairment. As of December 31, 2023 and 2022, our carrying amounts of investments in equity method investees exceeded our share of the underlying equity in the net assets of the investees by $352 million and $368 million, respectively. The difference will be amortized over the life of the underlying assets. As of December 31, 2023 and 2022, our consolidated retained earnings balance includes undistributed earnings from equity method investments of zero and $43 million, respectively. We use the cumulative earnings approach to classify proceeds received from equity method investees as dividends or distributions on the Consolidated Statements of Cash Flows.

Equity method investees are described below:

	Investments As of				% Owned As of
	December 31,				December 31,
Equity Method Investee	2023		2022		2023	2022
	(millions)
NEXUS	$	900	$	1,313	50%	50%
Vector	135		135		40%	40%
Millennium	727		752		52.5%	52.5%
Total investments in equity method investees	$	1,762	$	2,200

In May 2023, NEXUS closed on the sale of $750 million of senior unsecured notes with a weighted-average coupon rate of 5.52%. We received a distribution from NEXUS of $371 million, net of fees and expenses, which reduced our investment balance. We used the proceeds from the distribution to repay borrowings outstanding under our Revolving Credit Facility.

In October 2022, DT Midstream closed on the $552 million purchase of an additional 26.25% ownership interest in Millennium from National Grid. The transaction was financed with cash on hand and available capacity under the Company's Revolving Credit Facility. The purchase constituted National Grid's full ownership interest in Millennium and brought our total ownership interest in Millennium to 52.5%. We account for our ownership interest in Millennium under the equity method of accounting. Millennium is not a VIE and we do not have a controlling interest due to shared control with our partner over all of Millennium's significant business activities. Our carrying amount of our Millennium investment exceeded our share of the underlying equity in the net assets of Millennium by $343 million on the acquisition date.

63

DT Midstream, Inc.

Notes to Consolidated Financial Statements

The following tables present summarized financial information of our non-consolidated equity method investees. The amounts included below represent 100% of the results of continuing operations of such entities, including the portion owned by other parties.

Summarized balance sheet data is as follows:

	December 31,
	2023		2022
	(millions)
Current assets	$	159	$	198
Noncurrent assets	4,057		4,160
Current liabilities	208		206
Noncurrent liabilities	$	1,177	$	476

Summarized income statement data is as follows:

	Year Ended December 31,
	2023		2022		2021
	(millions)
Operating revenues	$	823	$	800	$	738
Operating expenses	377		396		371
Net Income	$	392	$	372	$	333

NOTE 2 — SIGNIFICANT ACCOUNTING POLICIES

Cash and Cash Equivalents

Cash and cash equivalents include cash in banks and highly liquid money market investments with remaining maturities of three months or less, when purchased. Cash equivalents are stated at cost, which approximates fair value.

Financing Receivables

Financing receivables are primarily composed of trade accounts receivable and notes receivable, which are stated at net realizable value.

We regularly monitor the credit quality of our financing receivables by reviewing counterparty credit quality indicators and monitoring for triggering events, such as a credit rating downgrade or bankruptcy. We have three internal grades of credit quality, with internal grade 1 as the lowest risk and internal grade 3 as the highest risk. The related credit quality indicators and risk ratings utilized to develop the internal grades have been updated through December 31, 2023. As of December 31, 2023, the Notes receivable — related party of $4 million, which originated prior to 2021, was classified as internal grade 1. There are no notes receivable on nonaccrual status and no past due financing receivables as of December 31, 2023.

Notes receivable are typically considered delinquent (past due) when payment is not received for periods ranging from 60 to 120 days. We cease accruing interest income (nonaccrual status) and may either write off or establish an allowance for expected credit loss for the note receivable when it is expected that all contractual principal or interest amounts due will not be collected. In determining an allowance for expected credit losses for or the write off of notes receivable, we consider the historical payment experience and other factors that are expected to have a specific impact on collection, including existing and future economic conditions. Cash receipts for notes receivable on nonaccrual status that do not bring the account contractually current are first applied to contractually owed past due interest, with any remainder applied to principal. Recognition of interest income is generally resumed when the note receivable becomes contractually current.

64

DT Midstream, Inc.

Notes to Consolidated Financial Statements

We had an investment in certain assets in the Utica Shale region which was accounted for as a note receivable — third party. In the second quarter 2021, we assessed the note receivable for expected loss and recorded a $19 million loss on the note receivable to Asset (gains) losses and impairments, net on the Consolidated Statement of Operations. Additionally, we ceased accruing interest on the note receivable balance and reclassified the note to an Internal grade 3 receivable. Subsequently, as cash payments were received, a portion was recognized as interest income. A third party purchased our investment in certain assets in the Utica Shale region based on significantly improved commodity pricing during the second quarter 2022 for proceeds of $22 million. This resulted in a gain of $17 million recorded in Asset (gains) losses and impairments, net on the Consolidated Statement of Operations. We maintain no continuing involvement with the note receivable.

For trade accounts receivable, the customer allowance for expected credit loss is calculated based on specific review of future collections based on receivable balances generally in excess of 30 days. Existing and future economic conditions, historical loss rates, customer trends and other relevant factors that may affect our ability to collect are also considered. Receivables are written off on a specific identification basis and determined based on the particular circumstances of the associated receivable. Uncollectible expense (recovery) was zero for each of the years ended December 31, 2023, 2022 and 2021. Our collections on accounts receivable from customers are current, and no material rate of historical loss was noted, which resulted in no allowance for expected credit loss as of December 31, 2023 or 2022.

The following table presents a roll-forward of the activity for the notes receivables' allowance for expected credit loss. The balance, if any, is shown as a deduction from the notes receivables' balance in the Consolidated Statements of Financial Position.

	2023		2022		2021
Allowance for expected credit loss- Notes Receivable	(millions)
Balance as of January 1	$	—	$	—	$	—
Additions: Charged to costs, expenses, and other accounts	—		—		19
Deductions: Current period provision and write-offs charged against allowance	—		—		(19)
Balance as of December 31	$	—	$	—	$	—

Property, Plant, and Equipment

Property is stated at cost and includes construction-related labor, materials, and overhead. Expenditures for maintenance and repairs are charged to expense when incurred. Property, plant and equipment is depreciated over its estimated useful life using the straight-line method. See Note 6, "Property, Plant, and Equipment and Intangible Assets" to the Consolidated Financial Statements.

Intangible Assets

Intangible assets with finite useful lives are amortized on a straight-line basis over the periods benefited. See Note 6, "Property, Plant, and Equipment and Intangible Assets" to the Consolidated Financial Statements.

Long-Lived Assets

Long-lived assets are reviewed for impairment whenever events or changes in circumstances indicate the carrying amount of an asset may not be recoverable. If the carrying amount of the asset exceeds the expected undiscounted future cash flows generated by the asset, an impairment loss is recognized resulting in the asset being written down to its estimated fair value. Assets to be disposed of are reported at the lower of the carrying amount or fair value, less costs to sell.

Operation and Maintenance

Operation and maintenance is primarily comprised of costs for labor and employee benefits, outside services, materials, compression, purchased natural gas, operating lease costs, office costs, and other operating and maintenance costs. For the year ended December 31, 2021, general corporate expense allocations from DTE Energy of $32 million, including $20 million of Separation-related transaction costs for legal, accounting, auditing and other professional services DTE Energy incurred for the benefit of DT Midstream, were also included in operation and maintenance. Effective July 1, 2021, with the completion of the Separation, we no longer received corporate allocations from DTE Energy.

65

DT Midstream, Inc.

Notes to Consolidated Financial Statements

Depreciation and Amortization

Depreciation and amortization is related to Property, plant and equipment and Customer relationships and other intangible assets, net, used in our transportation, storage and gathering businesses.

Other Accounting Policies

Footnote	Title
Note 4	Revenue
Note 7	Income Taxes
Note 9	Fair Value
Note 11	Leases

NOTE 3 — NEW ACCOUNTING PRONOUNCEMENTS

Recently Issued Pronouncements

In November 2023, the FASB issued ASU No. 2023-07, Segment Reporting (Topic 280) - Improvements to Reportable Segment Disclosures. The amendments improve reportable segment disclosure requirements, primarily through enhanced disclosures about significant segment expenses and interim disclosure requirements. The amendments are effective for fiscal years beginning after December 15, 2023 and interim periods within fiscal years beginning after December 15, 2024. Early adoption is permitted. The adoption of this standard is not expected to have a significant impact on our Consolidated Financial Statements.

In December 2023, the FASB issued ASU No. 2023-09, Income Taxes (Topic 740) - Improvements to Income Tax Disclosures. The amendments improve transparency of income tax disclosure requirements, primarily through enhanced disclosures of rate reconciliation and income taxes paid. The amendments are effective for annual periods beginning after December 15, 2024. Early adoption is permitted. The adoption of this standard is not expected to have a significant impact on our Consolidated Financial Statements.

NOTE 4 — REVENUE

Significant Accounting Policy – Revenue

Pipeline revenues consist of services related to the gathering, transportation and/or storage of natural gas. Gathering revenues consist of services related to the gathering, processing, and/or treating of natural gas. Revenue is measured based upon the pricing or consideration for such services specified in the contract with a customer. Consideration may consist of both fixed components including fixed demand charges and fixed deficiency fee rates for MVCs, and variable components including fixed rates for the actual volumes flowed under interruptible services and other associated fees.

Our contracts with customers generally contain a single performance obligation, which is a promise to deliver either a distinct service or a series of distinct services to the customer. When multiple performance obligations exist, the contract consideration is allocated between the performance obligations based on the relative standalone selling price, which is determined by prices charged to customers or the adjusted market assessment approach. The adjusted market assessment approach involves evaluating the market in which we sell services and estimating the price that a customer in that market would be willing to pay.

Revenue is recognized when performance obligations are satisfied by delivering a service to a customer, which occurs when the service is provided to the customer. When a customer simultaneously receives and consumes the service provided, revenue is recognized over time. Alternatively, if it is determined that the criteria for recognition of revenue over time is not met, the revenue is considered to be recognized at a point in time. Our revenues, including estimated unbilled amounts, are generally recognized over time as actual services are provided, or ratably over time when providing a stand-ready service. Unbilled amounts are generally determined using preliminary meter data volumes and contracted pricing, and typically result in minor adjustments. Generally, uncertainties in the variable consideration components are resolved and revenue amounts are known at the time of recognition. We have determined that the above methods represent a faithful depiction of delivering a service to the customer. Revenues are typically billed and consideration received monthly, however, certain deficiency fees related to MVCs are billed quarterly or annually.

66

DT Midstream, Inc.

Notes to Consolidated Financial Statements

Disaggregation of Revenue

The following is a summary of revenues disaggregated by segment:

	Year Ended December 31,
	2023		2022		2021
	(millions)
Pipeline (a)	$	377	$	339	$	307
Gathering	545		581		534
Elimination of Inter-segment Revenue	—		—		(1)
Total operating revenues	$	922	$	920	$	840

__________________________________

(a)Includes revenues outside the scope of ASC 606 primarily related to contracts accounted for as leases of $7 million, $10 million and $9 million for the years ended December 31, 2023, 2022 and 2021, respectively.

Nature of Services

We primarily provide two types of revenue services: firm service and interruptible service. Firm service revenue contracts provide for fixed revenue commitments regardless of actual volumes of natural gas that flow, which leads to more stable operating performance, revenues and cash flows and limits our exposure to natural gas price fluctuations. Firm service revenue contracts are typically long-term and structured using fixed demand charges or MVCs with fixed deficiency fee rates. Contracts structured using fixed demand charges contain a performance obligation of a stand-ready series of distinct services that are substantially the same with the same pattern of transfer to the customer, therefore revenue is recognized ratably over time. Contracts structured using MVCs with fixed deficiency fee rates require customers to transport or store a minimum volume of natural gas over a specified time period. If a customer fails to meet its MVCs for the specified time period, the contract consideration includes a fixed rate for the actual volumes gathered, transported or stored, and a deficiency fee for the shortfall between the MVCs and the actual volumes gathered, transported, or stored. If a customer exceeds its MVC for the specified time period, the contract consideration is based on fixed rates for the actual volumes gathered, transported, or stored. The contract consideration is allocated to each distinct monthly performance obligation, consistent with the allocation objective and based upon the level of effort required to satisfy the service obligation. Revenues are generally recognized over time based on the output measure of natural gas volumes gathered, transported, or stored, with the recognition of the deficiency fee revenue in the period when it is known the customer cannot make up the deficient volumes in the specified time period. Interruptible service revenue contracts typically contain fixed rates, with total consideration dependent on actual natural gas volumes that flow. Interruptible service revenues are recognized over time based on the output measure of natural gas volumes gathered, transported, or stored. Certain of our gathering contracts allow for the recovery of production-related operating expenses, which are offsetting in revenue and operating expense. Recovery of production-related operating expenses were $53 million, $65 million and $38 million for the years ended December 31, 2023, 2022 and 2021, respectively.

Contract Liabilities

The following is a summary of contract liability activity:

	2023		2022
	(millions)
Balance as of January 1	$	32	$	28
Increases due to cash received or receivable, excluding amounts recognized as revenue during the period (a)	101		13
Revenue recognized that was included in the balance at the beginning of the period	(4)		(9)
Balance as of December 31	$	129	$	32

____________________________________

(a) During the year ended December 31, 2023, we collected prepayment amounts from customers under various long-term revenue contracts on Ohio Utica Gathering, Appalachia Gathering, Blue Union Gathering and LEAP.

Contract liabilities generally represent amounts paid by or receivable from customers for which the associated performance obligation has not yet been satisfied. Contract liabilities associated with these services are recognized upon delivery of the service to the customer.    

67

DT Midstream, Inc.

Notes to Consolidated Financial Statements

The following table presents contract liability amounts as of December 31, 2023 that are expected to be recognized as revenue in future periods:

	(millions)
2024	$	18
2025	20
2026	19
2027	18
2028	16
2029 and thereafter	38
Total	$	129

Transaction Price Allocated to the Remaining Performance Obligations

In accordance with optional exemptions available under Topic 606, we do not disclose the value of unsatisfied performance obligations for (1) contracts with an original expected length of one year or less, (2) with the exception of fixed consideration, contracts for which the amount of revenue recognized depends upon our invoices for actual volumes gathered, transported, or stored, and (3) contracts for which variable consideration relates entirely to an unsatisfied performance obligation.

Such contracts consist of various types of performance obligations, including providing midstream services. Contracts with variable volumes and/or variable pricing, including those with pricing provisions tied to a consumer price or other index, have also been excluded as the related contract consideration is variable at the contract inception. Contract lengths vary from cancellable to multi-year.

The following table presents revenue amounts related to fixed consideration associated with unsatisfied performance obligations as of December 31, 2023 that are expected to be recognized as revenue in future periods:

	(millions)
2024	$	131
2025	138
2026	109
2027	77
2028	52
2029 and thereafter	202
Total	$	709

Costs to Obtain or Fulfill a Contract

We recognize an asset from the costs incurred to obtain a revenue contract only if we expect to recover those costs. In addition, the costs to fulfill a revenue contract are capitalized if the costs are specifically identifiable to a revenue contract, would result in enhancing resources that will be used in satisfying performance obligations in the future, and are expected to be recovered. These capitalized costs are amortized on a systematic basis consistent with the pattern of transfer of the services to which such costs relate.

As of December 31, 2023 and 2022, we had capitalized costs to obtain or fulfill a contract of $18 million and $19 million, respectively, which are included in other current assets and other noncurrent assets in the accompanying Consolidated Statements of Financial Position. During the years ended December 31, 2023, 2022 and 2021 we recognized approximately $1 million of amortization expense related to such capitalized costs.

68

DT Midstream, Inc.

Notes to Consolidated Financial Statements

Major Customers

The following table summarizes customers which represent 10% or more of our total revenue for the years ended December 31, 2023, 2022 and 2021. Both Pipeline and Gathering segments provide services to these customers.

	2023				2022				2021
	Customer		Percentage		Customer		Percentage		Customer		Percentage
	Revenue		of Total		Revenue		of Total		Revenue		of Total
Customers:	(millions, except percentages)
Customer A	$	560	60	%	$	596	65	%	$	563	67	%
Customer B	*		*		*		*		84		10	%
*Represents less than 10%

NOTE 5 — GOODWILL

We have goodwill that resulted from business combinations. The carrying value of goodwill is evaluated for impairment on an annual basis or whenever events or circumstances indicate that the value of goodwill may be impaired. We performed our annual impairment test as of October 1, 2023 and determined that the estimated fair value of each reporting unit exceeded its carrying value, and no impairment existed. No additions, impairments or other changes occurred during the years ended December 31, 2023, 2022 and 2021.

The following is the summary of the carrying value of goodwill:

	Year Ended December 31,
	2023		2022
	(millions)
Pipeline	$	53	$	53
Gathering	420		420
Total goodwill	$	473	$	473

While we believe the estimates and assumptions in the estimated fair value are reasonable, the actual results may differ from projections. To the extent projected results or cash flows are revised downward, the reporting unit may be required to write down all or a portion of its goodwill, which would adversely impact our earnings.

NOTE 6 — PROPERTY, PLANT, AND EQUIPMENT AND INTANGIBLE ASSETS

Property, Plant, and Equipment

The following is a summary of Property, plant, and equipment by classification:

	Average Estimated Useful Life	December 31,
		2023		2022
	(years)	(millions)
Property, plant, and equipment
Land and other non-depreciable assets	N/A	$	96	$	97
Rights of way and easements	25 to 40	103		103
Pipelines and interconnects	25 to 40	3,460		2,845
Facilities and processing plants	7 to 40	1,234		998
Wells and well equipment	40 to 70	70		70
General plant	3 to 40	40		32
Construction in progress	N/A	279		389
Total Property, plant, and equipment		$	5,282	$	4,534
Less accumulated depreciation		(848)		(728)
Net Property, plant, and equipment		$	4,434	$	3,806

69

DT Midstream, Inc.

Notes to Consolidated Financial Statements

Intangible Assets

The following is a summary of Intangible Assets by classification:

		December 31, 2023						December 31, 2022
	Useful Lives	Gross Carrying Value		Accumulated Amortization		Net Carrying Value		Gross Carrying Value		Accumulated Amortization		Net Carrying Value
		(millions)
Intangible assets subject to amortization
Customer relationships	25 - 40 years (a)	$	2,252	$	(289)	$	1,963	$	2,252	$	(233)	$	2,019
Contract intangibles	14 - 26 years	18		(13)		5		18		(12)		6
Total		$	2,270	$	(302)	$	1,968	$	2,270	$	(245)	$	2,025

_____________________________________

(a) The useful lives of the customer relationship intangible assets are based on the number of years in which the assets are expected to economically contribute to the business. The expected economic benefit incorporates existing customer contracts and expected renewal rates based on the estimated volume and production lives of natural gas resources in each region.

The following table summarizes estimated customer relationships and contract intangibles amortization expense to be recognized during each year through 2028:

	2024		2025		2026		2027		2028
	(millions)
Estimated amortization expense	$	57	$	57	$	57	$	57	$	57

Depreciation and Amortization

The following is a summary of depreciation and amortization expense by asset type:

	Year Ended December 31,
	2023		2022		2021
	(millions)
Property, plant, and equipment	$	125	$	113	$	108
Customer relationships and other intangible assets, net	57		57		58
Total Depreciation and amortization	$	182	$	170	$	166

NOTE 7 — INCOME TAXES

Significant Accounting Policy – Accounting for Income Taxes

We record the effect of income taxes in accordance with GAAP, which provides for the use of an asset and liability approach. Deferred income tax assets and liabilities are recognized for temporary differences between the basis of assets and liabilities for financial reporting and tax purposes and measured using enacted tax rates in effect for the year in which those temporary differences are expected to be recovered or settled. The effect on deferred tax assets and liabilities as a result of changes in the enacted tax rates is recognized in earnings in the period of enactment. Our recognition of deferred tax assets is based upon a more-likely-than-not criterion. We routinely assess realizability based on objectively-weighted, available positive and negative evidence.

We account for uncertainties in income taxes using a benefit recognition model with a two-step approach: a more-likely-than-not recognition criterion, and a measurement attribute that measures the position as the largest amount of tax benefit that is greater than a 50% likelihood of being realized upon ultimate settlement. If the benefit does not meet the more likely than not criteria for being sustained on its technical merits, no benefit will be recorded. Uncertain tax positions that relate only to timing of when an item is included on a tax return are considered to have met the recognition threshold.

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DT Midstream, Inc.

Notes to Consolidated Financial Statements

The Separation – Tax Considerations

For period prior to the Separation, discussed at Note 1, "Description of the Business and Basis of Presentation", the income tax provision has been presented on a stand-alone basis as if we filed separate federal, state, local, and foreign income tax returns, referred to as the separate return method.

Tax Legislation

On July 8, 2022, the Commonwealth of Pennsylvania enacted House Bill (H.B.) 1342 which includes a corporate income tax rate reduction from 9.99% to 4.99% that will phase-in over a nine-year period.

Our total Income Tax Expense varied from the statutory federal income tax rate for the following reasons:

	Year Ended December 31,
	2023			2022			2021
	(millions)
Income Before Income Taxes	$	500		$	482		$	422
Income tax expense at statutory rate	105			101			89
State and local income taxes, net of federal benefit	18			24			17
State tax rate changes	(18)			(25)			(3)
Other, net	(1)			—			1
Income Tax Expense	$	104		$	100		$	104
Effective income tax rate	20.9		%	20.7		%	24.7		%

Our 2023 effective tax rate includes the impact of state tax rate changes of an $18 million benefit driven by changes in tax status and updates to state apportionment which were completed in 2023 as a part of ongoing corporate tax structuring, simplification initiatives, and initial post-separation full-year tax return filings.

Our 2022 effective tax rate includes the impact of state tax rate changes of a $25 million benefit driven by the Pennsylvania legislative changes.

Components of Income Tax Expense were as follows:

	Year Ended December 31,
	2023		2022		2021
	(millions)
Current income tax expense
Federal	$	(4)	$	16	$	1
State and other income tax	(2)		14		(1)
Total current income taxes	(6)		30		—
Deferred income tax expense
Federal	109		86		85
State and other income tax	1		(16)		19
Total deferred income tax	110		70		104
	$	104	$	100	$	104

Deferred tax assets and liabilities are recognized for the estimated future tax effect of temporary differences between the tax basis of assets or liabilities and the reported amounts in our Consolidated Financial Statements. We believe it is more likely than not that we will generate sufficient taxable income in future periods to realize our deferred tax assets.

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DT Midstream, Inc.

Notes to Consolidated Financial Statements

Deferred tax assets (liabilities) were comprised of the following:

	December 31,
	2023		2022
	(millions)
Deferred income tax balance components
Property, plant, and equipment	$	(369)	$	(336)
Federal net operating loss carry-forward	184		129
State and local net operating loss carry-forward, net of federal	102		79
Investment in equity method investees and partnerships	(979)		(811)
Other	31		16
Net deferred income tax asset / (liability)	$	(1,031)	$	(923)
Total deferred income tax assets and liabilities
Deferred income tax assets	$	319	$	234
Deferred income tax liabilities	(1,350)		(1,157)
Net deferred income tax asset / (liability)	$	(1,031)	$	(923)

We have recorded a deferred tax asset related to a federal net operating loss carry-forward of $184 million as of December 31, 2023. U.S. federal net operating losses will be available to be carried forward indefinitely and available to offset 80% of taxable income in future years.

We have recorded state and local deferred tax assets related to net operating loss carry-forwards of $102 million as of December 31, 2023. Of which, $97 million of the state and local net operating loss carry-forwards can be carried indefinitely and $5 million will expire from 2033 through 2042 and are available to offset varying amounts of taxable income in future years.

Uncertain Tax Positions

As of December 31, 2023 and 2022, we did not have any unrecognized tax benefits.

For periods prior to the Separation, we were a member of the consolidated tax return of DTE Energy. As of December 31, 2023, DTE Energy did not have any open tax years subject to examination by the Internal Revenue Service (IRS) for which DT Midstream is a member. DTE Energy also files in multiple states, the statutes of which are open to examination for various periods.

For periods after the Separation, our income tax returns remain subject to examination by federal, state, and local taxing jurisdictions.

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DT Midstream, Inc.

Notes to Consolidated Financial Statements

NOTE 8 — EARNINGS PER SHARE AND DIVIDENDS

Basic earnings per share is calculated by dividing Net Income attributable to DT Midstream by the weighted-average number of common shares outstanding during the period. Diluted earnings per share reflect the dilution that would occur if any potentially dilutive instruments were exercised or converted into common shares, using the treasury stock method. Restricted stock units and performance share awards, including dividend equivalents on those grants, are potentially dilutive and, if dilutive, are included in the determination of weighted-average shares outstanding. Restricted stock units and performance share awards do not receive cash dividends, as such, these awards are not considered participating securities.

We issued 1,000 shares of common stock at $0.01 par value to its parent, a subsidiary of DTE Energy, in January 2021. Our Board of Directors authorized the issuance of an additional 96,731,466 common shares on June 30, 2021 for a total of 96,732,466 common shares issued and outstanding at the Separation date. This share amount is treated as issued and outstanding and utilized for the calculation of historical basic and diluted earnings per share for all periods prior to the Separation.

The following is a reconciliation of basic and diluted earnings per share:

	Year Ended December 31,
	2023		2022		2021
	(millions, except per share amounts)
Basic and Diluted Earnings per Common Share
Net Income Attributable to DT Midstream	$	384	$	370	$	307
Average number of common shares outstanding — basic	96.9		96.7		96.7
Incremental shares attributable to:
Average dilutive restricted stock units and performance share awards	0.6		0.5		0.2
Average number of common shares outstanding — diluted	97.5		97.2		96.9
Basic Earnings per Common Share	$	3.97	$	3.83	$	3.17
Diluted Earnings per Common Share	$	3.94	$	3.81	$	3.16

We declared the following cash dividends:

Dividends Declared	Dividend Amount				Dividend Payment Date
(quarter ended)	(per-share)		(millions)
2021
September 30	$	0.60	$	58	October 2021
December 31	$	0.60	$	58	January 2022
2022
March 31	$	0.64	$	62	April 2022
June 30	$	0.64	$	62	July 2022
September 30	$	0.64	$	62	October 2022
December 31	$	0.64	$	62	January 2023
2023
March 31	$	0.69	$	67	April 2023
June 30	$	0.69	$	67	July 2023
September 30	$	0.69	$	67	October 2023
December 31	$	0.69	$	67	January 2024

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DT Midstream, Inc.

Notes to Consolidated Financial Statements

NOTE 9 — FAIR VALUE

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 in a principal or most advantageous market. Fair value is a market-based measurement that is determined based on inputs, which refer broadly to assumptions that market participants use in pricing assets or liabilities. These inputs can be readily observable, market corroborated, or generally unobservable inputs. We make certain assumptions we believe that market participants would use in pricing assets or liabilities, including assumptions about risk, and the risks inherent in the inputs to valuation techniques. We believe we uses valuation techniques that maximize the use of observable market-based inputs and minimize the use of unobservable inputs.

A fair value hierarchy has been established that prioritizes the inputs to valuation techniques used to measure fair value in three broad levels. The fair value hierarchy gives the highest priority to quoted prices (unadjusted) in active markets for identical assets or liabilities (Level 1) and the lowest priority to unobservable inputs (Level 3). In some cases, the inputs used to measure fair value might fall in different levels of the fair value hierarchy. All assets and liabilities are required to be classified in their entirety based on the lowest level of input that is significant to the fair value measurement in its entirety. Assessing the significance of a particular input may require judgment considering factors specific to the asset or liability and may affect the valuation of the asset or liability and its placement within the fair value hierarchy. We classify fair value balances based on the fair value hierarchy defined as follows:

•Level 1 — Consists of unadjusted quoted prices in active markets for identical assets or liabilities that we have the ability to access as of the reporting date.

•Level 2 — Consists of inputs other than quoted prices included within Level 1 that are directly observable for the assets or liabilities or indirectly observable through corroboration with observable market data.

•Level 3 — Consists of unobservable inputs for assets or liabilities whose fair value is estimated based on internally developed models or methodologies using inputs that are generally less readily observable and supported by little, if any, market activity at the measurement date. Unobservable inputs are developed based on the best available information and subject to cost-benefit constraints.

Fair Value of Financial Instruments

The following table presents the carrying amount and fair value of financial instruments:

	December 31, 2023								December 31, 2022
	Carrying		Fair Value						Carrying		Fair Value
	Amount		Level 1		Level 2		Level 3		Amount		Level 1		Level 2		Level 3
	(millions)
Cash equivalents (a)	$	36	$	—	$	36	$	—	$	—	$	—	$	—	$	—
Long-term notes receivable — related party	4		—		—		4		4		—		—		4
Short-term borrowings (a)	165		—		165		—		330		—		330		—
Long-term debt (b)	$	3,065	$	—	$	2,850	$	—	$	3,059	$	—	$	2,701	$	—

______________________________________

(a)Short-term borrowings and money market cash equivalents are stated at cost, which approximates fair value.

(b)Carrying value represents principal of $3,099 million, net of unamortized debt discounts and issuance costs.

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DT Midstream, Inc.

Notes to Consolidated Financial Statements

NOTE 10 — DEBT

Amendments to Credit Agreement

In June 2023, we entered into an Amendment No. 2 to our Credit Agreement amending certain of the terms, including, among other things, the replacement of the interest rate provisions related to the Term Loan Facility from Eurodollar Rate to Term SOFR (as defined in the Credit Agreement).

In October 2022, we amended the Credit Agreement to increase the Revolving Credit Facility commitments by $250 million to aggregate commitments of $1.0 billion. The amendment also extended the Revolving Credit Facility maturity date to October 19, 2027, replaced the Revolving Credit Facility's LIBOR interest rate references with Term SOFR, and incorporated various amendments, including amendments to pricing, guarantee and collateral provisions, that will become effective if we receive an investment-grade rating from two of the three credit rating agencies.

Debt Issuances

In April 2022, we issued $600 million in aggregate principal amount of 4.300% senior secured notes due April 2032. The 2032 Notes are guaranteed by certain of our subsidiaries and secured by a first priority lien on certain assets of DT Midstream and our subsidiary guarantors that secure our existing credit facilities. The 2032 Notes have a security fall away provision where the collateral securing the notes will be released if we receive an investment-grade rating from two of the three credit rating agencies.

In June 2021, we issued the senior unsecured notes of $1.1 billion in aggregate principal amount due June 15, 2029 and $1.0 billion in aggregate principal amount due June 15, 2031.

Debt Redemptions

In April 2022, we used $593 million of the net proceeds from the sale of the 2032 Notes to make a partial repayment on the existing indebtedness under the Term Loan Facility. As a result, required quarterly principal payments were eliminated, and the remaining Term Loan Facility balance is not due until maturity in 2028. There were no prepayment costs in conjunction with the partial redemption of the Term Loan Facility. The early redemption resulted in a loss on extinguishment of debt of $9 million and loss on modification of debt of $4 million relating to the write-off of unamortized discount and issuance costs, which was recorded as a loss from financing activities in our Consolidated Statements of Operations for the year ended December 31, 2022.

Interest Expense

The following table summarizes our interest expense:

	Year Ended December 31,
	2023		2022		2021
	(millions)
Interest expense	$	170	$	142	$	113
Capitalized interest	(20)		(5)		(1)
Total interest expense, net	$	150	$	137	$	112

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DT Midstream, Inc.

Notes to Consolidated Financial Statements

Long-Term Debt

The following is a summary of long-term debt:

			Maturity	December 31,		December 31,
Title	Type	Interest Rate	Date	2023		2022
				(millions)
2029 Notes	Senior Notes (a)	4.125%	2029	$	1,100	$	1,100
2031 Notes	Senior Notes (a)	4.375%	2031	1,000		1,000
2032 Notes	Senior Secured Notes (b)	4.300%	2032	600		600
Term Loan Facility	Term Loan Facility	Variable (c)	2028	399		399
Long-term debt principal				3,099		3,099
Unamortized debt discount				(2)		(3)
Unamortized debt issuance costs				(32)		(37)
Long-term debt, net				$	3,065	$	3,059

______________________________

(a) Interest payable semi-annually in arrears each June 15 and December 15.

(b) Interest payable semi-annually in arrears each April 15 and October 15.

(c) Variable rate is SOFR plus 2.11% for a one-month interest period as of December 31, 2023.

The following table presents scheduled debt maturities, excluding any unamortized discount on debt:

		2024		2025	2026	2027	2028 and Thereafter	Total
	(millions)
Debt maturities		$	—	—	—	—	3,099	$	3,099

Short-Term Credit Arrangements and Borrowings

The following table presents the availability under the Revolving Credit Facility:

	December 31,
	2023
	(millions)
Total availability
Revolving Credit Facility, expiring October 2027	$	1,000
Amounts outstanding
Revolving Credit Facility borrowings (a)	165
Letters of credit	16
	181
Net availability	$	819

______________________________

(a) The weighted average interest rate for Revolving Credit Facility borrowings outstanding is 6.72%.

Borrowings under the Revolving Credit Facility are used for general corporate purposes, acquisitions, and letter of credit issuances to support our operations and liquidity. In April 2023, certain letters of credit totaling $23 million were replaced with surety bonds. See Note 12, "Commitments and Contingencies" for additional information. Revolving Credit Facility related issuance and amendment costs, net of amortization, were $6 million and $8 million, as of December 31, 2023 and 2022, respectively. These costs are included in other noncurrent assets in our Consolidated Statements of Financial Position and are being amortized over the remaining term of the Revolving Credit Facility.

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DT Midstream, Inc.

Notes to Consolidated Financial Statements

The Credit Agreement covering the Term Loan Facility and Revolving Credit Facility includes financial covenants that we must maintain. These covenants restrict the ability of DT Midstream and our subsidiaries to incur additional indebtedness and guarantee indebtedness, create or incur liens, engage in mergers, consolidations, liquidations or dissolutions, sell, transfer or otherwise dispose of assets, make investments, acquisitions, loans or advances, pay dividends and distributions or repurchase capital stock, prepay, redeem or repurchase certain junior indebtedness, enter into agreements that limit the ability of the restricted subsidiaries to make distributions to DT Midstream or the ability of DT Midstream and our restricted subsidiaries to incur liens on assets and enter into certain transactions with affiliates. The Term Loan Facility requires the maintenance of a minimum debt service coverage ratio of 1.1 to 1, and the Revolving Credit Facility requires maintenance of (i) a maximum consolidated net leverage ratio of 5 to 1, and (ii) a minimum interest coverage ratio of no less than 2.5 to 1. The debt service coverage ratio means the ratio of annual consolidated EBITDA to debt service, as defined in the Credit Agreement. The consolidated net leverage ratio means the ratio of net debt determined in accordance with GAAP to annual consolidated EBITDA. The interest coverage ratio means the ratio of annual consolidated EBITDA to annual interest expense, as defined in the Credit Agreement. The Credit Agreement definition of annual consolidated EBITDA excludes EBITDA from equity method investees, but includes dividends and distributions from equity method investees. As of December 31, 2023, the debt service coverage ratio, the consolidated net leverage ratio and the interest coverage ratio was 8.3 to 1, 2.4 to 1 and 7.8 to 1, respectively, and we were in compliance with these financial covenants.

Dividend Restrictions

The indenture governing the 2029 and 2031 Notes permits the payment of quarterly dividends on common stock in each fiscal year up to a dividend capacity calculated as defined in the indenture. For 2023, the dividend capacity remaining at year end was $356 million.

The Credit Agreement permits the payment of quarterly dividends on common stock in each fiscal year as long as giving pro forma effect thereto, we maintain a first lien net leverage ratio that does not exceed 3.25 to 1. We maintained such first lien net leverage ratio as of December 31, 2023.

NOTE 11 — LEASES

Lessee

Our leases are primarily comprised of equipment and buildings with terms ranging from approximately 3 to 11 years.

A lease exists when we have the right to control the use of identified property, plant or equipment, as conveyed through a contract, for a certain time period and consideration paid. The right to control is deemed to occur when we have the right to obtain substantially all of the economic benefits of the identified assets and the right to direct the use of such assets.

Lease liabilities are calculated utilizing a discount rate to determine the present values of lease payments. GAAP requires the use of the rate implicit in the lease if it is readily determinable. When the rate implicit in the lease is not readily determinable, the incremental borrowing rate is used. The incremental borrowing rate is based upon the rate of interest that would have been paid on a collateralized basis over similar contract terms to that of the leases. The incremental borrowing rates have been determined utilizing an implied secured borrowing rate based upon an unsecured rate for a similar time period of remaining lease terms, which is then adjusted for the estimated impact of collateral. We have leases with non-index-based escalation clauses for fixed dollar or percentage increases over the contract term.

We have certain leases which contain purchase options. Based upon the nature of the leased property and terms of the purchase options, we have determined it is not reasonably certain that such purchase options will be exercised. Thus, the impact of the purchase options has not been included in the determination of right-of-use assets and lease liabilities for the subject leases.

We have certain leases which contain renewal options. Where the renewal options were deemed reasonably certain to occur, the impacts of such options were included in the determination of the right-of-use assets and lease liabilities for the subject leases.

We have agreements with lease and non-lease components, which are generally accounted for separately. Consideration in a lease is allocated between lease and non-lease components based upon the estimated relative standalone prices.

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DT Midstream, Inc.

Notes to Consolidated Financial Statements

The components of lease cost for the following years includes:

	Year Ended December 31,
	2023		2022		2021
	(millions)
Operating lease cost	$	20	$	20	$	19
Short-term lease cost	3		3		1
	$	23	$	23	$	20

Operating lease cost includes amortization of operating lease right-of-use assets and other related costs. We have elected not to apply the lease balance sheet recognition requirements to short-term leases with a term of 12 months or less. Operating and short-term lease costs are recorded to operation and maintenance in our Consolidated Statements of Operations.

Other relevant information related to leases for the following years includes:

	Year Ended December 31,
	2023			2022			2021
Supplemental Cash Flows Information	(millions, except years and percentages)
Cash paid for amounts included in the measurement of these liabilities:
Operating cash flows for operating leases	$	21		$	18		$	19
Right-of-use assets obtained in exchange for lease obligations:
Operating leases	$	25		$	14		$	9
Weighted Average Remaining Lease Term
Operating leases	4.4 years			4.0 years			4.4 years
Weighted Average Discount Rate
Operating leases	4.8		%	3.5		%	2.6		%

Future minimum lease payments under leases for remaining periods as of December 31, 2023 are as follows:

	Operating Leases
	(millions)
2024	$	15
2025	9
2026	7
2027	7
2028	2
2029 and thereafter	4
Total future minimum lease payments	44
Imputed interest	(4)
Lease liabilities	$	40

Lessor

We lease assets under an operating lease for a pipeline which commenced in December 2018. The lease is comprised of fixed payments with a remaining term of 15 years. The operating lease does not have renewal provisions or options to purchase the assets at the end of the lease and does not have termination for convenience provisions. The lease term extends to the end of the estimated economic life of the leased assets, thereby resulting in no residual value.

A lease exists when we have provided other parties with the right to control the use of identified property, plant or equipment, as conveyed through a contract, for a certain time period and consideration received. The right to control is deemed to occur when we have provided other parties with the right to obtain substantially all of the economic benefits of the identified assets and the right to direct the use of such assets.

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DT Midstream, Inc.

Notes to Consolidated Financial Statements

Fixed lease income associated with the operating lease was $7 million, $10 million, and $9 million for the years ended December 31, 2023, 2022 and 2021, respectively. Fixed lease income is reported in Operating revenues in our Consolidated Statements of Operations. Depreciation expense associated with the property under the operating lease was $3 million for each of the years ended December 31, 2023, 2022 and 2021.

Future minimum rental revenues for remaining periods as of December 31, 2023 are as follows:

	Operating Lease
	(millions)
2024	$	9
2025	9
2026	9
2027	9
2028	9
2029 and thereafter	88
Total future minimum rental revenues	$	133

Property under the operating lease is as follows:

	December 31,
	2023		2022
	(millions)
Gross property under operating leases	$	58	$	58
Accumulated amortization of property under operating leases	$	15	$	12

NOTE 12 — COMMITMENTS AND CONTINGENCIES

From time to time, we are subject to legal, administrative and environmental proceedings before various courts, arbitration panels and governmental agencies concerning claims arising in the ordinary course of business. These proceedings include certain contract disputes, additional environmental reviews and investigations, audits and pending judicial matters. We cannot predict the final disposition of such proceedings. We regularly review legal matters and records provisions for claims that we can estimate and are considered probable of loss. The amount or range of reasonably possible losses is not anticipated to, either individually or in the aggregate, materially adversely affect our business, financial condition and results of operations.

Guarantees

In certain limited circumstances, we enter into contractual guarantees. We may guarantee another entity's obligation in the event it fails to perform and may provide guarantees in certain indemnification agreements. We did not have any guarantees of other parties' obligations as of December 31, 2023.

Purchase Commitments

As of December 31, 2023, we were party to long-term purchase commitments relating to a variety of goods and services required for our business. We estimate lifetime purchase commitments of approximately $103 million, due in the periods shown below.

	(millions)
2024	$	14
2025	13
2026	12
2027	11
2028	11
2029 and thereafter	42
Total	$	103

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Notes to Consolidated Financial Statements

Surety Bonds

In certain limited circumstances, we enter into contracts that require us to obtain external surety bonds to secure our payment and performance. We agree to indemnify the issuers of these surety bonds for amounts, if any, paid by them under these agreements. In the event that any surety bonds are called for non-performance, we would be obligated to reimburse the issuer of the surety bond. The maximum potential indemnification under our surety bond agreements as of December 31, 2023 is $32 million.

Vector Line of Credit

We are the lender under a revolving term credit facility to Vector, the borrower, in the amount of Canadian $70 million. The credit facility was executed in response to the passage of Canadian regulations requiring oil and gas pipelines to demonstrate their financial ability to respond to a catastrophic event and exists for the sole purpose of satisfying these regulations. Vector may only draw upon the facility if the funds are required to respond to a catastrophic event. The maximum potential payout as of December 31, 2023 is USD $53 million. The funding of a loan under the terms of the revolving term credit facility is considered remote.

Contingent Liability

In order to comply with certain state environmental regulations, we have an obligation to restore pipeline right-of-way slope failures that may arise in the ordinary course of business in the Utica and Marcellus formations. We conducted an evaluation, which was prioritized based on the severity and proximity of remaining locations, and used updated cost information to assess the adequacy of the estimate for the contingent liability accrual. Based on this evaluation, we recorded a reduction to the contingent liability accrual and decrease to operation and maintenance expense of $6 million during the year ended December 31, 2023. As of December 31, 2023 and 2022, we had accrued contingent liabilities of $13 million and $19 million, respectively, for future slope restoration expenditures. The accrual is included in other current liabilities and other liabilities in the Consolidated Statements of Financial Position. While restoration and continued evaluation is ongoing, we believe the accrued amounts are sufficient to cover estimated future expenditures.

NOTE 13 — STOCK-BASED COMPENSATION AND DEFINED CONTRIBUTION PLANS

The DT Midstream, Inc. Long-Term Incentive Plan ("DT Midstream Plan") permits the grant of incentive and nonqualified stock options, stock appreciation rights, restricted stock awards and restricted stock units, performance share awards, and performance units to employees, consultants and members of DT Midstream's Board of Directors. As a result of a restricted stock award grant, restricted stock unit or performance share award settlement, or by exercise of a stock option, we may issue common stock from our authorized but unissued common stock and/or from outstanding common stock acquired by or on behalf of DT Midstream in the participant's name. The DT Midstream Plan began on the Separation date. Key provisions of the DT Midstream Plan are:

•Authorized limit as of December 31, 2023 was 6,500,000 shares of common stock. The authorized limit increases annually on January 1 by the lesser of 1,750,000 shares of common stock or the amount determined by the DT Midstream Board of Directors.

•Prohibits the grant of a stock option with an exercise price that is less than the fair market value of DT Midstream's stock on the grant date.

Prior to the Separation, our employees participated in DTE Energy's Long-Term Incentive Plan. At the Separation, outstanding DT Midstream employee restricted stock awards and performance share awards were modified or settled as follows:

•DTE Energy restricted stock awards were converted into DT Midstream restricted stock units;

•Unsettled DTE Energy performance share awards were converted into DT Midstream performance share awards.

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DT Midstream, Inc.

Notes to Consolidated Financial Statements

The restricted stock awards and performance share awards were converted using a formula designed to preserve the fair value of the awards immediately prior to the Separation. All converted awards retained the vesting schedule of the original awards. The conversion of the restricted stock awards and performance share awards qualified as an accounting modification under GAAP. The pre- and post- Separation fair value of the awards was compared, and any incremental fair value was added to the original grant date fair value of the awards. The Separation modification gave rise to incremental fair value of approximately $1 million for the performance share awards granted in January 2021 and is reflected in the compensation cost and the unrecognized compensation costs described below. The Separation modification did not result in incremental fair value for any other converted restricted stock awards or performance share awards.

Prior to the Separation, we received an allocation of costs from DTE Energy associated with stock-based compensation. Allocated costs for the first six months of 2021 are included in the table below. No costs were allocated after July 1, 2021. The following table summarizes our stock-based compensation expense and the related income tax benefit:

	Year Ended December 31,
	2023		2022		2021
	(millions)
Stock-based compensation expense	$	20	$	17	$	12
Tax benefit	$	5	$	4	$	3

Restricted Stock Units

Restricted stock units granted under the DT Midstream Plan are for a specified number of shares of DT Midstream common stock that entitle the holder to receive common stock, a cash payment, or a combination thereof at the end of the specified vesting period, which is generally three or four years. Restricted stock units are deemed to be equity awards. The fair value of restricted stock units is based on DT Midstream's closing common stock price on the grant date. The fair value is amortized to stock-based compensation expense using a graded vesting schedule over the vesting period. Restricted stock units are settled with DT Midstream common stock and fractional shares are settled in cash.

During the vesting period, the number of restricted stock units granted will increase, assuming full dividend reinvestment on each dividend payment date. The recipient of a restricted stock unit has no shareholder rights during the vesting period. Restricted stock units are nontransferable and subject to risk of forfeiture during the vesting period. Forfeitures are recognized in the period they occur.

The following table summarizes restricted stock unit activity for the year ended December 31, 2023:

	Restricted Stock Units	Weighted- Average Grant Date Fair Value
	(thousands)	(per share)
Nonvested as of December 31, 2022	468	$	43.28
Granted (a)	103	51.28
Forfeited	(5)	47.80
Vested	(149)	41.52
Nonvested as of December 31, 2023	417	$	45.68

_____________________________________

(a)Includes initial grants and dividends reinvested.

The weighted-average grant date fair value of restricted stock units granted, excluding dividends reinvested, during the years ended December 31, 2023 and 2022 was $52.66 and $52.25, respectively. No restricted stock units were granted during the year ended December 31, 2021. The intrinsic value of restricted stock units vested and issued during the years ended December 31, 2023, 2022 and 2021 was $8 million, $3.3 million, and $0.1 million, respectively.

81

DT Midstream, Inc.

Notes to Consolidated Financial Statements

Performance Share Awards

Performance share awards granted under the DT Midstream Plan are for a specified number of shares of DT Midstream common stock that entitle the holder to receive common stock, a cash payment, or a combination thereof at the end of the specified vesting period, which is generally three years. Performance share awards are deemed to be equity awards. Performance share stock-based compensation expense is accrued over the vesting period based on the grant date fair value calculated using: (i) DT Midstream's closing common stock price on the grant date; (ii) the grant date fair value of the market condition; and (iii) the probable achievement of performance objectives. For the performance share awards converted at the Separation, the grant date fair value was based on DTE Energy's stock price and market conditions at grant date. The number of shares issued at settlement is determined based on market conditions and the achievement of certain DT Midstream performance objectives. Performance share awards are settled with DT Midstream common stock and fractional shares are settled in cash.

During the vesting period, the number of performance share awards granted will increase, assuming full dividend reinvestment on each dividend payment date. The recipient of a performance share award has no shareholder rights during the vesting period. Performance share awards are nontransferable and are subject to risk of forfeiture during the vesting period. Forfeitures are recognized in the period they occur.

The following table summarizes performance share award activity for the year ended December 31, 2023:

	Performance Share Awards	Weighted- Average Grant Date Fair Value
	(thousands)	(per share)
Nonvested as of December 31, 2022	409	$	56.55
Granted (a)	334	59.02
Forfeited	(19)	62.31
Settled	(167)	34.83
Nonvested as of December 31, 2023	557	$	64.36

_____________________________________

(a)Includes initial grants, dividends reinvested and shares added for achievement of final performance objectives on settled awards.

The weighted-average grant date fair value of performance share awards granted, excluding dividends reinvested, during the years ended December 31, 2023 and 2022 was $53.74 and $72.97, respectively. The intrinsic value of performance share awards settled during the years ended December 31, 2023 and 2022 was $9 million and $4 million, respectively. No performance share awards were granted or settled by DT Midstream during the year ended December 31, 2021.

Unrecognized Compensation Costs

As of December 31, 2023, we had $23 million of total unrecognized compensation costs related to non-vested stock incentive plan arrangements. The cost is expected to be recognized over a weighted-average period of 1.67 years.

Defined Contribution Plans

We sponsor defined contribution retirement savings plans, and participation in one of these plans is available to substantially all employees. We match employee contributions up to certain predefined and Internal Revenue Service limits based on eligible compensation and each employee's contribution rate, and contributes additional amounts in lieu of traditional pension and post-employment healthcare benefits. Prior to the Separation, we participated in the defined contribution retirement savings plans of DTE Energy. DT Midstream's cost for these plans was $7 million, $5 million and $3 million for the years ended December 31, 2023, 2022 and 2021, respectively.

82

DT Midstream, Inc.

Notes to Consolidated Financial Statements

NOTE 14 — SEGMENT AND RELATED INFORMATION

We set strategic goals, allocate resources, and evaluate performance based on the following structure:

The Pipeline segment owns and operates interstate and intrastate natural gas pipelines, storage systems, and natural gas gathering lateral pipelines. The Pipeline segment also has interests in equity method investees that own and operate interstate natural gas pipelines. The segment is engaged in the transportation and storage of natural gas for intermediate and end user customers. During the three months ended March 31, 2023, we completed the conversion of the Michigan System from gathering to dry gas transmission service and began providing services under a new long-term dry gas transmission contract. For the year ended December 31, 2023, the Michigan System financial results are presented in the Pipeline segment. The prior years' comparative activity was for gathering services and therefore was not revised from presentation in the Gathering segment.

The Gathering segment owns and operates gas gathering systems. The segment is engaged in collecting natural gas from points at or near customers’ wells for delivery to plants for treating, to gathering pipelines for further gathering, or to pipelines for transportation, as well as associated ancillary services, including compression, dehydration, gas treatment, water impoundment, water transportation, water disposal, and sand mining.

Inter-segment billing for goods and services exchanged between segments is based upon contracted prices of the provider. Inter-segment billings were not significant for the years ended December 31, 2023, 2022 and 2021.

Financial data for our business segments follows:

	Year Ended December 31, 2023
	Pipeline		Gathering		Eliminations		Total
	(millions)
Operating revenues	$	377	$	545	$	—	$	922
Operation and maintenance	55		190		—		245
Depreciation and amortization	69		113		—		182
Taxes other than income	15		13		—		28
Asset (gains) losses and impairments, net	(4)		—		—		(4)
Operating Income	242		229		—		471
Interest expense	55		95		—		150
Interest income	(1)		—		—		(1)
Earnings from equity method investees	(177)		—		—		(177)
Other (income) and expense	—		(1)		—		(1)
Income Tax Expense	75		29		—		104
Net Income	290		106		—		396
Less: Net Income Attributable to Noncontrolling Interests	12		—		—		12
Net Income Attributable to DT Midstream	$	278	$	106	$	—	$	384
Capital expenditures	$	255	$	517	$	—	$	772
	December 31, 2023
Investments in equity method investees	$	1,762	$	—	$	—	$	1,762
Goodwill	53		420		—		473
Total Assets	$	4,439	$	4,543	$	—	$	8,982

83

DT Midstream, Inc.

Notes to Consolidated Financial Statements

	Year Ended December 31, 2022
	Pipeline		Gathering		Eliminations		Total
	(millions)
Operating revenues	$	339	$	581	$	—	$	920
Operation and maintenance	54		213		—		267
Depreciation and amortization	63		107		—		170
Taxes other than income	14		14		—		28
Asset (gains) losses and impairments, net	(6)		(17)		—		(23)
Operating Income	214		264		—		478
Interest expense	57		80		—		137
Interest income	(1)		(2)		—		(3)
Earnings from equity method investees	(150)		—		—		(150)
Loss from financing activities	6		7		—		13
Other (income) and expense	—		(1)		—		(1)
Income Tax Expense	62		38		—		100
Net Income	240		142		—		382
Less: Net Income Attributable to Noncontrolling Interests	12		—		—		12
Net Income Attributable to DT Midstream	$	228	$	142	$	—	$	370
Capital expenditures and acquisitions	$	638	$	252	$	—	$	890
	December 31, 2022
Investments in equity method investees	$	2,200	$	—	$	—	$	2,200
Goodwill	53		420		—		473
Total Assets	$	4,625	$	4,208	$	—	$	8,833

	Year Ended December 31, 2021
	Pipeline		Gathering		Eliminations		Total
	(millions)
Operating revenues	$	307	$	534	$	(1)	$	840
Operation and maintenance	59		173		(1)		231
Depreciation and amortization	63		103		—		166
Taxes other than income	13		11		—		24
Asset (gains) losses and impairments, net	—		17		—		17
Operating Income	172		230		—		402
Interest expense	51		61		—		112
Interest income	(1)		(3)		—		(4)
Earnings from equity method investees	(126)		—		—		(126)
Other (income) and expense	(3)		1		—		(2)
Income Tax Expense	62		42		—		104
Net Income	189		129		—		318
Less: Net Income Attributable to Noncontrolling Interests	11		—		—		11
Net Income Attributable to DT Midstream	$	178	$	129	$	—	$	307
Capital expenditures	$	20	$	120	$	—	$	140
	December 31, 2021
Investments in equity method investees	$	1,691	$	—	$	—	$	1,691
Goodwill	53		420		—		473
Total Assets	$	4,165	$	4,001	$	—	$	8,166

84

DT Midstream, Inc.

Notes to Consolidated Financial Statements

NOTE 15 — RELATED PARTY TRANSACTIONS

Transactions between DT Midstream and DTE Energy prior to the Separation, as well as all transactions between DT Midstream and our equity method investees, have been presented as related party transactions in the accompanying Consolidated Financial Statements.

Prior to the Separation, DTE Energy and its subsidiaries provided physical operations, maintenance, and technical support pursuant to an operating agreement for our facilities. We also utilized various services performed by DTE Energy and its subsidiaries including marketing and capacity optimization services.

Prior to the Separation, interest expense recorded in the Consolidated Statements of Operations was primarily related to interest on the Short-term borrowings due to DTE Energy, amounts of which are shown in the table below. The working capital loan agreement had an interest rate of 3.3% for 2021 and a term of one year. No interest expense on Short-term borrowings due to DTE Energy was incurred after the Separation.

In June 2021, we made the following cash payments:

•Settled Short-term borrowings due to DTE Energy as of June 30, 2021 of $2,537 million

•Settled Accounts receivable due from DTE Energy and Accounts payable due to DTE Energy as of June 30, 2021 for net cash of $9 million

•Provided a one-time special dividend to DTE Energy

On July 1, 2021, DTE Energy completed the Separation through the distribution of 96,732,466 shares of DT Midstream common stock to DTE Energy shareholders. After the Separation, DTE Energy is not considered a related party of DT Midstream.

The following is a summary of our balances with related parties:

	December 31,
	2023		2022
	(millions)
Notes receivable from Vector — long-term	$	4	$	4
Current Liabilities — Other	1		3

The following is a summary of our transactions with related parties:

	Year Ended December 31,
	2023		2022		2021
	(millions)
Revenues
Pipeline	$	—	$	—	$	5
Gathering	—		—		10
Other Costs
Interest income	—		—		(5)
Interest expense	—		—		43
Operation and maintenance and Other expense	(1)		(1)		43
Other
Notes receivable (due from) repaid by DTE Energy	—		—		263
Short-term borrowings (repayment of borrowings) from DTE Energy	—		—		(3,175)
Dividend to DTE Energy	—		—		(501)
Contributions from DTE Energy	—		—		110
Non-cash distributions to DTE Energy	—		—		(10)

85

DT Midstream, Inc.

Notes to Consolidated Financial Statements

NOTE 16 — SUBSEQUENT EVENT

Dividend Declaration

On February 16, 2024, we announced that our Board of Directors declared a quarterly dividend of $0.735 per share of common stock. The dividend is payable to stockholders of record as of March 18, 2024 and is expected to be paid on April 15, 2024.

86

Item 9. Changes in and Disagreements with Accountants on Accounting and Financial Disclosure

None.

Item 9A. Controls and Procedures

(a) Evaluation of disclosure controls and procedures

Management of DT Midstream carried out an evaluation, under the supervision and with the participation of DT Midstream's Chief Executive Officer (CEO) and Chief Financial Officer (CFO), of the effectiveness of the design and operation of DT Midstream's disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) as of December 31, 2023, which is the end of the period covered by this report. Based on this evaluation, DT Midstream's CEO and CFO have concluded that such disclosure controls and procedures are effective in providing reasonable assurance that information required to be disclosed by DT Midstream in reports that it files or submits under the Exchange Act (i) is recorded, processed, summarized, and reported within the time periods specified in the SEC's rules and forms and (ii) is accumulated and communicated to DT Midstream's management, including our CEO and CFO, as appropriate to allow timely decisions regarding required disclosure. Due to the inherent limitations in the effectiveness of any disclosure controls and procedures, management cannot provide absolute assurance that the objectives of our disclosure controls and procedures will be attained.

(b) Management's report on internal control over financial reporting

Management of DT Midstream is responsible for establishing and maintaining adequate internal control over financial reporting as such term is defined in Exchange Act Rules 13a-15(f) and 15d-15(f). Internal control over financial reporting is a process designed by, or under the supervision of, DT Midstream's CEO and CFO, 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.

Because of its inherent limitations, internal control over financial reporting may not prevent or detect misstatements. Also, projections of any evaluation of effectiveness to future periods are subject to the risk that controls may become inadequate because of changes in conditions, or that the degree of compliance with the policies or procedures may deteriorate.

Management of DT Midstream has assessed the effectiveness of DT Midstream’s internal control over financial reporting as of December 31, 2023. In making this assessment, management used the criteria issued by the Committee of Sponsoring Organizations of the Treadway Commission in Internal Control - Integrated Framework (2013). Based on this assessment, DT Midstream's management concluded that, as of December 31, 2023, DT Midstream’s internal control over financial reporting was effective.

The effectiveness of DT Midstream's internal control over financial reporting as of December 31, 2023 has been audited by PricewaterhouseCoopers, LLP, an independent registered public accounting firm who also audited DT Midstream's financial statements, as stated in their report which appears herein.

(c) Changes in internal control over financial reporting

No changes in our internal control over financial reporting during the quarter ended December 31, 2023 have materially affected, or are reasonably likely to materially affect, our internal control over financial reporting.

Item 9B. Other Information

During the three months ended December 31, 2023, none of the Company’s directors or executive officers adopted, modified or terminated any contract, instruction or written plan for the purchase or sale of the Company’s common stock that was intended to satisfy the affirmative defense conditions of Exchange Act Rule 10b5-1(c) or any "non-Rule 10b5-1 trading arrangement."

Item 9C. Disclosure Regarding Foreign Jurisdictions that Prevent Inspections

Not applicable.

87

PART III

Information required of DT Midstream by Part III (Items 10, 11, 12, 13 and 14) of this Form 10-K is incorporated by reference from DT Midstream's definitive Proxy Statement for our 2024 Annual Meeting of Common Shareholders to be held May 10, 2024. The Proxy Statement will be filed with the SEC pursuant to Regulation 14A not later than 120 days after the end of DT Midstream's fiscal year covered by this report on Form 10-K, all of which information is hereby incorporated by reference in, and made part of, this Form 10-K.

Item 10. Directors, Executive Officers, and Corporate Governance

Item 11. Executive Compensation

Item 12. Security Ownership of Certain Beneficial Owners and Management and Related Stockholder Matters

Item 13. Certain Relationships and Related Transactions, and Director Independence

Item 14. Principal Accountant Fees and Services

88

PART IV

Item 15. Exhibits and Financial Statement Schedules

A.The following documents are filed as part of this Annual Report on Form 10-K.

(a)Consolidated Financial Statements. See "Item 8—Financial Statements."

(b)Financial Statement Schedules. Financial statement schedules listed under the SEC rules are omitted because they are not applicable, or the required information is provided in the Notes to Consolidated Financial Statements in Item 8 of this Form 10-K.

(c)Exhibits.

Exhibit Number	Description
	(i) Exhibits filed herewith:
4.1	Description of Securities
10.1*	Form of Amended and Restated Change-In-Control Severance Agreement
19.1	DT Midstream, Inc. Insider Trading Policy
21.1	Subsidiaries of DT Midstream, Inc.
23.1	Consent of PricewaterhouseCoopers LLP
31.1	Chief Executive Officer Section 302 Form 10-K Certification of Periodic Report
31.2	Chief Financial Officer Section 302 Form 10-K Certification of Periodic Report
95.1	Mine Safety Disclosure
97.1	DT Midstream, Inc. Clawback Policy
101.INS	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	XBRL Taxonomy Extension Schema
101.CAL	XBRL Taxonomy Extension Calculation Linkbase
101.DEF	XBRL Taxonomy Extension Definition Database
101.LAB	XBRL Taxonomy Extension Label Linkbase
101.PRE	XBRL Taxonomy Extension Presentation Linkbase
104	Cover Page Interactive Data File (formatted as Inline XBRL and contained in Exhibit 101)
	(ii) Exhibits furnished herewith:
32.1	Chief Executive Officer Section 906 Form 10-K Certification of Periodic Report
32.2	Chief Financial Officer Section 906 Form 10-K Certification of Periodic Report
	(iii) Exhibits incorporated by reference:
2.1	Separation and Distribution Agreement, dated June 25, 2021, between DTE Energy Company and DT Midstream, Inc. (incorporated by reference to Exhibit 2.1 to DT Midstream’s Current Report on Form 8-K filed on July 1, 2021)
3.1	Amended and Restated Certificate of Incorporation of DT Midstream, Inc., effective July 1, 2021 (incorporated by reference to Exhibit 3.1 to DT Midstream's Current Report on Form 8-K filed on July 1, 2021)
3.2	Amended and Restated Bylaws of DT Midstream, Inc., effective July 1, 2021 (incorporated by reference to Exhibit 3.2 to DT Midstream's Current Report on Form 8-K filed on July 1, 2021)
4.2	Indenture dated as of June 9, 2021 among DT Midstream, the Guarantors and U.S. Bank National Association, as trustee. (incorporated by reference to Exhibit 4.1 to DT Midstream's Current Report on Form 8-K filed on June 10, 2021)

89

Exhibit Number	Description
	(iii) Exhibits incorporated by reference:
4.3	Indenture, dated as of April 11, 2022, among DT Midstream, Inc., the Guarantors and U.S. Bank Trust Company, National Association, as trustee. (Exhibit 4.1 to DT Midstream's Form 8-K filed April 11, 2022)
4.4	Pari Passu Intercreditor Agreement, dated as of April 11, 2022, among DT Midstream, Inc., the Guarantors, Barclays Bank PLC, as Credit Agreement Agent, and U.S. Bank Trust Company, National Association, as Notes Collateral Agent. (Exhibit 4.2 to DT Midstream's Form 8-K filed April 11, 2022)
10.2	Credit Agreement, dated as of June 10, 2021 by and among DT Midstream, as borrower, the Lenders party thereto, the L/C Issuers party thereto, and Barclays Bank PLC, as Administrative Agent and Collateral Agent (incorporated by reference to Exhibit 10.1 to DT Midstream's Current Report on Form 8-K filed on June 10, 2021)
10.3	Transition Services Agreement, dated June 25, 2021, between DTE Energy Company and DT Midstream, Inc. (incorporated by reference to Exhibit 10.1 to DT Midstream’s Current Report on Form 8-K filed on July 1, 2021)
10.4	Tax Matters Agreement, dated June 25, 2021, between DTE Energy Company and DT Midstream, Inc (incorporated by reference to Exhibit 10.2 to DT Midstream’s Current Report on Form 8-K filed on July 1, 2021)
10.5	Employee Matters Agreement, dated June 25, 2021, between DTE Energy Company and DT Midstream, Inc (incorporated by reference to Exhibit 10.3 to DT Midstream’s Current Report on Form 8-K filed on July 1, 2021)
10.6	DT Midstream, Inc. Long-Term Incentive Plan (incorporated by reference to Exhibit 10.4 to DT Midstream’s Registration Statement on Form 10-12B (File No. 001-40392), filed on May 7, 2021)
10.7	DT Midstream, Inc. Supplemental Savings Plan (incorporated by reference to Exhibit 10.1 to DT Midstream’s Annual Report on Form 10-K filed on February 16, 2023)
10.8	Form of Severance Agreement (incorporated by reference to Exhibit 10.5 to DT Midstream’s Current Report on Form 8-K filed on July 1, 2021)
10.9	DT Midstream, Inc. Annual Incentive Plan (incorporated by reference to Exhibit 10.6 to DT Midstream’s Current Report on Form 8-K filed on July 1, 2021)
10.10	Purchase Agreement, dated as of May 25, 2021, among DT Midstream, Inc., Barclays Capital Inc., as representative of the initial purchasers named therein, and the guarantors party thereto (incorporated by reference to Exhibit 10.5 to Amendment No. 2 to DT Midstream’s Registration Statement on Form 10-12B (File No. 001-40392), filed on May 26, 2021)
10.11	First Incremental Revolving Facility Amendment and Amendment No. 1 to Credit Agreement and Collateral Agreement, by and among DT Midstream, Inc., the lenders and letter of credit issuers party thereto and Barclays Bank PLC, as administrative agent and collateral agent, dated as of October 19, 2022 (incorporated by reference to Exhibit 10.1 to DT Midstream's Current Report on Form 8-K filed on October 20, 2022)
10.12	Amendment No. 2 to Credit Agreement, by and between DT Midstream, Inc., and Barclay's Bank PLC, as administrative agent and collateral agent, dated as of June 27, 2023 (incorporated by reference to Exhibit 10.1 to DT Midstream's Current Report on Form 8-K filed on June 29, 2023)

* Certain portions of this exhibit have been redacted pursuant to Item 601(b)(10)(iv) of Regulation S-K. The registrant agrees to furnish supplementally an unredacted copy of the exhibit to the Securities and Exchange Commission upon its request

Item 16. Form 10-K Summary

None.

90

Signatures

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

Date:	February 16, 2024
			DT MIDSTREAM, INC.
			(Registrant)
		By:	/S/ DAVID J. SLATER
			David J. Slater President and Chief Executive Officer of DT Midstream, Inc.

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

By:	/S/  DAVID J. SLATER	By:	/S/  JEFFREY A. JEWELL
	David J. Slater President, Chief Executive Officer, and Director (Principal Executive Officer)		Jeffrey A. Jewell Executive Vice President, Chief Financial and Accounting Officer (Principal Financial and Accounting Officer)
By:	/S/ ROBERT C. SKAGGS, JR.	By:	/S/  ANGELA ARCHON
	Robert C. Skaggs, Jr.		Angela Archon, Director
	Chairman of the Board, and Director
By:	/S/  STEPHEN BAKER	By:	/S/  ELAINE PICKLE
	Stephen Baker, Director		Elaine Pickle, Director
By:	/S/  PETER TUMMINELLO	By:	/S/ DWAYNE WILSON
	Peter Tumminello, Director		Dwayne Wilson, Director

Date: February 16, 2024

91

EX-4.1

Exhibit 4.1

DESCRIPTION OF SECURITIES

The following is a summary of the terms of our securities. This summary does not purport to be complete, nor does it represent all information which you might find to be important for understanding our capital stock. This summary is subject to, and qualified in its entirety by reference to, our amended and restated certificate of incorporation and bylaws. References to “DT Midstream,” the “Company,” “we,” “our” and “us” herein are, unless the context otherwise requires, only to DT Midstream, Inc. and not to any of its subsidiaries.

Description of Capital Stock

General

Our authorized capital stock consists of 550,000,000 shares of common stock, par value $0.01 per share and 50,000,000 shares of preferred stock, par value $0.01 per share.

The number of authorized shares of our common or preferred stock may be increased or decreased by the affirmative vote of the holders of shares of our capital stock representing a majority of the votes represented by all outstanding shares of such capital stock entitled to vote on such matter, irrespective of the provisions of Section 242(b)(2) of General Corporation Law of the State of Delaware (the “DGCL”), in addition to any vote of the holders of one or more series of our preferred stock that may be required by the terms of such preferred stock. However, the number of authorized shares of common or preferred stock to be decreased may not be decreased below the number of shares thereof then outstanding.

Common Stock

All shares of our common stock now outstanding are duly authorized, fully paid and non-assessable. Below is a summary of the rights of the common stock.

Voting Rights. The holders of common stock are entitled to one (1) vote per share on each such matter properly submitted on which the holders of common stock are entitled to vote, including the right to vote for the election of directors. The holders of shares of common stock do not have the ability to cumulate votes for the election of directors. Holders of common stock are not allowed to vote on any amendment of our amended and restated certificate of incorporation that relates only to the terms of a series of outstanding preferred stock for which the holders of such affected preferred stock have the right to vote under the certificate of incorporation or the DGCL.

Dividend Rights. Subject to preferences that may apply to shares of preferred stock outstanding at the time, the holders of outstanding shares of our common stock are entitled to receive dividends out of assets or funds legally available if our board of directors, in its discretion, determines to issue dividends and only then at the times and in the amounts that the board of directors may determine.

Right to Receive Liquidation Distributions. Upon our dissolution, liquidation or winding-up, the assets legally available for distribution to our stockholders are distributable ratably among the holders of common stock, subject to prior satisfaction of all outstanding debt and liabilities and the preferential rights and payment of liquidation preferences, if any, on any outstanding shares of preferred stock.

No Preemptive or Similar Rights. The common stock is not entitled to preemptive rights or preferential rights and is not subject to redemption or sinking fund provisions.

No Ownership Limitations or Transfer Restrictions. The common stock is not subject to any limitation on the amount of securities that may be held by holders, and the common stock is not by its terms subject to any transfer restrictions.

Preferred Stock

Under our amended and restated certificate of incorporation, our board of directors may, without further action by our stockholders, fix the rights, preferences, privileges and restrictions of up to an aggregate of 50,000,000 shares of preferred stock in one or more series and authorize their issuance. These rights, preferences and privileges could include dividend rights, conversion rights, voting rights, terms of redemption, liquidation preferences and the number of shares constituting any series or the designation of such series, any or all of which may be greater than the rights common stock. Any issuance of our preferred stock could adversely affect the voting power of holders of our common stock and the likelihood that such holders would receive dividend payments and payments on liquidation. In addition, the issuance of preferred stock could have the effect of delaying, deferring or preventing a change of control or other corporate action, as further described below. We currently have no shares of preferred stock outstanding and we have no present plan to issue any shares of preferred stock.

Anti-takeover Effects of Delaware Law and Governance Provisions

Certain provisions of Delaware law and our amended and restated certificate of incorporation and bylaws may be deemed to have an anti-takeover effect and may delay, defer or prevent a tender offer or change in control that a stockholder might consider to be in its best interests, including attempts that might result in a premium being paid over the market price for the shares held by stockholders. These provisions are intended to enhance the likelihood of continuity and stability in the composition of our board of directors and in the policies formulated by our board of directors and could discourage certain types of transactions that may involve an actual or threatened change of control:

•Classified Board.Our amended and restated certificate of incorporation provides that, until the election of directors at the 2024 annual meeting of stockholders, our board shall be divided into three classes of directors, Class I, Class II and Class III (each class as nearly equal in number as possible), with the directors in Class I having a term initially expiring at the 2022 annual meeting of stockholders, the directors in Class II having a term initially expiring at the 2023 annual meeting of stockholders and the directors in Class III having a term expiring at the 2024 annual meeting of stockholders, and in each case until his or her respective successor shall have been duly elected and qualified. The initial assignment of directors to each such class shall be made by the board. Each director elected at the 2022 or 2023 annual meeting of stockholders shall belong to the same class of the director whose term shall have then expired and who is being succeeded by such director. Each Class I director elected at the 2022 annual meeting of stockholders and each Class II director elected at the 2023 annual meeting of stockholders shall hold office until the 2024 annual meeting of stockholders and in each case until his or her respective successor shall have been duly elected and qualified. At all times prior to the 2024 annual meeting of stockholders or such other time as the board is no longer classified under section 141(d) of the DGCL (or any successor provision thereto), any newly created directorships or any decrease in directorships shall be apportioned among the classes by the board as to make all classes as nearly equal in number as possible. Commencing with the 2024 annual meeting of stockholders or such other time as the board is no longer classified under Section 141(d) of the DGCL (or any successor provision thereto), each director shall be elected annually and shall hold office until the next succeeding annual meeting of stockholders and until his or her respective successor shall have been duly elected and qualified. Before our board is declassified, it would take at least two annual stockholder meetings to occur for any individual or group to gain control of our board. Accordingly, while the board is divided into classes, these provisions could discourage a third-party from initiating a proxy contest, making a tender offer or otherwise attempting to control our board.

•Removal and Vacancies; Size of Board.Our amended and restated certificate of incorporation and bylaws provide that, subject to the rights of holders of any series of preferred stock with respect to the election of directors, any removal of a director by the stockholders shall require the affirmative vote of the majority in voting power of all of outstanding stock then entitled to vote thereon. A director may be removed from office at any time by the stockholders (i) at all times prior to the 2024 annual meeting of stockholders or such other time as the board is no longer classified under Section 141(d) of the DGCL (or any successor provision thereto), only for cause and (ii) commencing with the 2024 annual meeting of stockholders or

such other time, with or without cause. Vacancies occurring on the board for any reason and newly created directorships resulting from an increase in the number of directors may be filled only be a vote of the majority of the remaining members of the board, although less than a quorum, or by a sole remaining director, at any meeting of the board, and not by the stockholders. In addition, our amended and restated certificate of incorporation and bylaws provide that the number of directors that shall constitute the entire board shall be fixed, from time to time, exclusively by the board, subject to the rights that may apply to shares of preferred stock outstanding at the time with respect to the election of directors, if any. These provisions will prevent a stockholder from increasing the size of the board of directors and gaining control of the board of directors by filling the resulting vacancies with its own nominees.

•Preferred Stock. Our amended and restated certificate of incorporation authorizes the board to issue from time to time shares of preferred stock in one or more series pursuant to a resolution or resolutions without further action by the stockholders. These terms may include powers, designations, preferences and relative, participating, optional or other special rights, if any, and the qualifications, limitations or restrictions thereof, if any, of any wholly unissued series of preferred stock, including, without limitation, dividend rights, dividend rate, conversion rights, voting rights, rights and terms of redemption (including, without limitation, sinking fund provisions), redemption price or prices and liquidation preferences of any such series, and the number of shares constituting any such series and the designation thereof, or any of the foregoing. The issuance of any preferred stock could diminish the rights of holders of common stock and therefore could reduce the value of such common stock. The ability of the board of directors to issue preferred stock could make it more difficult, delay, discourage, prevent or make it more costly to acquire or effect a change-in-control, which in turn could prevent stockholders from recognizing a gain in the event that a favorable offer is extended and could materially and negatively affect the market price of our common stock.

•No Action by Written Consent of Stockholders. Subject to the rights that may apply to holders of shares of preferred stock outstanding at the time, our amended and restated certificate of incorporation and bylaws expressly exclude the right of our stockholders to act by written consent. Stockholder action must therefore take place at an annual or special meeting of the stockholders.

•No Stockholder Ability to Call Special Meetings. Our amended and restated certificate of incorporation and bylaws provide that, subject to the rights that may apply to holders of shares of preferred stock outstanding at the time, special meetings of the stockholders may be called only by the chairperson of the board, the chief executive officer or the board. Our stockholders are not able to call a special meeting of the stockholders.

•Requirements for Advance Notification of Stockholders Nominations and Proposals.Our amended and restated bylaws require stockholders seeking to nominate persons for election as directors at an annual or special meeting of stockholders, or to bring other business before an annual or special meeting (other than a proposal submitted under Rule 14a-8 under the Securities Exchange Act of 1934, as amended (the “Exchange Act”)), to provide timely notice in writing. A stockholder’s notice to the Secretary must be in proper written form and must set forth certain information, as required under our amended and restated bylaws, related to the stockholder giving the notice, the beneficial owner (if any) on whose behalf the nomination is made as well as their control persons and information about the proposal or nominee for election to the board of directors. Although our amended and restated bylaws do not give the board of directors the power to approve or disapprove stockholder nominations of candidates or proposals regarding other business to be conducted at a special or annual meeting, the bylaws may have the effect of precluding the conduct of certain business at a meeting if the proper procedures are not followed or may discourage or deter a potential acquirer from conducting a solicitation of proxies to elect its own slate of directors or otherwise attempting to obtain control of us.

•Amendments to Bylaws. Our amended and restated certificate of incorporation and bylaws provides that the board is expressly authorized to adopt, amend, alter or repeal the amended and restated bylaws without stockholder vote.

Charter Exclusive Forum Provisions

Our amended and restated certificate of incorporation provides that, unless we consent in writing to the selection of an alternative forum, the Court of Chancery of the State of Delaware shall, to the fullest extent permitted by law, be the sole and exclusive forum for (i) any derivative action or proceeding brought on behalf of us; (ii) any action asserting a claim of breach of a fiduciary duty owed by any of our current or former directors, officers, employees or stockholders to us or our stockholders; (iii) any action or proceeding asserting a claim arising pursuant to, or seeking to enforce any right, obligation or remedy under, any provision of Delaware law (as may be amended from time to time) or the amended and restated certificate of incorporation or our amended and restated bylaws; (iv) any action or proceeding asserting a claim against us, any of our directors, officers or other employees or stockholders governed by the internal affairs doctrine of the laws of the State of Delaware or any other action asserting an “internal corporate claim” as that term is defined in Section 115 of the DGCL (or any successor provision thereto); or (v) any action or proceeding as to which the DGCL confers jurisdiction on the Court of Chancery of the State of Delaware. The Delaware exclusive forum provision described in the foregoing sentence does not apply to actions arising under the Exchange Act or the Securities Act of 1933, as amended (the “Securities Act”). In this regard, it is noted that 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 promulgated thereunder and, further, that investors cannot waive compliance with the federal securities laws and the rules and regulations thereunder. It is further noted that our amended and restated certificate of incorporation also provides that, unless we consent in writing to the selection of an alternative forum, the U.S. federal district courts shall, to the fullest extent permitted by applicable law, be the exclusive forum for the resolution of any complaint asserting a cause of action arising under U.S. federal securities laws. Although our amended and restated certificate of incorporation contains the federal exclusive forum provision described in the foregoing sentence, it is uncertain whether this provision would apply to actions arising under the Securities Act as it is possible that a court could rule that such provision is inapplicable for a particular claim or action or that such provision is unenforceable, particularly in light of Section 22 of the Securities Act, which creates concurrent jurisdiction for federal and state courts over all suits brought to enforce any duty or liability created by the Securities Act or the rules and regulations promulgated thereunder.

Transfer Agent

We have appointed Equiniti Trust Company as the transfer agent for our common stock. Its address is 1110 Centre Pointe Curve, Suite 101, Mendota Heights, Minnesota 55120 and its telephone number is toll free 833-914-2118.

Listing

Our common stock is listed on the New York Stock Exchange under the trading symbol “DTM.”

EX-10.1

Exhibit 10.1

AMENDED AND RESTATED CHANGE-IN-CONTROL SEVERANCE AGREEMENT

This AMENDED AND RESTATED CHANGE-IN-CONTROL SEVERANCE AGREEMENT (the “Agreement”) is entered into as of December 21, 2023 (the “Effective Date”) between DT Midstream, Inc., a Delaware corporation (the “Company”), and {EXECUTIVE} (the “Executive”).

RECITALS

The Executive is an executive or a key employee of the Company or one or more of its Subsidiaries and has made and is expected to continue to make major contributions to the short- and long-term profitability, growth and financial strength of the Company.

The Company recognizes that, as is the case for most publicly held companies, the possibility of a Change-in-Control exists and that potential employment uncertainty resulting from a Change-in-Control may distract management from conducting the Company’s business or cause management employees to leave the Company.

The Company wants to provide security to its senior executives and key employees to enable them to discharge their duties during the consideration and consummation of a Change-in-Control in order to preserve the value of the Company for its shareholders.

In consideration of these objectives, the Company and the Executive agree as follows:

1.Term of Agreement. The term of this Agreement (the “Term”) begins on the Effective Date and ends on the earlier of:

(a)the later of:

(1)the Agreement Expiration Date; or

(2)the last day of the Severance Period.

or

(b)the date prior to a Change-in-Control on which the Executive ceases for any reason to be an employee of the Company and any Subsidiary. For purposes of this Section 1(b), the Executive does not cease to be an employee of the Company and any Subsidiary if the Executive’s employment is transferred between the Company and any Subsidiary, or among any Subsidiaries.

2.Right to Receive Severance Benefits and Other Consideration. The Executive will become entitled to the severance benefits and other consideration provided under this Agreement if the Executive’s employment is terminated because of a Qualifying Termination.

3.Severance Benefits and Other Consideration.

(a)Severance Benefits. The Severance Benefits payable under this Agreement are all the following:

(1)A lump sum payment equal to X% of the sum of:

(A)Base Salary; plus

(B)[the greater of:

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(i)the Annual Bonus for the year in which the Change-in-Control occurs; or

(ii)the Annual Bonus for the year in which the Termination Date occurs,

in either case based on the assumption that target performance goals for the applicable year would be met and the Executive was employed for the entire year or until any later date required to receive the payment;]

(2)A lump sum payment equal to:

(A)[the greater of:

(i)the actual Annual Bonus or target Annual Bonus, whichever is higher, for the year in which the Change-in-Control occurs; or

(ii)the actual Annual Bonus or target Annual Bonus, whichever is higher, for the year in which the Termination Date occurs,

in either case calculated based on the assumption that the Executive was employed for the entire year or until any later date required to receive such payment,]

(B)multiplied by the following fraction:

(i)the numerator is the number of days prior to the Executive’s Termination Date during the calendar year in which the Termination Date occurs; and

(ii)the denominator is 365,

(C)then reduced by the Annual Bonus for the year in which the Termination Date occurs that is payable to the Executive under the terms of the Annual Incentive Plan if the Executive has attained age 55 and completed 10 years of service with the Company and all Subsidiaries.

(3)For Welfare Benefits provided to the Executive immediately prior to the Executive’s Termination Date (or, if greater, immediately prior to reduction, termination, or denial), a lump sum payment equal to the present value of the cost of coverage for the Benefit Continuation Period. The cost of coverage will be determined at rates in effect as of the Termination Date. The present value of the cost will be determined using an interest rate equal to the composite prime rate in effect as of the Termination Date in the Northeast Edition of The Wall Street Journal.

(4)Outplacement services by a firm selected by the Executive, at a cost to the Company in an amount up to 15% of the Executive’s Base Salary. No payments by the Company for outplacement services will be made after December 31st of the calendar year following the calendar year including the Termination Date and no additional monetary compensation will be granted in lieu of using outplacement services.

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(5)Any outstanding equity-based awards will be subject to the terms and conditions of the LTIP and any applicable award document.

(b)Other Consideration. The consideration for the restrictive covenant in Section 9(d) (Competitive Activity) is a lump sum payment equal to:

(1)X% of the sum of:

(A)Base Salary; plus

(B)the greater of:

(i)the actual Annual Bonus or target Annual Bonus, whichever is higher, for the year in which the Change-in-Control occurs; or

(ii)the actual Annual Bonus or target Annual Bonus, whichever is higher, for the year in which the Termination Date occurs,

in either case calculated based on the assumption that the Executive was employed for the entire year or until any later date required to receive such payment,]

4.Timing of Payments.

(a)Payments under the following Sections will be paid on the later of 60 days after the Executive’s Termination Date or any later date required by Code Section 409A or any other law:

(1)Section 3(a)(1);

(2)Section 3(a)(2);

(3)Section 3(a)(3);

(4)Section 3(a)(4); and

(5)Section 3(b);

Notwithstanding anything in this Agreement to contrary, consideration provided under Section 3(a)(5) above will be paid in accordance with the terms of the LTIP.

(b)Withholding of Taxes. The Company will withhold from any amounts payable under this Agreement all federal, state, city or other taxes that the Company is required to withhold under any law or government regulation or ruling.

(c)Interest. If the Company fails to make any payment or provide any benefit required to be made or provided under this Agreement on a timely basis, the Company will pay interest on the amount or value at an annualized rate of interest equal to the composite prime rate as quoted from time to time during the relevant period in the Northeast Edition of The Wall Street Journal. The interest is payable as it accrues on demand, but the Company is not required to pay interest more frequently than monthly. Any change in the prime rate will be effective on and as of the date of the change.

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(d)Severance Benefits Not Included in Other Compensation. The lump sum payments referenced in Section 3 above will not be included in Executive’s earnings or compensation for purposes of calculating any benefits to which the Executive may be entitled to under any other employee benefit plan or program, including but not limited to any qualified or non-qualified defined contribution plan calculation, post-employment benefit calculation, or 401(k) calculation.

5.Non-Duplication of Severance Benefits and Other Consideration.

(a)Qualifying Termination During Concurrent Severance Periods. If the Executive experiences a Qualifying Termination when two or more Severance Periods are running concurrently, as applicable (because two or more Changes-in-Control have occurred), the Executive will have a Qualifying Termination with respect to each Severance Period. A determination of the payments and benefits to be provided under the Agreement will be made for each Qualifying Termination. However, the Executive will receive only:

(1)the greatest lump sum payment under Section 3(a)(1) payable for any Qualifying Termination;

(2)the greatest lump sum payment under Section 3(a)(2) for any Qualifying Termination;

(3)the greatest lump sum payment under Section 3(a)(3) for any Qualifying Termination;

(4)one instance of outplacement assistance under Section 3(a)(4);

(5)the greatest of payments regarding any outstanding equity-based awards as called for under the terms and conditions of the LTIP and any applicable award document; and

(6)the greatest lump sum payment under Section 3(b) for any Qualifying Termination;

(b)Effect on Other Employee Benefits. The Executive’s Qualifying Termination will not affect any rights the Executive may have under any agreement, policy, plan, program or arrangement of the Company or Subsidiary providing Employee Benefits (other than Severance Pay), which rights are governed by the terms of the agreement, policy, plan, program or arrangement. The benefits received by an Executive under this Agreement because of a Qualifying Termination supersede and are in lieu of any other Severance Pay to which the Executive may be entitled.

6.No Mitigation.

The Company acknowledges that it will be difficult and may be impossible for the Executive to find reasonably comparable employment following the Termination Date. Accordingly, the Company acknowledges that payment of the severance compensation by the Company to the Executive under this Agreement is reasonable. The Executive is not required to mitigate the amount of any payment provided for in this Agreement by seeking other employment or otherwise. No profits, income, earnings or other benefits from any source will create any mitigation, offset, reduction or other obligation on the part of the Executive, except as may have been otherwise paid to the Executive by the Company or a Subsidiary in connection with or in consideration of Executive’s release and settlement of any claims arising out of the Executive’s employment or the termination of the Executive’s employment.

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7.Arbitration; Legal Fees and Expenses.

(a)Except for legal proceedings brought by the Executive or the Company for injunctive relief, any dispute or claim involving this Agreement will be submitted to final and binding arbitration. The arbitration will take place in Oakland County, Michigan before a single neutral arbitrator under the then-current National Rules for the Resolution of Employment Disputes of the American Arbitration Association. The arbitrator will issue a written opinion and will not have authority to render an award beyond the scope and specific terms of this Agreement. Judgment upon the arbitrator’s award may be entered in any court of competent jurisdiction. Any demand for arbitration must be made within 30 days of when the party knew or should have known of the alleged dispute or claim. Failure to timely demand arbitration makes the dispute or claim non-arbitrable. The Executive and the Company expressly waive their rights to institute or prosecute any lawsuits or other court proceedings and waive their right to a jury trial, except for the legal proceedings excluded above.

(b)It is the intent of the Company that the Executive not be required to incur legal fees and the related expenses associated with the interpretation, enforcement or defense of Executive’s rights under this Agreement because the legal fees and related expenses would substantially detract from the benefits intended to be extended to the Executive under this Agreement.

(c)If it appears to the Executive that the Company has failed to comply with any of its obligations under this Agreement or if the Company or any other person takes or threatens to take any action to declare this Agreement void or unenforceable, or institutes any action or proceeding designed to deny, or to recover from, the Executive the benefits provided or intended to be provided to the Executive under this Agreement, the Company irrevocably authorizes the Executive to retain counsel of Executive’s choice, at the expense of the Company as provided in this Section 7, to advise and represent the Executive in connection with any interpretation, enforcement or defense of the Executive’s rights under this Agreement.

(d)The Executive may pursue any legal defense of the Executive’s rights under this Agreement whether by or against the Company or any Director, officer, stockholder or other person affiliated with the Company, in any jurisdiction.

(e)Whether or not the Executive prevails in connection with any defense of the Executive’s rights under this Agreement, the Company will pay and be solely financially responsible for reasonable hourly attorneys’ fees and related fees and expenses incurred by the Executive under this Section 7, but only if the arbitrator determines the Executive’s claim was brought in good faith and was not frivolous. If the Executive’s request for injunctive relief is denied and the Executive does not timely demand arbitration for the dispute or claim underlying the Executive’s request for injunctive relief, the Executive’s request for injunctive relief is deemed to be frivolous and not brought in good faith for purposes of this Section 7(e).

(f)The Company’s payment of the Executive’s legal fees and expenses under this Section 7 following termination of the Executive’s employment (whether or not in a

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Qualifying Termination) will be made during the first calendar year beginning after the date the Executive’s employment terminated.

8.Survival of Rights and Obligations.

The rights and obligations of the Executive and the Company under the following Sections will survive the termination or expiration of this Agreement and the termination of the Executive’s employment after a Change-in-Control for any reason:

(a)Section 2 (Right to Receive Severance Benefits and Other Consideration);

(b)Section 3 (Severance Benefits and Other Consideration);

(c)Section 4 (Timing of Payments);

(d)Section 5 (Non-Duplication of Severance Benefits and Other Consideration);

(e)Section 6 (Mitigation);

(f)Section 7 (Legal Fees); and

(g)Section 20 (Definitions).

9.Confidential Information; Non-Disparagement; Non-Solicitation; Competitive Activity.

(a)Confidential Information. At all times following the Termination Date, the Executive will not, without the prior written consent of the Company, either directly or indirectly use, appropriate, or disseminate, disclose, or communicate to any person or entity any confidential information of the Company or any Subsidiary that is now known or later becomes known to the Executive because of the Executive’s employment with the Company or any Subsidiary, unless the disclosure is required by a valid subpoena or order issued by a court or governmental body.

(1)For purposes of this Section 9(a), “confidential information” is any confidential, proprietary, or trade secret information, including concepts, ideas, information, and materials related to the Company or any Subsidiary, customer records, customer lists, economic and financial analyses, financial data, customer contracts, marketing plans, notes, memoranda, lists, books, correspondence, manuals, reports or research, whether developed by the Company or a Subsidiary or developed by the Executive while employed by the Company or a Subsidiary.

(2)This Section 9(a) does not apply to any confidential information that becomes publicly disseminated by means other than a breach of this provision.

(b)Non-Disparagement. The Executive will not make any verbal or written comments to any third party that are defamatory, disparaging, or critical of the Company or any Subsidiary or its products, management, employees, officers or operations or that would otherwise adversely affect the finances or business reputation of the Company or any Subsidiary.

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(c)Non-Solicitation.

(1)For a period of two years after the Termination Date, the Executive will not solicit, divert, take away, or attempt to take away any customer of the Company or any Subsidiary or the business of any customer of the Company or any Subsidiary.

(A)A “customer” of the Company or any Subsidiary is any person or other entity to which the Company or any Subsidiary has sold services or products during the 24-month period immediately preceding the Termination Date, any person or other entity that the Company or any Subsidiary is in the process of selling services or products, or any person or other entity to which the Company or any Subsidiary has submitted or is in the process of submitting a bid to sell services or products.

(2)For a period of two years after the Termination Date, the Executive will not solicit, attempt to employ, or employ any individual who is an employee, consultant, or agent of the Company or any Subsidiary.

(d)Competitive Activity. For a period of one year following the Termination Date, the Executive will not engage in any Competitive Activity. If the Executive engages in any Competitive Activity earlier than one year following the Termination Date, the Executive must repay to the Company the consideration paid to the Executive under Section 3(b).

(e)Whistleblower Rights. Notwithstanding anything to the contrary in the foregoing, the Executive has the right under federal and state law to certain protections for cooperating with or reporting legal violations to various governmental entities. No provision in this Agreement (including this Section 9) prohibits the Executive, is intended to prohibit the Executive or should be construed or deemed to prohibit the Executive from filing a charge with, reporting violations to or cooperating or participating in an investigation with, any governmental entity or disclosing this Agreement to any governmental entity in connection therewith, and the Executive may do so without disclosure to the Company. The Company may not retaliate against the Executive, cause the Executive to forfeit or return any compensation or benefits otherwise payable to the Executive or require the Executive to pay any liquidated damages for any of these activities, and nothing in this Agreement would require the Executive to waive any monetary award or other payment that the Executive might become entitled to from any governmental entity. Nothing contained in this Agreement prohibits or prevents the Executive from, or places limitations or restrictions on the Executive or is intended to prohibit or prevent the Executive from, or place limitations or restrictions on the Executive: (i) filing a charge with or participating, testifying or assisting in any investigation, hearing, whistleblowing proceeding or other proceeding before any government agency (including the Equal Employment Opportunity Commission, the National Labor Relations Board or the Securities and Exchange Commission), including communicating directly with the Securities and Exchange Commission staff about possible securities law violations; (ii) making truthful statements or disclosures about alleged unlawful employment practices, retaliation, wage and hour violations or workplace discrimination, harassment, sexual harassment or assault, or any other law that is enforced by the Equal Employment Opportunity Commission or similar state agency; or (iii) making any disclosure or statement that an employer may not contractually prohibit an employee from making under applicable law, including under Section 7 of the National Labor Relations Act or any applicable state law.

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10.Employment Rights.

This Agreement is not intended to constitute a contract of employment for any specific term or period. Nothing in this Agreement creates any right or duty on the part of the Company or the Executive to have the Executive remain in the employment of the Company or any Subsidiary prior to or following any Change-in-Control.

11. Successors and Binding Agreement.

(a)The Company will require any successor (whether direct or indirect, by purchase, merger, consolidation, reorganization or otherwise) to all or substantially all of the business or assets of the Company, by agreement in form and substance satisfactory to the Executive, to expressly assume and agree to perform this Agreement in the same manner and to the same extent the Company would be required to perform it if the succession had not taken place. This Agreement will be binding upon and inure to the benefit of the Company and any successor to the Company, including without limitation any person acquiring directly or indirectly all or substantially all of the business or assets of the Company by purchase, merger, consolidation, reorganization or otherwise, with the successor thereafter deemed to be the “Company” for the purposes of this Agreement. Other than as permitted under this Section 11(a), this Agreement is not assignable, transferable or delegable by the Company.

(b)This Agreement will inure to the benefit of and be enforceable by the Executive’s personal or legal representatives, executors, administrators, successors, heirs, distributees and legatees.

(c)This Agreement is personal in nature and neither of the parties may, without the consent of the other, assign, transfer or delegate this Agreement or any rights or obligations hereunder except as expressly provided in Sections 11(a) and 11(b). The Executive’s right to receive payments under the Agreement is not assignable, transferable or delegable, including by pledge, creation of a security interest, or otherwise, other than by a transfer by Executive’s will or by the laws of descent and distribution. If any assignment or transfer not permitted by this Section 11(c) is attempted, the Company will have no liability to pay any amount attempted to be assigned, transferred or delegated.

12. Notices.

(a)All communications, including notices, consents, requests or approvals, required or permitted to be given under this Agreement must be in writing.

(b)All notices must be provided by:

(1)hand delivery (deemed provided when delivered);

(2)electronic mail transmission, with verbal confirmation of receipt;

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(3)United States registered or certified mail, return receipt requested, postage prepaid (deemed provided five business days after mailing); or

(4)a nationally recognized overnight courier service such as Federal Express or UPS (deemed provided three business days after deposit with courier service).

(c)Notices to the Company must be addressed to the attention of the highest-ranking Human Resources official of the Company at the Company’s principal executive office.

(d)Notices to the Executive must be addressed to the Executive at the Executive’s principal residence.

(e)The Company or the Executive can change the address to which notices to that party are to be addressed by providing notice to the other party as required under this Section 12, except that notices of changes of address are effective only upon actual receipt.

13.Governing Law.

The validity, interpretation, construction and performance of this Agreement will be governed by and construed in accordance with the substantive laws of the State of Michigan without giving effect to its principles of conflict of laws.

14.Validity.

If any provision of this Agreement or the application of any provision to any person or circumstances is held invalid, unenforceable or otherwise illegal by a court of competent jurisdiction, the remainder of this Agreement and the application of the provision to any other person or circumstances will not be affected. The provision held to be invalid, unenforceable or otherwise illegal will be amended to the minimum extent necessary to make it enforceable, valid or legal.

15.Miscellaneous.

(a)No provision of this Agreement may be modified, waived or discharged unless the waiver, modification or discharge is agreed to in writing signed by the Executive and the Company.

(b)No waiver by either party at the time of any breach by the other party or compliance with any condition or provision of this Agreement to be performed by the other party will be a waiver of similar or dissimilar provisions or conditions at the same or at any prior or subsequent time.

(c)This Agreement contains the entire agreement between Executive and the Company regarding the subject herein and fully supersedes any and all prior agreements or understandings, whether oral or written, between Executive and the Company pertaining to the subject matter addressed in this Agreement.

(d)References to Sections are to references to Sections of this Agreement.

16.Prior Agreements.

As of the Effective Date, this Agreement supersedes and replaces all prior change-in-control severance agreements and similar agreements between the Executive and the Company or

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any of its Subsidiaries (“Prior Agreements”). Any and all Prior Agreements cease to be of force and effect as of the Effective Date.

17.Counterparts.

This Agreement may be executed in one or more counterparts, each of which is deemed an original but all of which together will constitute one agreement.

18.Section 280G.

This Section 18 will apply if the Executive is a “disqualified individual” within the meaning of Section 1.280G-1, Q/A-15 of the Treasury regulations. In the event of an event constituting a change in the ownership or effective control of the Company or ownership of a substantial portion of the assets of the Company described in Section 280G(b)(2)(A)(i) of the Code, the Company, at its sole expense, will cause its independent auditors promptly to review all payments, accelerations, distributions and benefits that have been made to or provided to, and are to be made, or may be made, to or provided to, the Executive under the Agreement (irrespective of whether severance payment and benefits or other payments and benefits are then payable to the Executive at that time), and any other agreement or plan under which the Executive may individually or collectively benefit (collectively the “Original Payments”), to determine the applicability of Section 4999 of the Code to the Executive in connection with such event. The Company’s independent auditors will perform this analysis in conformity with the foregoing provisions and will provide the Executive with a copy of their analysis and determination. Notwithstanding anything contained in this Agreement to the contrary, to the extent that the Original Payments would be subject to the excise tax imposed under Section 4999 of the Code (the “Excise Tax”), the Original Payments will be reduced (but not below zero) to the extent necessary so that no Original Payment will be subject to the Excise Tax, but only if, by reason of such reduction, the net after-tax benefit received by the Executive will exceed the net after-tax benefit received by him or her if no such reduction was made. For purposes of this Agreement, “net after-tax benefit” will mean (a) the Original Payments which the Executive receives or is then entitled to receive from the Company that would constitute “parachute payments” within the meaning of Section 280G of the Code, less (b) the amount of all federal, state and local income taxes payable with respect to the foregoing calculated at the maximum marginal income tax rate for each year in which the foregoing will be paid to the Executive (based on the rate in effect for such year as set forth in the Code as in effect at the time of the first payment of the foregoing), less (c) the amount of the Excise Tax imposed with respect to the payments and benefits described in (a) above. If a reduction is required by this provision, the payments and benefits will be reduced in the following order: any cash severance to which the Executive becomes entitled (starting with the last payment due), then other cash amounts that are parachute payments (starting with the last payment due), then any stock option awards that have exercise prices higher than the then-fair market value price of the stock (based on the latest vesting tranches), then restricted stock and restricted stock units based on the latest awards scheduled to be distributed, and then other stock options based on the latest vesting tranches. The fees and expenses of the Company’s auditor for its services in connection with the determinations and calculations contemplated by this provision will be borne by the Company.

19.Section 409A.

The Company intends that all payments and benefits provided under this Agreement or otherwise are exempt from, or comply with, the requirements of Code Section 409A so that none of the payments or benefits will be subject to the additional tax imposed under Code

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Section 409A, and any ambiguities herein will be interpreted in accordance with such intent. For purposes of Code Section 409A, each payment, installment or benefit payable under this Agreement is hereby designated as a separate payment. “Termination of employment,” “resignation” or words of similar import, as used in this Agreement shall mean, with respect to any payments subject to Code Section 409A, the Executive’s “separation from service” as defined by Code Section 409A. If any payment subject to Code Section 409A is contingent on the delivery of a release by the Executive and could occur in either of two years, the payment will occur in the later year. In addition, if the Company determines that Executive is a “specified employee” under Code Section 409A(a)(2)(B)(i) at the time of Executive’s separation from service, then (i) any severance payments or benefits, to the extent that they are subject to Code Section 409A, shall be paid the first business day after the end of such six-month period, or, if earlier, within 30 days after the Executive’s death and (ii) any installments that otherwise would have been paid or provided prior to such date will be paid or provided in a lump sum when the severance payments or benefits commence.

20.Definitions.

For purposes of this Agreement, the following definitions apply:

(a)Agreement Expiration Date is the later of:

(1)the day before the third anniversary of the Effective Date; or

(2)the last day of any extension of the Agreement under this Section 20(a).

(3)Beginning onthe third anniversary of the Effective Date and on each subsequent anniversary of the Effective Date, this Agreement will automatically be extended for an additional year unless, not later than 90 days before any anniversary of the Effective Date the Company gives notice that it does not wish to have the Term extended; at which time this Agreement will stay in effect for a period of two years and then expire.

(b)Annual Bonus is the aggregate annual bonus to which the Executive would have been entitled under the DT Midstream, Inc. Annual Incentive Plan a Subsidiary’s annual incentive plan, or any successor annual incentive plan (an “Annual Plan”) in the applicable year, presuming that the Executive’s individual performance multiplier is 100%.

(c)Base Salary is the Executive’s annual base salary (prior to any pre-tax deferrals made under any employee benefit plans of the Company), and as in effect immediately prior to the Change-in-Control or immediately prior to the Executive’s Termination Date, if higher.

(d)Benefit Continuation Period is the two-year period beginning on the Executive’s Termination Date.

(e)Board is the Board of Directors of the Company.

(f)Cause. The Executive’s employment will be considered terminated for Cause if prior termination of the Executive’s employment, the Authorized Entity reasonably determines, based on a preponderance of the evidence reasonably to the Authorized Entity as of the date the Authorized Entity adopts the resolution described below, that the Executive committed or engaged in:

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For {EXECUTIVE}

(1)an intentional act of fraud, embezzlement or theft at a level that constitutes a felony in connection with the Executive’s duties or in the course of the Executive’s employment with the Company or a Subsidiary, whether or not the Executive is convicted or pleads guilty or nolo contender (no contest) to any related criminal charges;

(2)intentional wrongful damage to property of the Company or a Subsidiary;

(3)intentional wrongful disclosure of secret processes or confidential information of the Company or a Subsidiary;

(4)intentional wrongful engagement in any Competitive Activity;

(5)willful and continued failure by the Executive to substantially perform the Executive’s duties with the Company that is not cured within 30 days after the Authorized Entity delivers to the Executive a written demand for substantial performance specifically identifying the Executive’s failure to perform;

(6)acts or omissions that cause material damage to the business or financial reputation of the Company or a Subsidiary; or

(7)other intentional activity, including but not limited to a breach of the Executive’s fiduciary duties with respect to the Company, a Subsidiary, or any welfare plan or pension plan sponsored by the Company or a Subsidiary;

which, in the reasonable judgment of the Authorized Entity and based on a preponderance of the evidence available to the Authorized Entity is significantly detrimental to the reputation, goodwill or business of the Company or significantly disrupts the workplace environment or operation of the Company’s business or administrative activities.

For purposes of this Section 20(f), no act or failure to act on the part of Executive will be deemed “intentional” if it was due primarily to an error in the Executive’s judgment or the Executive’s negligence. An act will be deemed “intentional” only if done or omitted to be done by the Executive not in good faith and without reasonable belief that the Executive’s action or omission was in the best interest of the Company.

For purposes of this Section 20(f), the Executive has not been terminated for Cause unless and until:

(8)If the Authorized Entity is the Board or a committee created by the Board:

(A)A meeting of the Authorized Entity is called and held for the purpose of determining if the Executive is to be terminated for Cause; and

(B)The Executive is given reasonable notice of the meeting and an opportunity to be heard before the Authorized Entity, with Executive’s counsel if the Executive so chooses; and

(C)At that meeting the Authorized Entity finds, in the good faith opinion of the Authorized Entity, that the Executive has committed an act entitling the Authorized Entity to terminate the Executive’s employment for Cause; and

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For {EXECUTIVE}

(D)The Executive has been provided a copy of the resolution duly adopted at that meeting by the affirmative vote of not less than three-quarters of the Authorized Entity and specifying in detail the particulars of the Authorized Entity’s finding.

(9)If the Authorized Entity is an individual:

(A)The Authorized Entity has made a preliminary determination, in good faith, that the Executive has committed an act entitling the Authorized Entity to terminate the Executive’s employment for Cause; and

(B)The Authorized Entity gives the Executive reasonable notice of a meeting between the Authorized Entity and the Executive, and the Executive’s counsel if the Executive so chooses, with the meeting notice including the Authorized Entity’s preliminary determination; and

(C)At the meeting the Executive, and the Executive’s counsel if the Executive so chooses, is given the opportunity to be heard regarding the Authorized Entity’s preliminary determination; and

(D)After the meeting, the Authorized Entity makes a final determination, in good faith, that the Executive has committed an act entitling the Authorized Entity to terminate the Executive’s employment for cause; and

(E)The Authorized Entity provides the Executive written notice specifying in detail the particulars of the Authorized Entity’s final determination.

Executive and the Executive’s beneficiaries retain the right to contest the validity or propriety of the Authorized Entity’s determination that the Executive’s employment was terminated for Cause.

For purposes of this Section 20(f), the Authorized Entity is the Board. However, the Board, in its discretion, may delegate in writing to the Chief Executive Officer, the President of the Company, the chief Human Resources Officer of the Company, or a committee (created for this purpose) the Board’s authority and duties under Section 20(f) as the Authorized Entity with respect to determining if Executive has terminated for Cause.

(g)Change-in-Control occurs if any of the following events occurs during the Term of this Agreement:

(1)The consummation of a transaction in which the Company is merged, consolidated or reorganized into or with another corporation or other legal person (the “Surviving Entity”), and as a result of the transaction less than 50% of the combined voting power of the then-outstanding Voting Stock of the Surviving Entity immediately after the transaction is held in the aggregate by the holders of Voting Stock of the Company immediately prior to the transaction; or

(2)The consummation of a sale or transfer in which the Company sells or otherwise transfers all or substantially all of its assets to another corporation or other legal person (the “Acquiring Entity”), and as a result of the sale or transfer less than 50% of the combined voting power of the then-outstanding Voting Stock of the Acquiring Entity immediately after the sale or transfer is held in the aggregate (directly or through ownership of Voting Stock of the Company or a Subsidiary) by the holders of Voting Stock of the Company immediately prior to the sale or transfer. However, a sale or transfer described in this Section 20(g) will not constitute a Change in Control if the sale or transfer is pursuant to a spin-off type of transaction (directly or indirectly) of the Company’s assets to the Company's shareholders; or

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(3)The approval by the shareholders of the Company of a complete liquidation or dissolution of the Company; or

(4)Any "person" (as such term is used in Sections 13(d) and 14(d) of the Exchange Act, other than (A) a trustee or other fiduciary holding securities under an employee benefit plan of the Company or any Affiliate, or (B) any corporation owned, directly or indirectly, by the shareholders of the Company in substantially the same proportions as their ownership of the Common Stock) becomes the "beneficial owner" (as defined in Rule 13d-3 of the Exchange Act), directly or indirectly, of securities of the Company representing thirty percent (30%) or more of the total voting power represented by the Company's then outstanding Voting Stock; or

(5)A change in the composition of the Board occurring within any consecutive twelve-month period, as a result of which fewer than a majority of the directors are Incumbent Directors. “Incumbent Directors” means directors who either (i) are Directors or Directors-Elect as of the first date the Common Stock is listed on any established stock exchange, or (ii) are elected, or nominated for election, to the Board with the affirmative votes of at least a majority of the Incumbent Directors at the time of the election or nomination (but will not include an individual whose election or nomination is in connection with an actual or threatened proxy contest relating to the election of directors to the Company). However, a change in the composition of the Board described in this Section 20(g) will not constitute a Change in Control if the change in the composition of the Board is pursuant to a spin-off type of transaction (directly or indirectly) of the Company’s Voting Stock or assets to the Company's shareholders.

For purposes of this Section 20(g):

(6)“Affiliate” “Affiliate” means, with respect to any specified person, any other person that directly or indirectly, through one or more intermediaries, controls, is controlled by, or is under common control with, the specified person (“control,” “controlled by” and “under common control with” will mean the possession, directly or indirectly, of the power to direct or cause the direction of the management and policies of a person, whether through ownership of voting securities, by contact or credit arrangement, as trustee or executor, or otherwise); and

(7)“Voting Stock.” Means securities entitled to vote generally in the election of directors.

(h)Code is the Internal Revenue Code of 1986, as amended.

(i)Common Stock means the common stock of the Company.

(j)Company means DT Midstream, Inc., a Delaware corporation, or any successor corporation.

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(k)Competitive Activity is the Executive’s direct employment, without the written consent of the Board (or any Committee of the Board to which the Board delegates its authority under this Section 20(k) in writing), in any business or enterprise (including the Executive’s own business or enterprise) if:

(1)the business or enterprise engages in substantial and direct competition with the Company or any of its Subsidiaries in any state in which the Company or Subsidiary was engaged in business or actively negotiating to enter business on the Termination Date; and

(2)the business’s or enterprise’s sales of any product or service competitive with any product or service of the Company or any of its Subsidiaries amounted to 10% of the business’s or enterprise’s net sales for its most recently completed fiscal year; and

(3)the Company’s or Subsidiary’s net sales of the competitive product or service amounted to 10% of the Company’s or Subsidiary’s net sales for its most recently completed fiscal year; and

(4)the Board determines the Executive’s employment in the business or enterprise is detrimental to the Company or any of its Subsidiaries.

“Competitive Activity” does not include the mere ownership of not more than 10% of the total combined voting power or aggregate value of all classes of stock or other securities in the enterprise and the Executive’s exercise of rights resulting from ownership of the stock.

The Board (or its delegate) has sole discretion and authority to determine if the Executive is engaging in Competitive Activity for purposes of this Agreement. It is the Executive’s responsibility to provide information sufficient for the Board (or its delegate) to make these determinations.

(l)Exchange Act is the Securities Exchange Act of 1934, as amended.

(m)Good Reason. An Executive terminates employment for Good Reason if the Executive terminates his or her employment during the Severance Period following the occurrence of any of the following events during the Severance Period, provided that, before terminating employment, the Executive gives the Company written notice of the occurrence of the event within 90 days of the occurrence and the Company fails to cure the event within 30 days of receiving the Executive’s written notice:

(1)Failure to maintain the Executive in a position within the same or higher employee subgroup (as in existence prior to the Change in Control) with the Company and/or a Subsidiary, as applicable, which the Executive held immediately prior to the Change in Control, or the removal of the Executive as Chairman of the Company (or any successor to the Company) if the Executive was Chairman of the Company immediately prior to the Change in Control;

(2)A significant adverse change in the nature or scope of the authorities, powers, functions, responsibilities or duties attached to the position with the Company and its Subsidiaries as compared to other employees in the same employee subgroup within the Company or the Subsidiary which the Executive held immediately prior to the Change in Control;

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For {EXECUTIVE}

(3)A reduction in the Executive’s Base Pay or the opportunity to earn Incentive Pay from the Company, its Subsidiaries or the failure to pay the Executive Base Pay or Incentive Pay earned when due;

(4)The termination or denial of the Executive’s rights to employee benefits or a material reduction in the aggregate scope or value of employee benefits (unless, in the case of Welfare Benefits or pension benefits, the termination, denial or reduction applies to all similarly situated employees of the Company and its Subsidiaries), any of which is not remedied by the Company within 10 calendar days after the Company receives written notice from the Executive of the change, reduction or termination;

(5)Without the Executive’s prior written consent, the Company:

(A)Requires the Executive to change the Executive’s principal location of work to any location that is in excess of 60 miles from the location immediately prior to the Change in Control; or

(B)Requires the Executive to travel away from the Executive’s office in the course of discharging the Executive’s responsibilities or duties at least 40% more (in terms of aggregate days in any calendar year or in any calendar quarter when annualized for purposes of comparison to any prior year) than the average number of travel days per calendar year that was required of the Executive in the three full calendar years immediately prior to the Change in Control.

(6)Any material breach of this Agreement by the Company or its successor.

(n)LTIP means the DT Midstream, Inc. Long-Term Incentive Plan, as may be amended from time to time or such successor plan.

(o)Qualifying Termination means:

(1)Termination of the Executive’s employment by the Company or a Subsidiary during the Severance Period other than a termination:

(A)because of the Executive’s death;

(B)because the Executive became permanently disabled within the meaning of, and began receiving disability benefits under, the Company or Subsidiary sponsored long-term disability plan in effect for, or applicable to, the Executive immediately prior to the Change-in-Control; or

(C)for Cause;

or

(2)Termination of the Executive’s employment by the Executive during the Severance Period for Good Reason, regardless of whether any other reason, other than Cause, for the Executive’s termination exists or has occurred, including other employment.

(p)Severance Pay is the collective benefits provided under any agreement, policy, plan, program, or arrangement of the Company or a Subsidiary or any provision of any

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individual severance, employment, or other agreement between the Executive and the Company or a Subsidiary that are paid to the Executive solely because of the termination of the Executive’s employment.

(q)Severance Period resulting from a Change-in-Control described in Section 20(g) is the period beginning on the date a Change-in-Control occurs and ending on the earliest of:

(1)    the second anniversary of the Change-in-Control;

(2)    the Executive’s death.

(r)Subsidiary means a "subsidiary corporation" with respect to the Company, whether now or hereafter existing, as defined in Section 424(f) of the Code.

(s)Termination Date is the date on which the Executive’s employment is terminated by a Qualifying Termination.

(t)Welfare Benefits are benefits provided under employee welfare benefit plans, as defined in Section 3(1) of the Employee Retirement Income Security Act of 1974, as amended.

In witness whereof, this Agreement has been entered into by the Company and the Executive as of the Effective Date.

____________________________________            

{EXECUTIVE}                                Date

DT MIDSTREAM, INC.

_____________________________________            

David Slater                                Date

President & CEO

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Compensation Committee

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EX-19.1

Exhibit 19.1

Insider Trading Policy

Company Policy

Insider Trading

Revision 1

June 1, 2023

1.Applicability

This Policy applies to all employees of DT Midstream and their respective family members. This Policy also applies to contract personnel (defined as contractors, vendors, consultants or any others performing work on behalf of DT Midstream) and any other external party that may be considered an “Insider” because they have access to material nonpublic information concerning DT Midstream.1

2.Policy

A.General

1.The purpose of this policy is to inform DT Midstream and its subsidiary employees that anyone who has knowledge of material nonpublic information may be considered an “Insider” for purposes of the federal securities laws prohibiting insider trading.

2.To prevent even the appearance of improper insider trading or tipping, DT Midstream has adopted this Insider Trading Policy for all of its directors, officers and employees and their family members, as well as for others who have access to information through business relationships with the Company.

B.Definitions

1.Insider

An “Insider” is a person who has access to confidential or nonpublic information about a publicly traded company.

2.Material Information

“Material” information is any information pertaining to DT Midstream that a reasonable investor would consider important in making an investment decision to buy or sell the Company’s securities. Some examples of material information, but not limited to, include the following:

-----------------------------------------------------------------------

1The applicability of these policy requirements to contractors, vendors, consultants, service providers, or any others performing work on behalf of DT Midstream should not be interpreted or construed to create or establish an employment relationship between DT Midstream or any DT Midstream subsidiary and its contractors, vendors, consultants, service providers, or their employees or agents.

1

Insider Trading Policy

Company Policy

a.Financial statements and forecasts

b.Potential mergers and acquisitions

c.New, or the loss of, major contracts, orders, suppliers or customers

d.Legal or regulatory matters

e.Changes to the Company’s credit rating

f.Impending bankruptcy or financial liquidity challenges

g.Significant cybersecurity incident

3.Nonpublic Information

“Nonpublic” information is information that has not yet been disseminated to the public through various sources including SEC filings, press releases, earnings calls, news publications, social media and other media outlets.

3. Content

A.Law

Federal securities laws prohibit insider trading. As a result, it is a violation of DT Midstream’s Insider Trading Policy and the federal securities laws for any employee or external party as referenced in Section 1 above to:

1.trade in securities of DT Midstream while aware of “material nonpublic information” concerning the Company, or

2.communicate, “tip” or disclose material nonpublic information to outsiders so that they may trade in securities of the Company based on that information.

B.Covered Transactions

1.This Policy applies to any and all transactions in DT Midstream’s securities, which include but are not limited to the following:

a.Common stock

b.Preferred stock

c.Convertible debentures

d.Warrants

e.Exchange-traded options

f.Derivatives

g.Short sales

2.Transactions in DT Midstream securities include not only market transactions but also private sales of Company securities, including but not limited to the following:

2

Insider Trading Policy

Company Policy

a.Pledges

b.Charitable donations

C.Section 16 Officers and Designated Employees

1.Section 16 Officers

Each member of the DT Midstream’s Board of Directors (Board) and those Officers designated by the Board as Section 16 Officers are subject to the reporting provisions and trading restrictions of Section 16 of the Securities Exchange Act of 1934 and the underlying rules and regulations promulgated by the U.S. Securities and Exchange Commission (SEC). Section 16 individuals must obtain prior approval of all trades in DT Midstream securities from the Corporate Secretary’s Office.

2.Designated Employees

The Company may choose to identify additional Officers and employees that because of their duties, may have regular access to material nonpublic information. These “designated employees” may be required to comply with additional Company trading restrictions.

D.Open Trading Window

Provided that no other restrictions on trading in DT Midstream securities apply, Board members, Section 16 Officers and any other “designated employee” may trade in Company securities only during the trading Open Window Period as published by the Corporate Secretary’s Office and with prior approval.

E.Reporting and Inquiries

Anyone having information relative to violations of this policy or inadvertent disclosures of material nonpublic information must immediately report it to DT Midstream’s Corporate Secretary for further evaluation. Questions regarding this policy or inquiries pertaining to potential transactions can also be directed to the Corporate Secretary. Alternatively, reports or inquiries can be made confidentially and anonymously, if preferred, to DT Midstream’s Ethics Helpline by phone at 855.222.0671 or by internet at www.lighthouse-services.com.

3

Insider Trading Policy

Company Policy

4. Sources

A.DT Midstream’s Employee Code of Conduct

B.Director Code of Ethics

C.Open Window Schedule

Accountable Officer: General Counsel and Corporate Secretary

Last Reviewed: May 15, 2023

4

EX-21.1

Exhibit 21.1

SUBSIDIARIES OF DT MIDSTREAM, INC.

DT Midstream’s principal subsidiaries as of December 31, 2023 are listed below. All other subsidiaries, if considered in the aggregate as a single subsidiary, would not constitute a significant subsidiary.

Subsidiary		State of Incorporation
1	Bluestone Gas Corporation of New York, Inc.	New York
2	Bluestone Pipeline Company of Pennsylvania, LLC	Pennsylvania
3	DTM Appalachia Gathering, LLC	Delaware
4	DTM LEAP Gas Gathering, LLC	Delaware
5	DTM Louisiana Gathering, LLC	Delaware
6	DTM Millennium Company	Michigan
7	DTM Nexus, LLC	Delaware
8	DTM Vector Company	Michigan
9	Stonewall Gas Gathering LLC	Delaware
10	Stonewall Gas Holdings, LLC	Delaware
11	Susquehanna Gathering Company I, LLC	Pennsylvania

EX-23.1

Exhibit 23.1

CONSENT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM

We hereby consent to the incorporation by reference in the Registration Statement on Form S-8 (No. 333-257607) of DT Midstream, Inc. of our report dated February 16, 2024 relating to the financial statements and the effectiveness of internal control over financial reporting, which appears in this Form 10-K.

/s/ PricewaterhouseCoopers LLP

Detroit, Michigan

February 16, 2024

EX-31.1

Exhibit 31.1

FORM 10-K CERTIFICATION

I, David Slater, certify that:

1.I have reviewed this Annual Report on Form 10-K of DT Midstream, Inc.;

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(s) 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(s) 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.

/S/ DAVID J. SLATER	Date:	February 16, 2024
David J. Slater President and Chief Executive Officer of DT Midstream, Inc.

EX-31.2

Exhibit 31.2

FORM 10-K CERTIFICATION

I, Jeffrey Jewell, certify that:

1.I have reviewed this Annual Report on Form 10-K of DT Midstream, Inc.;

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(s) 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(s) 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.

/S/ JEFFREY A. JEWELL	Date:	February 16, 2024
Jeffrey A. Jewell Executive Vice President Chief Financial and Accounting Officer of DT Midstream, Inc.

EX-32.1

Exhibit 32.1

CERTIFICATION PURSUANT TO

18 U.S.C. SECTION 1350,

AS ADOPTED PURSUANT TO

SECTION 906 OF THE SARBANES-OXLEY ACT OF 2002

In connection with the Annual Report on Form 10-K of DT Midstream, Inc. (the “Company”) for the year ended December 31, 2023, as filed with the Securities and Exchange Commission on the date hereof (the “Report”), I, David J. Slater, certify, pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, that to the best of my knowledge and belief:

(1)the Report fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934; and

(2)the information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of the Company.

Date:	February 16, 2024	/S/ DAVID J. SLATER
		David J. Slater President and Chief Executive Officer of DT Midstream, Inc.

A signed original of this written statement required by Section 906 has been provided to the Company and will be retained by the Company and furnished to the Securities and Exchange Commission or its staff upon request.

EX-32.2

Exhibit 32.2

CERTIFICATION PURSUANT TO

18 U.S.C. SECTION 1350,

AS ADOPTED PURSUANT TO

SECTION 906 OF THE SARBANES-OXLEY ACT OF 2002

In connection with the Annual Report on Form 10-K of DT Midstream, Inc. (the “Company”) for the year ended December 31, 2023, as filed with the Securities and Exchange Commission on the date hereof (the “Report”), I, Jeffrey A. Jewell, certify, pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, that to the best of my knowledge and belief:

(1)the Report fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934; and

(2)the information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of the Company.

Date:	February 16, 2024	/S/ JEFFREY A. JEWELL
		Jeffrey A. Jewell Executive Vice President, Chief Financial and Accounting Officer of DT Midstream, Inc.

A signed original of this written statement required by Section 906 has been provided to the Company and will be retained by the Company and furnished to the Securities and Exchange Commission or its staff upon request.

EX-95.1

EXHIBIT 95.1

Mine Safety Disclosure

The following disclosure is provided pursuant to Section 1503(a) of the Dodd-Frank Wall Street Reform and Consumer Protection Act, which requires certain disclosures by companies required to file periodic reports under the Securities Exchange Act of 1934, as amended, that operate mines regulated under the Federal Mine Safety and Health Act of 1977.

The table that follows reflects citations, orders, violations and proposed assessments issued by the Mine Safety and Health Administration (the “MSHA”) to DTM Louisiana Gathering, LLC, an indirect wholly owned subsidiary of DT Midstream, Inc. The disclosure is with respect to the year ended December 31, 2023. Due to timing and other factors, the data may not agree with the mine data retrieval system maintained by the MSHA at www.MSHA.gov.

DT Midstream, Inc.

Mine Safety Disclosure

For the Year Ended December 31, 2023

Operation (1)	Section 104 S&S Citations	Section 104(b) Orders	Section 104(d) Citations and Orders	Section 110(b)(2) Violations	Section 107(a) Orders	Total Dollar Value of Proposed MSHA Assessments (2)		Total Number of Mining Related Fatalities	Received Notice of Pattern of Violations Under Section 104(e)	Received Notice of Potential to Have Pattern Under Section 104(e)	Legal Actions Pending as of the Last Day of Period	Legal Actions Initiated During Period	Legal Actions Resolved During Period
DTM GEN6 Proppants, LLC ID: 1601585	—	—	—	—	—	$	2,161	—	No	No	—	—	—
Total	—	—	—	—	—	$	2,161	—	No	No	—	—	—

(1) The definition of mine under section 3 of the Mine Act includes the mine, as well as other items used in, or to be used in, or resulting from, the work of extracting minerals, such as land, structures, facilities, equipment, machines, tools, and preparation facilities. Unless otherwise indicated, any of these other items associated with a single mine have been aggregated in the totals for that mine.

(2) The whole-dollar amounts included are the total dollar value of all proposed or outstanding assessments, regardless of classification, received from MSHA on or before December 31, 2023 regardless of whether the assessment has been challenged or appealed, for alleged violations occurring during the year ended December 31, 2023. Citations and orders can be contested and appealed, and as part of that process, are sometimes reduced in severity and amount, and are sometimes dismissed. The number of citations, orders, and proposed assessments vary by inspector and also vary depending on the size and type of the operation.

EX-97.1

Exhibit 97.1

Clawback Policy

 Company Policy

Clawback Policy

Version 1

September 19, 2023

1.Applicability

This Policy applies to all current and former Executive Officers of DT Midstream, Inc. (Company). Incentive-Based Compensation Received by a newly appointed Executive Officers prior to the Executive Officer’s appointment is not subject to this Policy.

2.Policy

A.General

1.The purpose of this Policy is to establish a policy for the recovery of Erroneously Awarded Compensation Received by Covered Individuals during the Lookback Period.

2.This Policy is established to comply with Section 303A.14 of the New York Stock Exchange Listed Company Manual (Clawback Rules), promulgated pursuant to the final rules adopted by the Securities and Exchange Commission enacting the clawback standards under Section 954 of the Dodd-Frank Wall Street Reform and Consumer Protection Act.

B.Definitions

1.Covered Individual – a current or former Executive Officer.

2.Executive Officer – an “officer” as defined in Rule 16a-1(f) of the Securities Exchange Act of 1934, as amended.

3.Erroneously Awarded Compensation – the amount of Incentive-Based Compensation Received that exceeds the amount of Incentive-Based Compensation that otherwise would have been Received had it been determined based on the restated amounts, computed without regard to any taxes paid by the Covered Individual or withheld from the Incentive-Based Compensation.

4.Incentive-Based Compensation – any compensation that is granted, earned or vested based upon the attainment of a Financial Reporting Measure.

1

Clawback Policy

 Company Policy

5.Financial Reporting Measure – a measure that is determined and presented in accordance with the accounting principles used in preparing the Company’s financial statements and any measure that is derived wholly or in part from such measures, including stock price and total shareholder return (TSR), whether or not included in a filing with the Securities and Exchange Commission.

6.Lookback Period – the three-year period immediately preceding the date the Company (board, committee, or management) concludes that a restatement is required (or reasonably should have concluded a restatement was required) or a regulator, court or other legally authorized entity directs the Company to prepare a restatement.

7.Received – Incentive-Based Compensation is deemed received in the Company’s fiscal period during which the financial reporting measure specified in the Incentive-Based Compensation award is attained, even if the payment or grant of the Incentive-Based Compensation occurs after the end of that period.

8.Content

A.Triggering Events

The Company must seek recoupment of Erroneously Awarded Compensation in the event of an accounting restatement due to the Company’s material noncompliance with any financial reporting requirement under the securities laws, including:

1.Any required accounting restatement to correct an error in previously issued financial statements that is material to the previously issued financial statements, or

2.To correct an error in previously issued financial statements that would result in a material misstatement if:

a.The error was corrected in the current period, or

b.The error was left uncorrected in the current period.

B.Recovery of Erroneously Awarded Compensation

The Company shall reasonably promptly recover Erroneously Awarded Compensation Received by a Covered Individual as required by the Clawback Rules during the Lookback Period.

2

Clawback Policy

 Company Policy

C.Covered Compensation

1.This Policy applies to the Incentive-Based Compensation Received:

a.after such Covered Individual began service as an Executive Officer;

b.who served as an Executive Officer at any time during the performance period for that Incentive-Based Compensation;

c.while the Company has a class of securities listed on a national securities exchange or a national securities association; and

d.during the Lookback Period (or during any transition period, that results from a change in the Company’s fiscal year, within or immediately following those three completed fiscal years, as determined in accordance with the Clawback Rules).

2.The amount of Incentive-Based Compensation subject to this Policy is the amount of any Erroneously Awarded Compensation, as determined in accordance with this Policy and the Clawback Rules.

3.The Company’s Organization and Compensation Committee (O&C Committee) shall make all determinations regarding the amount of Erroneously Awarded Compensation.

D.Method of Recovery

1.The O&C Committee shall determine, in its sole discretion, the manner in which any Erroneously Awarded Compensation shall be recovered. Methods of recovery may include, but are not limited to:

a.seeking direct repayment from the Covered Individual;

b.reducing (subject to applicable law and the terms and conditions of the applicable plan, program or arrangement pursuant to which the Incentive-Based Compensation was paid) the amount that would otherwise be payable to the Covered Individual under any compensation, bonus, incentive, equity and other benefit plan, agreement, policy or arrangement maintained by the Company or any of its affiliates;

c.cancelling any award (whether cash- or equity-based) or portion thereof previously granted to the Covered Individual; or

d. any combination of the foregoing.

E.Disclosures

3

Clawback Policy

 Company Policy

1.The Company will file this Policy, including revised versions, as an Exhibit to its Annual Report on Form 10-K.

2.The Company will make certain disclosures in its Annual Report on Form 10-K or proxy statement should a triggering event occur, which shall include, but not be limited to:

a.date required to prepare the accounting statement;

b.aggregate dollar amount of clawback and analysis of how the amount was calculated;

c.aggregate amount that remains unrecovered at the end of the current fiscal year;

d.amounts owed by each Executive Officer that is outstanding by more than 180 days; and

e.estimates used to calculate the clawback amount and methodology used if the clawback is attributable to Incentive-Based Compensation based on stock price or TSR.

F.No-Fault Basis

This Policy applies on a no-fault basis, and Covered Individuals will be subject to recovery under this Policy without regard to their personal culpability.

G.Other Company Arrangements

This Policy shall be in addition to, and not in lieu of, any other clawback, recovery or recoupment policy maintained by the Company from time to time, as well as any clawback, recovery or recoupment provision in any of the Company’s plans, awards or individual agreements (including the clawback, recovery and recoupment provisions in the Company’s equity award agreements) (collectively, Other Company Arrangement) and any other rights or remedies available to the Company, including termination of employment; provided, however, that there is no intention to, nor shall there be, any duplicative recoupment of the same compensation under more than one policy, plan, award or agreement. In addition, no Other Company Arrangement shall serve to restrict the scope or the recoverability of Erroneously Awarded Compensation under this Policy or in any way limit recovery in compliance with the Clawback Rules.

H.No Indemnification

Notwithstanding anything to the contrary set forth in any policy, arrangement, bylaws, charter, certificate of incorporation or plan of the Company or any

4

Clawback Policy

 Company Policy

individual agreement between a Covered Individual and the Company or any of its affiliates, no Covered Individual shall be entitled to indemnification from the Company or any of its affiliates for the amount that is or may be recovered by the Company pursuant to this Policy; provided, however, that to the extent expense advancement or reimbursement is available to a Covered Individual, this Policy shall not serve to prohibit such advancement or reimbursement.

I.Administration and Interpretation

1.The O&C Committee shall interpret and construe this Policy consistent with the Clawback Rules and applicable laws and regulation and shall make all determinations necessary, appropriate or advisable for the administration of this Policy.

2.Any determinations made by the O&C Committee shall be final, binding and conclusive on all affected individuals.

3.As required by the Clawback Rules, the Company shall provide public disclosures related to this Policy and any applicable recoveries of Erroneously Awarded Compensation.

4.To the extent this Policy conflicts or is inconsistent with the Clawback Rules, the Clawback Rules shall govern.

5.In no event is this Policy intended to be broader than, or require recoupment in addition to, that required pursuant to the Clawback Rules.

J. Amendment or Termination of this Policy

The Board reserves the right to amend this Policy at any time and for any reason, subject to applicable law and the Clawback Rules. To the extent that the Clawback Rules cease to be in force or cease to apply to the Company, this Policy shall also cease to be in force.

I.Covered Individual Acknowledgment

All Covered Individuals are required to sign a Covered Individual Acknowledgment Form confirming their understanding of this Policy and the Clawback Rules. The Covered Individual Acknowledgment Form will be administered and maintained by the Corporate Secretary’s Office.

4.Sources

A.Section 303A.14 of the New York Stock Exchange Listed Company Manual

B.Officer Code of Business Conduct and Ethics

5

Clawback Policy

 Company Policy

C.Internal Control over Financial Reporting Policy

D.Covered Individual Acknowledgment Form

Accountable Officer: O&C Committee

Last Reviewed: September 19, 2023

6

XML

Cover - USD ($) $ in Billions	12 Months Ended
	Dec. 31, 2023	Feb. 08, 2024	Jun. 30, 2023
Cover [Abstract]
Document Type	10-K
Document Annual Report	true
Document Period End Date	Dec. 31, 2023
Current Fiscal Year End Date	--12-31
Document Transition Report	false
Entity File Number	001-40392
Entity Registrant Name	DT Midstream, Inc.
Entity Incorporation, State or Country Code	DE
Entity Tax Identification Number	38-2663964
Entity Address, Address Line One	500 Woodward Ave., Suite 2900
Entity Address, City or Town	Detroit
Entity Address, State or Province	MI
Entity Address, Postal Zip Code	48226-1279
City Area Code	313
Local Phone Number	402-8532
Title of 12(b) Security	Common stock, par value $0.01
Trading Symbol	DTM
Security Exchange Name	NYSE
Entity Well-known Seasoned Issuer	Yes
Entity Voluntary Filers	No
Entity Current Reporting Status	Yes
Entity Interactive Data Current	Yes
Entity Filer Category	Large Accelerated Filer
Entity Small Business	false
Entity Emerging Growth Company	false
ICFR Auditor Attestation Flag	true
Document Financial Statement Error Correction [Flag]	false
Entity Shell Company	false
Entity Public Float			$ 4.8
Entity Common Stock, Shares Outstanding		96,979,556
Documents Incorporated by Reference	Certain information in DT Midstream's definitive Proxy Statement for our 2024 Annual Meeting of Common Shareholders to be held May 10, 2024, which will be filed with the Securities and Exchange Commission pursuant to Regulation 14A, not later than 120 days after the end of the registrant’s fiscal year covered by this report on Form 10-K, is incorporated herein by reference to Part III (Items 10, 11, 12, 13, and 14) of this Form 10-K.
Entity Central Index Key	0001842022
Document Fiscal Year Focus	2023
Document Fiscal Period Focus	FY
Amendment Flag	false

XML

Audit Information	12 Months Ended
	Dec. 31, 2023
Audit Information [Abstract]
Auditor Firm ID	238
Auditor Name	PricewaterhouseCoopers LLP
Auditor Location	Detroit, Michigan

XML

Consolidated Statements of Operations - USD ($) shares in Millions, $ in Millions	12 Months Ended
	Dec. 31, 2023	Dec. 31, 2022	Dec. 31, 2021
Revenues
Operating revenues	$ 922	$ 920	$ 840
Operating Expenses
Operation and maintenance	245	267	231
Depreciation and amortization	182	170	166
Taxes other than income	28	28	24
Asset (gains) losses and impairments, net	(4)	(23)	17
Operating Income	471	478	402
Other (Income) and Deductions
Interest expense	150	137	112
Interest income	(1)	(3)	(4)
Earnings from equity method investees	(177)	(150)	(126)
Loss from financing activities	0	13	0
Other (income) and expense	(1)	(1)	(2)
Income Before Income Taxes	500	482	422
Income Tax Expense	104	100	104
Net Income	396	382	318
Less: Net Income Attributable to Noncontrolling Interests	12	12	11
Net Income Attributable to DT Midstream	$ 384	$ 370	$ 307
Basic Earnings per Common Share
Net Income Attributable to DT Midstream (in dollars per share)	$ 3.97	$ 3.83	$ 3.17
Diluted Earnings per Common Share
Net Income Attributable to DT Midstream (in dollars per share)	$ 3.94	$ 3.81	$ 3.16
Weighted Average Common Shares Outstanding
Basic (in shares)	96.9	96.7	96.7
Diluted (in shares)	97.5	97.2	96.9

XML

Consolidated Statements of Comprehensive Income - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2023	Dec. 31, 2022	Dec. 31, 2021
Statement of Comprehensive Income [Abstract]
Net Income	$ 396	$ 382	$ 318
Foreign currency translation and unrealized gain on derivatives, net of tax	2	0	1
Other comprehensive income	2	0	1
Comprehensive income	398	382	319
Less: Comprehensive income attributable to noncontrolling interests	12	12	11
Comprehensive Income Attributable to DT Midstream	$ 386	$ 370	$ 308

XML

Consolidated Statements of Financial Position - USD ($) $ in Millions	Dec. 31, 2023	Dec. 31, 2022
Current Assets
Cash and cash equivalents	$ 56	$ 61
Accounts receivable (net of $— allowance for expected credit loss for each period end)	154	161
Deferred property taxes	31	22
Taxes receivable	15	0
Prepaid expenses and other	16	18
Total Current Assets	272	262
Investments
Investments in equity method investees	1,762	2,200
Property
Property, plant, and equipment	5,282	4,534
Accumulated depreciation	(848)	(728)
Net Property, plant, and equipment	4,434	3,806
Other Assets
Goodwill	473	473
Long-term notes receivable — related party	4	4
Operating lease right-of-use assets	38	31
Intangible assets, net	1,968	2,025
Other	31	32
Total Other Assets	2,514	2,565
Total Assets	8,982	8,833
Current Liabilities
Accounts payable	94	119
Short-term borrowings	165	330
Operating lease liabilities	13	16
Dividends payable	67	62
Interest payable	10	10
Property taxes payable	34	29
Accrued compensation	18	20
Contract liabilities	18	4
Other	15	24
Total Current Liabilities	434	614
Long-Term Debt, net	3,065	3,059
Other Liabilities
Deferred income taxes	1,031	923
Operating lease liabilities	27	19
Contract liabilities	111	28
Other	34	36
Total Other Liabilities	1,203	1,006
Total Liabilities	4,702	4,679
Commitments and Contingencies (Note 12)
Stockholders' Equity
Preferred stock ($0.01 par value, 50,000,000 shares authorized, and no shares issued or outstanding as of December 31, 2023 and 2022)	0	0
Common stock ($0.01 par value, 550,000,000 shares authorized, and 96,971,021 and 96,754,549 shares issued and outstanding as of December 31, 2023 and 2022, respectively)	1	1
Additional paid-in capital	3,485	3,469
Retained earnings	661	547
Accumulated other comprehensive income (loss)	(8)	(10)
Total DT Midstream Equity	4,139	4,007
Noncontrolling interests	141	147
Total Equity	4,280	4,154
Total Liabilities and Equity	$ 8,982	$ 8,833

XML

Consolidated Statements of Financial Position (Parenthetical) - USD ($) $ in Millions	Dec. 31, 2023	Dec. 31, 2022
Current Assets
Allowance for expected credit loss	$ 0	$ 0
Stockholders' Equity
Preferred stock, par value (in dollars per share)	$ 0.01	$ 0.01
Preferred stock, shares authorized (in shares)	50,000,000	50,000,000
Preferred stock, shares issued (in shares)	0	0
Preferred stock, shares outstanding (in shares)	0	0
Common stock, par value (in dollars per share)	$ 0.01	$ 0.01
Common stock, shares authorized (in shares)	550,000,000	550,000,000
Common stock, shares issued (in shares)	96,971,021	96,754,549
Common stock, shares outstanding (in shares)	96,971,021	96,754,549

XML

Consolidated Statements of Cash Flows - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2023	Dec. 31, 2022	Dec. 31, 2021
Operating Activities
Net Income	$ 396	$ 382	$ 318
Adjustments to reconcile Net Income to Net cash and cash equivalents from operating activities:
Depreciation and amortization	182	170	166
Stock-based compensation	20	17	12
Amortization of operating lease right-of-use assets	18	19	18
Deferred income taxes	110	70	104
Earnings from equity method investees	(177)	(150)	(126)
Dividends from equity method investees	196	181	129
Asset (gains) losses and impairments, net	0	(17)	17
Loss from financing activities	0	13	0
Changes in assets and liabilities:
Accounts receivable, net	7	8	(43)
Accounts payable — third party	(5)	7	4
Accounts payable — related party	0	0	(10)
Contract liabilities	97	3	6
Other current and noncurrent assets and liabilities	(46)	22	(23)
Other investing activities	1	2	2
Net cash and cash equivalents from operating activities	798	725	572
Investing Activities
Plant and equipment expenditures	(772)	(338)	(140)
Proceeds from sale of notes receivable	0	22	0
Distributions from equity method investees	427	17	9
Contributions to equity method investees	(7)	(5)	(11)
Acquisition of additional interest in equity method investee	0	(552)	0
Notes receivable repaid by DTE Energy	0	0	263
Net cash and cash equivalents from (used for) investing activities	(351)	(854)	123
Financing Activities
Issuance of long-term debt, net of discount and issuance costs	0	591	3,047
Repayment of long-term debt	0	(596)	(5)
Repayment of borrowings from DTE Energy	0	0	(3,175)
Borrowings under the Revolving Credit Facility	540	370	25
Repayment of borrowings under the Revolving Credit Facility	(705)	(40)	(25)
Payment of Revolving Credit Facility issuance costs	0	(3)	(7)
Repurchase of common stock	0	(3)	0
Distributions to noncontrolling interests	(18)	(14)	(16)
Dividends paid on common stock	(263)	(244)	(58)
Dividend to DTE Energy	0	0	(501)
Contributions from DTE Energy	0	0	110
Other financing activities	(6)	(3)	0
Net cash and cash equivalents from (used for) financing activities	(452)	58	(605)
Net Increase (Decrease) in Cash and Cash Equivalents	(5)	(71)	90
Cash and Cash Equivalents at Beginning of Period	61	132	42
Cash and Cash Equivalents at End of Period	56	61	132
Supplemental disclosure of cash information
Interest, net of interest capitalized	140	125	103
Income taxes	22	24	3
Supplemental disclosure of non-cash investing and financing activities
Plant and equipment expenditures in accounts payable and other accruals	$ 80	$ 99	$ 10

XML

Consolidated Statements of Changes in Stockholders' Equity/Member's Equity - USD ($) $ in Millions	Total		Related Party		Common Stock		Common Stock Related Party	[2]	Additional Paid-In Capital	Retained Earnings	Retained Earnings Related Party	Accumulated Other Comprehensive Income (Loss)	Noncontrolling Interests
Beginning balance (in shares) at Dec. 31, 2020					0
Beginning balance at Dec. 31, 2020	$ 4,228				$ 0				$ 3,333	$ 751		$ (11)	$ 155
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net Income	318									307			11
Issuance of common shares (in shares)					1,000	[1]	96,731,000
Issuance of common shares	0	[1]	$ 1	[2]			$ 1
Dividends	(116)		$ (501)							(116)	$ (501)
Distributions to noncontrolling interests	(16)												(16)
Stock-based compensation (in shares)					2,000
Stock-based compensation	8								8
Taxes and other adjustments	98								109	(10)			(1)
Other comprehensive income, net of tax	1											1
Ending balance (in shares) at Dec. 31, 2021					96,734,000
Ending balance at Dec. 31, 2021	$ 4,021				$ 1				3,450	431		(10)	149
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Common stock, par value (in dollars per share)	$ 0.01
Net Income	$ 382									370			12
Dividends	(248)									(248)
Distributions to noncontrolling interests	(14)												(14)
Stock-based compensation (in shares)					78,000
Stock-based compensation	15								17	(2)
Taxes and other adjustments	1								2	(1)
Repurchase of common stock (in shares)					(57,000)
Repurchase of common stock	(3)									(3)
Other comprehensive income, net of tax	$ 0
Ending balance (in shares) at Dec. 31, 2022	96,754,549				96,755,000
Ending balance at Dec. 31, 2022	$ 4,154				$ 1				3,469	547		(10)	147
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Common stock, par value (in dollars per share)	$ 0.01
Net Income	$ 396									384			12
Dividends	(268)									(268)
Distributions to noncontrolling interests	(18)												(18)
Stock-based compensation (in shares)					216,000
Stock-based compensation	14								16	(2)
Other comprehensive income, net of tax	$ 2											2
Ending balance (in shares) at Dec. 31, 2023	96,971,021				96,971,000
Ending balance at Dec. 31, 2023	$ 4,280				$ 1				$ 3,485	$ 661		$ (8)	$ 141
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Common stock, par value (in dollars per share)	$ 0.01

[1] Issuance of common shares at $0.01 par value upon conversion to C Corporation from a single member LLC.

[2] Issuance of common shares to DTE Energy in anticipation of the Separation.

XML

Consolidated Statements of Changes in Stockholders' Equity/Member's Equity (Parenthetical) - $ / shares	3 Months Ended										12 Months Ended
	Dec. 31, 2023	Sep. 30, 2023	Jun. 30, 2023	Mar. 31, 2023	Dec. 31, 2022	Sep. 30, 2022	Jun. 30, 2022	Mar. 31, 2022	Dec. 31, 2021	Sep. 30, 2021	Dec. 31, 2021
Statement of Stockholders' Equity [Abstract]
Dividends declared on common stock (in dollars per share)	$ 0.69	$ 0.69	$ 0.69	$ 0.69	$ 0.64	$ 0.64	$ 0.64	$ 0.64	$ 0.60	$ 0.60	$ 1.20

XML

Description of the Business and Basis of Presentation

12 Months Ended

Dec. 31, 2023

Organization, Consolidation and Presentation of Financial Statements [Abstract]

Description of the Business and Basis of Presentation

DESCRIPTION OF THE BUSINESS AND BASIS OF PRESENTATION

Description of the Business

DT Midstream is an owner, operator, and developer of an integrated portfolio of natural gas midstream assets. We provide multiple, integrated natural gas services to customers through two segments: (i) Pipeline, which includes interstate pipelines, intrastate pipelines, storage systems, lateral pipelines including related treatment plants and compression and surface facilities, and (ii) Gathering, which includes gathering systems, related treatment plants, and compression and surface facilities. Our Pipeline segment also includes joint venture interests in equity method investees which own and operate interstate pipelines that connect to our wholly owned assets.

Our core assets strategically connect key demand centers in the Midwestern U.S., Eastern Canada and Northeastern U.S. regions to the premium production areas of the Marcellus/Utica natural gas formation in the Appalachian Basin, and connect key demand centers and LNG export terminals in the Gulf Coast region to premium production areas of the Haynesville natural gas formation.

In connection with the Separation from DTE Energy, on January 13, 2021, DTE Gas Enterprises, LLC, and its consolidated subsidiaries converted into a Delaware corporation pursuant to a statutory conversion and changed its name to DT Midstream, Inc. ("DT Midstream"). At the conversion, DT Midstream issued 1,000 shares of common stock at $0.01 par value to its parent, a subsidiary of DTE Energy. As DT Midstream was a single member LLC as of December 31, 2020, and a corporation with stockholders' equity as of December 31, 2023, 2022 and 2021, Consolidated Statements of Changes in Stockholders' Equity/Member's Equity are presented as of December 31, 2023, 2022, and 2021. In June 2021, the DT Midstream Board of Directors authorized the issuance of an additional 96,731,466 common shares in anticipation of the Separation, for a total of 96,732,466 common shares issued and outstanding. DT Midstream is authorized to issue 50,000,000 shares of preferred stock at $0.01 par value. No preferred stock was issued or outstanding as of December 31, 2023 and 2022.

On July 1, 2021, DTE Energy completed the Separation through the distribution of 96,732,466 shares of DT Midstream common stock to DTE Energy shareholders. Following the Separation on July 1, 2021, DT Midstream became an independent public company listed under the symbol "DTM" on the NYSE. DTE Energy did not retain ownership in DT Midstream.

Basis of Presentation

The Consolidated Financial Statements and Notes to Consolidated Financial Statements as of and for the periods presented subsequent to July 1, 2021, the date of the Separation, reflect the consolidated financial position, results of operations and cash flows for DT Midstream as an independent company. Prior to the Separation, we operated as a consolidated entity of DTE Energy and not as a standalone company. For the periods prior to the Separation, the Consolidated Financial Statements and Notes to Consolidated Financial Statements were prepared on a carve-out basis using the consolidated financial statements and accounting records of DTE Energy. The carve-out basis financial statements represent our historical financial position, results of operations, and cash flows as they were historically managed in accordance with GAAP and reflect significant assumptions and allocations. The carve-out financial statements may not include all expenses that would have been incurred had we existed as a standalone entity.

GAAP requires management to use estimates and assumptions that impact reported amounts of assets, liabilities, revenues and expenses, and the disclosure of contingent assets and liabilities. Actual results may differ from our estimates. We believe the assumptions underlying these financial statements are reasonable.

Cash Management

Our sources of liquidity include cash generated from operations and available borrowings under our Revolving Credit Facility.

Prior to the Separation, our sources of liquidity included cash generated from operations and loans obtained through DTE Energy’s corporate-wide cash management program, including a working capital loan agreement. Cash was managed centrally, with certain net earnings reinvested in, and working capital requirements met from, existing liquid funds. Effective July 1, 2021, we no longer participated in the cash management program and the working capital loan was terminated.

Principles of Consolidation

We consolidate all majority-owned subsidiaries and investments in entities in which we have a controlling influence. Non-controlled investments are accounted for using the equity method of accounting when we are able to significantly influence the operating policies of the investee. When we do not influence the operating policies of an investee, the equity investment is measured at fair value, if readily determinable, or if not readily determinable, at cost less impairment, if applicable. We eliminate all intercompany balances and transactions.

We evaluate whether an entity is a VIE whenever reconsideration events occur. We consolidate VIEs for which we are the primary beneficiary. If we are not the primary beneficiary and an ownership interest is held, the VIE is accounted for under the equity method of accounting. When assessing the determination of the primary beneficiary, we consider all relevant facts and circumstances, including: the power, through voting or similar rights, to direct the activities of the VIE that most significantly impact the VIE's economic performance and the obligation to absorb the expected losses and/or the right to receive the expected returns of the VIE. We perform ongoing reassessments of all VIEs to determine if the primary beneficiary status has changed.

We own an 85% interest in the Stonewall VIE and are the primary beneficiary, therefore Stonewall is consolidated. We own a 50% interest in the South Romeo VIE and are the primary beneficiary, therefore South Romeo is consolidated.

The following table summarizes the major line items in the Consolidated Statements of Financial Position for consolidated VIEs as of December 31, 2023 and 2022. All assets and liabilities of a consolidated VIE are included in the table when it has been determined that a consolidated VIE has either (1) assets that can be used only to settle obligations of the VIE or (2) liabilities for which creditors do not have recourse to the general credit of the primary beneficiary. The assets and liabilities of consolidated VIEs that meet the definition of a business and whose assets can be used for purposes other than the settlement of the VIEs' obligations have been excluded from the table below.

	December 31,
	2023		2022
	(millions)
ASSETS (a)
Cash	$	13	$	27
Accounts receivable	10		9
Other current assets	2		3
Intangible assets, net	483		498
Property, plant and equipment, net	391		403
Goodwill	25		25
	$	924	$	965
LIABILITIES (a)
Accounts payable and other current liabilities	$	4	$	4
Other noncurrent liabilities	3		4
	$	7	$	8

_____________________________________

(a)Amounts shown are 100% of the consolidated VIEs' assets and liabilities.

We had a variable interest in an investment in certain assets in the Utica Shale region that was accounted for as a Note receivable — third party. We did not have an ownership interest in the entity and were not the primary beneficiary. This investment was sold during the second quarter 2022. See Note 2, "Significant Accounting Policies – Financing Receivables" to the Consolidated Financial Statements for additional discussion.

Related Parties

Transactions between DT Midstream and DTE Energy prior to the Separation, as well as transactions between us and our equity method investees, have been presented as related party transactions in the accompanying Consolidated Financial Statements. See Note 15, "Related Party Transactions" to the Consolidated Financial Statements.

Equity Method Investments

Non-controlled investments are accounted for using the equity method of accounting when we are able to significantly influence the operating policies of the investee. Under the equity method of accounting, investments are recorded at historical cost as an asset and adjusted for capital contributions, dividends and distributions received, and our share of the investee's earnings or losses, which are recorded as earnings from equity method investees on the Consolidated Statements of Operations. Our equity method investments are periodically evaluated for certain factors that may be indicative of other-than-temporary impairment. As of December 31, 2023 and 2022, our carrying amounts of investments in equity method investees exceeded our share of the underlying equity in the net assets of the investees by $352 million and $368 million, respectively. The difference will be amortized over the life of the underlying assets. As of December 31, 2023 and 2022, our consolidated retained earnings balance includes undistributed earnings from equity method investments of zero and $43 million, respectively. We use the cumulative earnings approach to classify proceeds received from equity method investees as dividends or distributions on the Consolidated Statements of Cash Flows.

Equity method investees are described below:

	Investments As of				% Owned As of
	December 31,				December 31,
Equity Method Investee	2023		2022		2023	2022
	(millions)
NEXUS	$	900	$	1,313	50%	50%
Vector	135		135		40%	40%
Millennium	727		752		52.5%	52.5%
Total investments in equity method investees	$	1,762	$	2,200

In May 2023, NEXUS closed on the sale of $750 million of senior unsecured notes with a weighted-average coupon rate of 5.52%. We received a distribution from NEXUS of $371 million, net of fees and expenses, which reduced our investment balance. We used the proceeds from the distribution to repay borrowings outstanding under our Revolving Credit Facility.

In October 2022, DT Midstream closed on the $552 million purchase of an additional 26.25% ownership interest in Millennium from National Grid. The transaction was financed with cash on hand and available capacity under the Company's Revolving Credit Facility. The purchase constituted National Grid's full ownership interest in Millennium and brought our total ownership interest in Millennium to 52.5%. We account for our ownership interest in Millennium under the equity method of accounting. Millennium is not a VIE and we do not have a controlling interest due to shared control with our partner over all of Millennium's significant business activities. Our carrying amount of our Millennium investment exceeded our share of the underlying equity in the net assets of Millennium by $343 million on the acquisition date.

The following tables present summarized financial information of our non-consolidated equity method investees. The amounts included below represent 100% of the results of continuing operations of such entities, including the portion owned by other parties.

Summarized balance sheet data is as follows:

	December 31,
	2023		2022
	(millions)
Current assets	$	159	$	198
Noncurrent assets	4,057		4,160
Current liabilities	208		206
Noncurrent liabilities	$	1,177	$	476

Summarized income statement data is as follows:

	Year Ended December 31,
	2023		2022		2021
	(millions)
Operating revenues	$	823	$	800	$	738
Operating expenses	377		396		371
Net Income	$	392	$	372	$	333

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Significant Accounting Policies

12 Months Ended

Dec. 31, 2023

Accounting Policies [Abstract]

Significant Accounting Policies

SIGNIFICANT ACCOUNTING POLICIES

Cash and Cash Equivalents

Cash and cash equivalents include cash in banks and highly liquid money market investments with remaining maturities of three months or less, when purchased. Cash equivalents are stated at cost, which approximates fair value.

Financing Receivables

Financing receivables are primarily composed of trade accounts receivable and notes receivable, which are stated at net realizable value.

We regularly monitor the credit quality of our financing receivables by reviewing counterparty credit quality indicators and monitoring for triggering events, such as a credit rating downgrade or bankruptcy. We have three internal grades of credit quality, with internal grade 1 as the lowest risk and internal grade 3 as the highest risk. The related credit quality indicators and risk ratings utilized to develop the internal grades have been updated through December 31, 2023. As of December 31, 2023, the Notes receivable — related party of $4 million, which originated prior to 2021, was classified as internal grade 1. There are no notes receivable on nonaccrual status and no past due financing receivables as of December 31, 2023.

Notes receivable are typically considered delinquent (past due) when payment is not received for periods ranging from 60 to 120 days. We cease accruing interest income (nonaccrual status) and may either write off or establish an allowance for expected credit loss for the note receivable when it is expected that all contractual principal or interest amounts due will not be collected. In determining an allowance for expected credit losses for or the write off of notes receivable, we consider the historical payment experience and other factors that are expected to have a specific impact on collection, including existing and future economic conditions. Cash receipts for notes receivable on nonaccrual status that do not bring the account contractually current are first applied to contractually owed past due interest, with any remainder applied to principal. Recognition of interest income is generally resumed when the note receivable becomes contractually current.

We had an investment in certain assets in the Utica Shale region which was accounted for as a note receivable — third party. In the second quarter 2021, we assessed the note receivable for expected loss and recorded a $19 million loss on the note receivable to Asset (gains) losses and impairments, net on the Consolidated Statement of Operations. Additionally, we ceased accruing interest on the note receivable balance and reclassified the note to an Internal grade 3 receivable. Subsequently, as cash payments were received, a portion was recognized as interest income. A third party purchased our investment in certain assets in the Utica Shale region based on significantly improved commodity pricing during the second quarter 2022 for proceeds of $22 million. This resulted in a gain of $17 million recorded in Asset (gains) losses and impairments, net on the Consolidated Statement of Operations. We maintain no continuing involvement with the note receivable.

For trade accounts receivable, the customer allowance for expected credit loss is calculated based on specific review of future collections based on receivable balances generally in excess of 30 days. Existing and future economic conditions, historical loss rates, customer trends and other relevant factors that may affect our ability to collect are also considered. Receivables are written off on a specific identification basis and determined based on the particular circumstances of the associated receivable. Uncollectible expense (recovery) was zero for each of the years ended December 31, 2023, 2022 and 2021. Our collections on accounts receivable from customers are current, and no material rate of historical loss was noted, which resulted in no allowance for expected credit loss as of December 31, 2023 or 2022.

The following table presents a roll-forward of the activity for the notes receivables' allowance for expected credit loss. The balance, if any, is shown as a deduction from the notes receivables' balance in the Consolidated Statements of Financial Position.

	2023		2022		2021
Allowance for expected credit loss- Notes Receivable	(millions)
Balance as of January 1	$	—	$	—	$	—
Additions: Charged to costs, expenses, and other accounts	—		—		19
Deductions: Current period provision and write-offs charged against allowance	—		—		(19)
Balance as of December 31	$	—	$	—	$	—

Property, Plant, and Equipment

Property is stated at cost and includes construction-related labor, materials, and overhead. Expenditures for maintenance and repairs are charged to expense when incurred. Property, plant and equipment is depreciated over its estimated useful life using the straight-line method. See Note 6, "Property, Plant, and Equipment and Intangible Assets" to the Consolidated Financial Statements.

Intangible Assets

Intangible assets with finite useful lives are amortized on a straight-line basis over the periods benefited. See Note 6, "Property, Plant, and Equipment and Intangible Assets" to the Consolidated Financial Statements.

Long-Lived Assets

Long-lived assets are reviewed for impairment whenever events or changes in circumstances indicate the carrying amount of an asset may not be recoverable. If the carrying amount of the asset exceeds the expected undiscounted future cash flows generated by the asset, an impairment loss is recognized resulting in the asset being written down to its estimated fair value. Assets to be disposed of are reported at the lower of the carrying amount or fair value, less costs to sell.

Operation and Maintenance

Operation and maintenance is primarily comprised of costs for labor and employee benefits, outside services, materials, compression, purchased natural gas, operating lease costs, office costs, and other operating and maintenance costs. For the year ended December 31, 2021, general corporate expense allocations from DTE Energy of $32 million, including $20 million of Separation-related transaction costs for legal, accounting, auditing and other professional services DTE Energy incurred for the benefit of DT Midstream, were also included in operation and maintenance. Effective July 1, 2021, with the completion of the Separation, we no longer received corporate allocations from DTE Energy.

Depreciation and Amortization

Depreciation and amortization is related to Property, plant and equipment and Customer relationships and other intangible assets, net, used in our transportation, storage and gathering businesses.

Other Accounting Policies

Footnote	Title
Note 4	Revenue
Note 7	Income Taxes
Note 9	Fair Value
Note 11	Leases

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New Accounting Pronouncements

12 Months Ended

Dec. 31, 2023

Accounting Standards Update and Change in Accounting Principle [Abstract]

New Accounting Pronouncements

NEW ACCOUNTING PRONOUNCEMENTS

Recently Issued Pronouncements

In November 2023, the FASB issued ASU No. 2023-07, Segment Reporting (Topic 280) - Improvements to Reportable Segment Disclosures. The amendments improve reportable segment disclosure requirements, primarily through enhanced disclosures about significant segment expenses and interim disclosure requirements. The amendments are effective for fiscal years beginning after December 15, 2023 and interim periods within fiscal years beginning after December 15, 2024. Early adoption is permitted. The adoption of this standard is not expected to have a significant impact on our Consolidated Financial Statements.

In December 2023, the FASB issued ASU No. 2023-09, Income Taxes (Topic 740) - Improvements to Income Tax Disclosures. The amendments improve transparency of income tax disclosure requirements, primarily through enhanced disclosures of rate reconciliation and income taxes paid. The amendments are effective for annual periods beginning after December 15, 2024. Early adoption is permitted. The adoption of this standard is not expected to have a significant impact on our Consolidated Financial Statements.

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Revenue

12 Months Ended

Dec. 31, 2023

Revenue from Contract with Customer [Abstract]

Revenue

REVENUE

Significant Accounting Policy – Revenue

Pipeline revenues consist of services related to the gathering, transportation and/or storage of natural gas. Gathering revenues consist of services related to the gathering, processing, and/or treating of natural gas. Revenue is measured based upon the pricing or consideration for such services specified in the contract with a customer. Consideration may consist of both fixed components including fixed demand charges and fixed deficiency fee rates for MVCs, and variable components including fixed rates for the actual volumes flowed under interruptible services and other associated fees.

Our contracts with customers generally contain a single performance obligation, which is a promise to deliver either a distinct service or a series of distinct services to the customer. When multiple performance obligations exist, the contract consideration is allocated between the performance obligations based on the relative standalone selling price, which is determined by prices charged to customers or the adjusted market assessment approach. The adjusted market assessment approach involves evaluating the market in which we sell services and estimating the price that a customer in that market would be willing to pay.

Revenue is recognized when performance obligations are satisfied by delivering a service to a customer, which occurs when the service is provided to the customer. When a customer simultaneously receives and consumes the service provided, revenue is recognized over time. Alternatively, if it is determined that the criteria for recognition of revenue over time is not met, the revenue is considered to be recognized at a point in time. Our revenues, including estimated unbilled amounts, are generally recognized over time as actual services are provided, or ratably over time when providing a stand-ready service. Unbilled amounts are generally determined using preliminary meter data volumes and contracted pricing, and typically result in minor adjustments. Generally, uncertainties in the variable consideration components are resolved and revenue amounts are known at the time of recognition. We have determined that the above methods represent a faithful depiction of delivering a service to the customer. Revenues are typically billed and consideration received monthly, however, certain deficiency fees related to MVCs are billed quarterly or annually.

Disaggregation of Revenue

The following is a summary of revenues disaggregated by segment:

	Year Ended December 31,
	2023		2022		2021
	(millions)
Pipeline (a)	$	377	$	339	$	307
Gathering	545		581		534
Elimination of Inter-segment Revenue	—		—		(1)
Total operating revenues	$	922	$	920	$	840

__________________________________

(a)Includes revenues outside the scope of ASC 606 primarily related to contracts accounted for as leases of $7 million, $10 million and $9 million for the years ended December 31, 2023, 2022 and 2021, respectively.

Nature of Services

We primarily provide two types of revenue services: firm service and interruptible service. Firm service revenue contracts provide for fixed revenue commitments regardless of actual volumes of natural gas that flow, which leads to more stable operating performance, revenues and cash flows and limits our exposure to natural gas price fluctuations. Firm service revenue contracts are typically long-term and structured using fixed demand charges or MVCs with fixed deficiency fee rates. Contracts structured using fixed demand charges contain a performance obligation of a stand-ready series of distinct services that are substantially the same with the same pattern of transfer to the customer, therefore revenue is recognized ratably over time. Contracts structured using MVCs with fixed deficiency fee rates require customers to transport or store a minimum volume of natural gas over a specified time period. If a customer fails to meet its MVCs for the specified time period, the contract consideration includes a fixed rate for the actual volumes gathered, transported or stored, and a deficiency fee for the shortfall between the MVCs and the actual volumes gathered, transported, or stored. If a customer exceeds its MVC for the specified time period, the contract consideration is based on fixed rates for the actual volumes gathered, transported, or stored. The contract consideration is allocated to each distinct monthly performance obligation, consistent with the allocation objective and based upon the level of effort required to satisfy the service obligation. Revenues are generally recognized over time based on the output measure of natural gas volumes gathered, transported, or stored, with the recognition of the deficiency fee revenue in the period when it is known the customer cannot make up the deficient volumes in the specified time period. Interruptible service revenue contracts typically contain fixed rates, with total consideration dependent on actual natural gas volumes that flow. Interruptible service revenues are recognized over time based on the output measure of natural gas volumes gathered, transported, or stored. Certain of our gathering contracts allow for the recovery of production-related operating expenses, which are offsetting in revenue and operating expense. Recovery of production-related operating expenses were $53 million, $65 million and $38 million for the years ended December 31, 2023, 2022 and 2021, respectively.

Contract Liabilities

The following is a summary of contract liability activity:

	2023		2022
	(millions)
Balance as of January 1	$	32	$	28
Increases due to cash received or receivable, excluding amounts recognized as revenue during the period (a)	101		13
Revenue recognized that was included in the balance at the beginning of the period	(4)		(9)
Balance as of December 31	$	129	$	32

____________________________________

(a) During the year ended December 31, 2023, we collected prepayment amounts from customers under various long-term revenue contracts on Ohio Utica Gathering, Appalachia Gathering, Blue Union Gathering and LEAP.

Contract liabilities generally represent amounts paid by or receivable from customers for which the associated performance obligation has not yet been satisfied. Contract liabilities associated with these services are recognized upon delivery of the service to the customer.    

The following table presents contract liability amounts as of December 31, 2023 that are expected to be recognized as revenue in future periods:

	(millions)
2024	$	18
2025	20
2026	19
2027	18
2028	16
2029 and thereafter	38
Total	$	129

Transaction Price Allocated to the Remaining Performance Obligations

In accordance with optional exemptions available under Topic 606, we do not disclose the value of unsatisfied performance obligations for (1) contracts with an original expected length of one year or less, (2) with the exception of fixed consideration, contracts for which the amount of revenue recognized depends upon our invoices for actual volumes gathered, transported, or stored, and (3) contracts for which variable consideration relates entirely to an unsatisfied performance obligation.

Such contracts consist of various types of performance obligations, including providing midstream services. Contracts with variable volumes and/or variable pricing, including those with pricing provisions tied to a consumer price or other index, have also been excluded as the related contract consideration is variable at the contract inception. Contract lengths vary from cancellable to multi-year.

The following table presents revenue amounts related to fixed consideration associated with unsatisfied performance obligations as of December 31, 2023 that are expected to be recognized as revenue in future periods:

	(millions)
2024	$	131
2025	138
2026	109
2027	77
2028	52
2029 and thereafter	202
Total	$	709

Costs to Obtain or Fulfill a Contract

We recognize an asset from the costs incurred to obtain a revenue contract only if we expect to recover those costs. In addition, the costs to fulfill a revenue contract are capitalized if the costs are specifically identifiable to a revenue contract, would result in enhancing resources that will be used in satisfying performance obligations in the future, and are expected to be recovered. These capitalized costs are amortized on a systematic basis consistent with the pattern of transfer of the services to which such costs relate.

As of December 31, 2023 and 2022, we had capitalized costs to obtain or fulfill a contract of $18 million and $19 million, respectively, which are included in other current assets and other noncurrent assets in the accompanying Consolidated Statements of Financial Position. During the years ended December 31, 2023, 2022 and 2021 we recognized approximately $1 million of amortization expense related to such capitalized costs.

Major Customers

The following table summarizes customers which represent 10% or more of our total revenue for the years ended December 31, 2023, 2022 and 2021. Both Pipeline and Gathering segments provide services to these customers.

	2023				2022				2021
	Customer		Percentage		Customer		Percentage		Customer		Percentage
	Revenue		of Total		Revenue		of Total		Revenue		of Total
Customers:	(millions, except percentages)
Customer A	$	560	60	%	$	596	65	%	$	563	67	%
Customer B	*		*		*		*		84		10	%
*Represents less than 10%

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Goodwill

12 Months Ended

Dec. 31, 2023

Goodwill and Intangible Assets Disclosure [Abstract]

Goodwill

GOODWILL

We have goodwill that resulted from business combinations. The carrying value of goodwill is evaluated for impairment on an annual basis or whenever events or circumstances indicate that the value of goodwill may be impaired. We performed our annual impairment test as of October 1, 2023 and determined that the estimated fair value of each reporting unit exceeded its carrying value, and no impairment existed. No additions, impairments or other changes occurred during the years ended December 31, 2023, 2022 and 2021.

The following is the summary of the carrying value of goodwill:

	Year Ended December 31,
	2023		2022
	(millions)
Pipeline	$	53	$	53
Gathering	420		420
Total goodwill	$	473	$	473

While we believe the estimates and assumptions in the estimated fair value are reasonable, the actual results may differ from projections. To the extent projected results or cash flows are revised downward, the reporting unit may be required to write down all or a portion of its goodwill, which would adversely impact our earnings.

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Property, Plant, and Equipment and Intangible Assets

12 Months Ended

Dec. 31, 2023

Property, Plant and Equipment [Abstract]

Property, Plant, and Equipment and Intangible Assets

PROPERTY, PLANT, AND EQUIPMENT AND INTANGIBLE ASSETS

Property, Plant, and Equipment

The following is a summary of Property, plant, and equipment by classification:

	Average Estimated Useful Life	December 31,
		2023		2022
	(years)	(millions)
Property, plant, and equipment
Land and other non-depreciable assets	N/A	$	96	$	97
Rights of way and easements	25 to 40	103		103
Pipelines and interconnects	25 to 40	3,460		2,845
Facilities and processing plants	7 to 40	1,234		998
Wells and well equipment	40 to 70	70		70
General plant	3 to 40	40		32
Construction in progress	N/A	279		389
Total Property, plant, and equipment		$	5,282	$	4,534
Less accumulated depreciation		(848)		(728)
Net Property, plant, and equipment		$	4,434	$	3,806

Intangible Assets

The following is a summary of Intangible Assets by classification:

		December 31, 2023						December 31, 2022
	Useful Lives	Gross Carrying Value		Accumulated Amortization		Net Carrying Value		Gross Carrying Value		Accumulated Amortization		Net Carrying Value
		(millions)
Intangible assets subject to amortization
Customer relationships	25 - 40 years (a)	$	2,252	$	(289)	$	1,963	$	2,252	$	(233)	$	2,019
Contract intangibles	14 - 26 years	18		(13)		5		18		(12)		6
Total		$	2,270	$	(302)	$	1,968	$	2,270	$	(245)	$	2,025

_____________________________________

(a) The useful lives of the customer relationship intangible assets are based on the number of years in which the assets are expected to economically contribute to the business. The expected economic benefit incorporates existing customer contracts and expected renewal rates based on the estimated volume and production lives of natural gas resources in each region.

The following table summarizes estimated customer relationships and contract intangibles amortization expense to be recognized during each year through 2028:

	2024		2025		2026		2027		2028
	(millions)
Estimated amortization expense	$	57	$	57	$	57	$	57	$	57

Depreciation and Amortization

The following is a summary of depreciation and amortization expense by asset type:

	Year Ended December 31,
	2023		2022		2021
	(millions)
Property, plant, and equipment	$	125	$	113	$	108
Customer relationships and other intangible assets, net	57		57		58
Total Depreciation and amortization	$	182	$	170	$	166

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Income Taxes

12 Months Ended

Dec. 31, 2023

Income Tax Disclosure [Abstract]

Income Taxes

INCOME TAXES

Significant Accounting Policy – Accounting for Income Taxes

We record the effect of income taxes in accordance with GAAP, which provides for the use of an asset and liability approach. Deferred income tax assets and liabilities are recognized for temporary differences between the basis of assets and liabilities for financial reporting and tax purposes and measured using enacted tax rates in effect for the year in which those temporary differences are expected to be recovered or settled. The effect on deferred tax assets and liabilities as a result of changes in the enacted tax rates is recognized in earnings in the period of enactment. Our recognition of deferred tax assets is based upon a more-likely-than-not criterion. We routinely assess realizability based on objectively-weighted, available positive and negative evidence.

We account for uncertainties in income taxes using a benefit recognition model with a two-step approach: a more-likely-than-not recognition criterion, and a measurement attribute that measures the position as the largest amount of tax benefit that is greater than a 50% likelihood of being realized upon ultimate settlement. If the benefit does not meet the more likely than not criteria for being sustained on its technical merits, no benefit will be recorded. Uncertain tax positions that relate only to timing of when an item is included on a tax return are considered to have met the recognition threshold.

The Separation – Tax Considerations

For period prior to the Separation, discussed at Note 1, "Description of the Business and Basis of Presentation", the income tax provision has been presented on a stand-alone basis as if we filed separate federal, state, local, and foreign income tax returns, referred to as the separate return method.

Tax Legislation

On July 8, 2022, the Commonwealth of Pennsylvania enacted House Bill (H.B.) 1342 which includes a corporate income tax rate reduction from 9.99% to 4.99% that will phase-in over a nine-year period.

Our total Income Tax Expense varied from the statutory federal income tax rate for the following reasons:

	Year Ended December 31,
	2023			2022			2021
	(millions)
Income Before Income Taxes	$	500		$	482		$	422
Income tax expense at statutory rate	105			101			89
State and local income taxes, net of federal benefit	18			24			17
State tax rate changes	(18)			(25)			(3)
Other, net	(1)			—			1
Income Tax Expense	$	104		$	100		$	104
Effective income tax rate	20.9		%	20.7		%	24.7		%

Our 2023 effective tax rate includes the impact of state tax rate changes of an $18 million benefit driven by changes in tax status and updates to state apportionment which were completed in 2023 as a part of ongoing corporate tax structuring, simplification initiatives, and initial post-separation full-year tax return filings.

Our 2022 effective tax rate includes the impact of state tax rate changes of a $25 million benefit driven by the Pennsylvania legislative changes.

Components of Income Tax Expense were as follows:

	Year Ended December 31,
	2023		2022		2021
	(millions)
Current income tax expense
Federal	$	(4)	$	16	$	1
State and other income tax	(2)		14		(1)
Total current income taxes	(6)		30		—
Deferred income tax expense
Federal	109		86		85
State and other income tax	1		(16)		19
Total deferred income tax	110		70		104
	$	104	$	100	$	104

Deferred tax assets and liabilities are recognized for the estimated future tax effect of temporary differences between the tax basis of assets or liabilities and the reported amounts in our Consolidated Financial Statements. We believe it is more likely than not that we will generate sufficient taxable income in future periods to realize our deferred tax assets.

Deferred tax assets (liabilities) were comprised of the following:

	December 31,
	2023		2022
	(millions)
Deferred income tax balance components
Property, plant, and equipment	$	(369)	$	(336)
Federal net operating loss carry-forward	184		129
State and local net operating loss carry-forward, net of federal	102		79
Investment in equity method investees and partnerships	(979)		(811)
Other	31		16
Net deferred income tax asset / (liability)	$	(1,031)	$	(923)
Total deferred income tax assets and liabilities
Deferred income tax assets	$	319	$	234
Deferred income tax liabilities	(1,350)		(1,157)
Net deferred income tax asset / (liability)	$	(1,031)	$	(923)

We have recorded a deferred tax asset related to a federal net operating loss carry-forward of $184 million as of December 31, 2023. U.S. federal net operating losses will be available to be carried forward indefinitely and available to offset 80% of taxable income in future years.

We have recorded state and local deferred tax assets related to net operating loss carry-forwards of $102 million as of December 31, 2023. Of which, $97 million of the state and local net operating loss carry-forwards can be carried indefinitely and $5 million will expire from 2033 through 2042 and are available to offset varying amounts of taxable income in future years.

Uncertain Tax Positions

As of December 31, 2023 and 2022, we did not have any unrecognized tax benefits.

For periods prior to the Separation, we were a member of the consolidated tax return of DTE Energy. As of December 31, 2023, DTE Energy did not have any open tax years subject to examination by the Internal Revenue Service (IRS) for which DT Midstream is a member. DTE Energy also files in multiple states, the statutes of which are open to examination for various periods.

For periods after the Separation, our income tax returns remain subject to examination by federal, state, and local taxing jurisdiction

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Earnings Per Share and Dividends

12 Months Ended

Dec. 31, 2023

Earnings Per Share [Abstract]

Earnings Per Share and Dividends

EARNINGS PER SHARE AND DIVIDENDS

Basic earnings per share is calculated by dividing Net Income attributable to DT Midstream by the weighted-average number of common shares outstanding during the period. Diluted earnings per share reflect the dilution that would occur if any potentially dilutive instruments were exercised or converted into common shares, using the treasury stock method. Restricted stock units and performance share awards, including dividend equivalents on those grants, are potentially dilutive and, if dilutive, are included in the determination of weighted-average shares outstanding. Restricted stock units and performance share awards do not receive cash dividends, as such, these awards are not considered participating securities.

We issued 1,000 shares of common stock at $0.01 par value to its parent, a subsidiary of DTE Energy, in January 2021. Our Board of Directors authorized the issuance of an additional 96,731,466 common shares on June 30, 2021 for a total of 96,732,466 common shares issued and outstanding at the Separation date. This share amount is treated as issued and outstanding and utilized for the calculation of historical basic and diluted earnings per share for all periods prior to the Separation.

The following is a reconciliation of basic and diluted earnings per share:

	Year Ended December 31,
	2023		2022		2021
	(millions, except per share amounts)
Basic and Diluted Earnings per Common Share
Net Income Attributable to DT Midstream	$	384	$	370	$	307
Average number of common shares outstanding — basic	96.9		96.7		96.7
Incremental shares attributable to:
Average dilutive restricted stock units and performance share awards	0.6		0.5		0.2
Average number of common shares outstanding — diluted	97.5		97.2		96.9
Basic Earnings per Common Share	$	3.97	$	3.83	$	3.17
Diluted Earnings per Common Share	$	3.94	$	3.81	$	3.16

We declared the following cash dividends:

Dividends Declared	Dividend Amount				Dividend Payment Date
(quarter ended)	(per-share)		(millions)
2021
September 30	$	0.60	$	58	October 2021
December 31	$	0.60	$	58	January 2022
2022
March 31	$	0.64	$	62	April 2022
June 30	$	0.64	$	62	July 2022
September 30	$	0.64	$	62	October 2022
December 31	$	0.64	$	62	January 2023
2023
March 31	$	0.69	$	67	April 2023
June 30	$	0.69	$	67	July 2023
September 30	$	0.69	$	67	October 2023
December 31	$	0.69	$	67	January 2024

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Fair Value

12 Months Ended

Dec. 31, 2023

Fair Value Disclosures [Abstract]

Fair Value

FAIR VALUE

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 in a principal or most advantageous market. Fair value is a market-based measurement that is determined based on inputs, which refer broadly to assumptions that market participants use in pricing assets or liabilities. These inputs can be readily observable, market corroborated, or generally unobservable inputs. We make certain assumptions we believe that market participants would use in pricing assets or liabilities, including assumptions about risk, and the risks inherent in the inputs to valuation techniques. We believe we uses valuation techniques that maximize the use of observable market-based inputs and minimize the use of unobservable inputs.

A fair value hierarchy has been established that prioritizes the inputs to valuation techniques used to measure fair value in three broad levels. The fair value hierarchy gives the highest priority to quoted prices (unadjusted) in active markets for identical assets or liabilities (Level 1) and the lowest priority to unobservable inputs (Level 3). In some cases, the inputs used to measure fair value might fall in different levels of the fair value hierarchy. All assets and liabilities are required to be classified in their entirety based on the lowest level of input that is significant to the fair value measurement in its entirety. Assessing the significance of a particular input may require judgment considering factors specific to the asset or liability and may affect the valuation of the asset or liability and its placement within the fair value hierarchy. We classify fair value balances based on the fair value hierarchy defined as follows:

•Level 1 — Consists of unadjusted quoted prices in active markets for identical assets or liabilities that we have the ability to access as of the reporting date.

•Level 2 — Consists of inputs other than quoted prices included within Level 1 that are directly observable for the assets or liabilities or indirectly observable through corroboration with observable market data.

•Level 3 — Consists of unobservable inputs for assets or liabilities whose fair value is estimated based on internally developed models or methodologies using inputs that are generally less readily observable and supported by little, if any, market activity at the measurement date. Unobservable inputs are developed based on the best available information and subject to cost-benefit constraints.

Fair Value of Financial Instruments

The following table presents the carrying amount and fair value of financial instruments:

	December 31, 2023								December 31, 2022
	Carrying		Fair Value						Carrying		Fair Value
	Amount		Level 1		Level 2		Level 3		Amount		Level 1		Level 2		Level 3
	(millions)
Cash equivalents (a)	$	36	$	—	$	36	$	—	$	—	$	—	$	—	$	—
Long-term notes receivable — related party	4		—		—		4		4		—		—		4
Short-term borrowings (a)	165		—		165		—		330		—		330		—
Long-term debt (b)	$	3,065	$	—	$	2,850	$	—	$	3,059	$	—	$	2,701	$	—

______________________________________

(a)Short-term borrowings and money market cash equivalents are stated at cost, which approximates fair value.

(b)Carrying value represents principal of $3,099 million, net of unamortized debt discounts and issuance costs.

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Debt

12 Months Ended

Dec. 31, 2023

Debt Disclosure [Abstract]

Debt

DEBT

Amendments to Credit Agreement

In June 2023, we entered into an Amendment No. 2 to our Credit Agreement amending certain of the terms, including, among other things, the replacement of the interest rate provisions related to the Term Loan Facility from Eurodollar Rate to Term SOFR (as defined in the Credit Agreement).

In October 2022, we amended the Credit Agreement to increase the Revolving Credit Facility commitments by $250 million to aggregate commitments of $1.0 billion. The amendment also extended the Revolving Credit Facility maturity date to October 19, 2027, replaced the Revolving Credit Facility's LIBOR interest rate references with Term SOFR, and incorporated various amendments, including amendments to pricing, guarantee and collateral provisions, that will become effective if we receive an investment-grade rating from two of the three credit rating agencies.

Debt Issuances

In April 2022, we issued $600 million in aggregate principal amount of 4.300% senior secured notes due April 2032. The 2032 Notes are guaranteed by certain of our subsidiaries and secured by a first priority lien on certain assets of DT Midstream and our subsidiary guarantors that secure our existing credit facilities. The 2032 Notes have a security fall away provision where the collateral securing the notes will be released if we receive an investment-grade rating from two of the three credit rating agencies.

In June 2021, we issued the senior unsecured notes of $1.1 billion in aggregate principal amount due June 15, 2029 and $1.0 billion in aggregate principal amount due June 15, 2031.

Debt Redemptions

In April 2022, we used $593 million of the net proceeds from the sale of the 2032 Notes to make a partial repayment on the existing indebtedness under the Term Loan Facility. As a result, required quarterly principal payments were eliminated, and the remaining Term Loan Facility balance is not due until maturity in 2028. There were no prepayment costs in conjunction with the partial redemption of the Term Loan Facility. The early redemption resulted in a loss on extinguishment of debt of $9 million and loss on modification of debt of $4 million relating to the write-off of unamortized discount and issuance costs, which was recorded as a loss from financing activities in our Consolidated Statements of Operations for the year ended December 31, 2022.

Interest Expense

The following table summarizes our interest expense:

	Year Ended December 31,
	2023		2022		2021
	(millions)
Interest expense	$	170	$	142	$	113
Capitalized interest	(20)		(5)		(1)
Total interest expense, net	$	150	$	137	$	112

Long-Term Debt

The following is a summary of long-term debt:

			Maturity	December 31,		December 31,
Title	Type	Interest Rate	Date	2023		2022
				(millions)
2029 Notes	Senior Notes (a)	4.125%	2029	$	1,100	$	1,100
2031 Notes	Senior Notes (a)	4.375%	2031	1,000		1,000
2032 Notes	Senior Secured Notes (b)	4.300%	2032	600		600
Term Loan Facility	Term Loan Facility	Variable (c)	2028	399		399
Long-term debt principal				3,099		3,099
Unamortized debt discount				(2)		(3)
Unamortized debt issuance costs				(32)		(37)
Long-term debt, net				$	3,065	$	3,059

______________________________

(a) Interest payable semi-annually in arrears each June 15 and December 15.

(b) Interest payable semi-annually in arrears each April 15 and October 15.

(c) Variable rate is SOFR plus 2.11% for a one-month interest period as of December 31, 2023.

The following table presents scheduled debt maturities, excluding any unamortized discount on debt:

		2024		2025	2026	2027	2028 and Thereafter	Total
	(millions)
Debt maturities		$	—	—	—	—	3,099	$	3,099

Short-Term Credit Arrangements and Borrowings

The following table presents the availability under the Revolving Credit Facility:

	December 31,
	2023
	(millions)
Total availability
Revolving Credit Facility, expiring October 2027	$	1,000
Amounts outstanding
Revolving Credit Facility borrowings (a)	165
Letters of credit	16
	181
Net availability	$	819

______________________________

(a) The weighted average interest rate for Revolving Credit Facility borrowings outstanding is 6.72%.

Borrowings under the Revolving Credit Facility are used for general corporate purposes, acquisitions, and letter of credit issuances to support our operations and liquidity. In April 2023, certain letters of credit totaling $23 million were replaced with surety bonds. See Note 12, "Commitments and Contingencies" for additional information. Revolving Credit Facility related issuance and amendment costs, net of amortization, were $6 million and $8 million, as of December 31, 2023 and 2022, respectively. These costs are included in other noncurrent assets in our Consolidated Statements of Financial Position and are being amortized over the remaining term of the Revolving Credit Facility.

The Credit Agreement covering the Term Loan Facility and Revolving Credit Facility includes financial covenants that we must maintain. These covenants restrict the ability of DT Midstream and our subsidiaries to incur additional indebtedness and guarantee indebtedness, create or incur liens, engage in mergers, consolidations, liquidations or dissolutions, sell, transfer or otherwise dispose of assets, make investments, acquisitions, loans or advances, pay dividends and distributions or repurchase capital stock, prepay, redeem or repurchase certain junior indebtedness, enter into agreements that limit the ability of the restricted subsidiaries to make distributions to DT Midstream or the ability of DT Midstream and our restricted subsidiaries to incur liens on assets and enter into certain transactions with affiliates. The Term Loan Facility requires the maintenance of a minimum debt service coverage ratio of 1.1 to 1, and the Revolving Credit Facility requires maintenance of (i) a maximum consolidated net leverage ratio of 5 to 1, and (ii) a minimum interest coverage ratio of no less than 2.5 to 1. The debt service coverage ratio means the ratio of annual consolidated EBITDA to debt service, as defined in the Credit Agreement. The consolidated net leverage ratio means the ratio of net debt determined in accordance with GAAP to annual consolidated EBITDA. The interest coverage ratio means the ratio of annual consolidated EBITDA to annual interest expense, as defined in the Credit Agreement. The Credit Agreement definition of annual consolidated EBITDA excludes EBITDA from equity method investees, but includes dividends and distributions from equity method investees. As of December 31, 2023, the debt service coverage ratio, the consolidated net leverage ratio and the interest coverage ratio was 8.3 to 1, 2.4 to 1 and 7.8 to 1, respectively, and we were in compliance with these financial covenants.

Dividend Restrictions

The indenture governing the 2029 and 2031 Notes permits the payment of quarterly dividends on common stock in each fiscal year up to a dividend capacity calculated as defined in the indenture. For 2023, the dividend capacity remaining at year end was $356 million.

The Credit Agreement permits the payment of quarterly dividends on common stock in each fiscal year as long as giving pro forma effect thereto, we maintain a first lien net leverage ratio that does not exceed 3.25 to 1. We maintained such first lien net leverage ratio as of December 31, 2023.

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Leases

12 Months Ended

Dec. 31, 2023

Leases [Abstract]

Leases

LEASES

Lessee

Our leases are primarily comprised of equipment and buildings with terms ranging from approximately 3 to 11 years.

A lease exists when we have the right to control the use of identified property, plant or equipment, as conveyed through a contract, for a certain time period and consideration paid. The right to control is deemed to occur when we have the right to obtain substantially all of the economic benefits of the identified assets and the right to direct the use of such assets.

Lease liabilities are calculated utilizing a discount rate to determine the present values of lease payments. GAAP requires the use of the rate implicit in the lease if it is readily determinable. When the rate implicit in the lease is not readily determinable, the incremental borrowing rate is used. The incremental borrowing rate is based upon the rate of interest that would have been paid on a collateralized basis over similar contract terms to that of the leases. The incremental borrowing rates have been determined utilizing an implied secured borrowing rate based upon an unsecured rate for a similar time period of remaining lease terms, which is then adjusted for the estimated impact of collateral. We have leases with non-index-based escalation clauses for fixed dollar or percentage increases over the contract term.

We have certain leases which contain purchase options. Based upon the nature of the leased property and terms of the purchase options, we have determined it is not reasonably certain that such purchase options will be exercised. Thus, the impact of the purchase options has not been included in the determination of right-of-use assets and lease liabilities for the subject leases.

We have certain leases which contain renewal options. Where the renewal options were deemed reasonably certain to occur, the impacts of such options were included in the determination of the right-of-use assets and lease liabilities for the subject leases.

We have agreements with lease and non-lease components, which are generally accounted for separately. Consideration in a lease is allocated between lease and non-lease components based upon the estimated relative standalone prices.

The components of lease cost for the following years includes:

	Year Ended December 31,
	2023		2022		2021
	(millions)
Operating lease cost	$	20	$	20	$	19
Short-term lease cost	3		3		1
	$	23	$	23	$	20

Operating lease cost includes amortization of operating lease right-of-use assets and other related costs. We have elected not to apply the lease balance sheet recognition requirements to short-term leases with a term of 12 months or less. Operating and short-term lease costs are recorded to operation and maintenance in our Consolidated Statements of Operations.

Other relevant information related to leases for the following years includes:

	Year Ended December 31,
	2023			2022			2021
Supplemental Cash Flows Information	(millions, except years and percentages)
Cash paid for amounts included in the measurement of these liabilities:
Operating cash flows for operating leases	$	21		$	18		$	19
Right-of-use assets obtained in exchange for lease obligations:
Operating leases	$	25		$	14		$	9
Weighted Average Remaining Lease Term
Operating leases	4.4 years			4.0 years			4.4 years
Weighted Average Discount Rate
Operating leases	4.8		%	3.5		%	2.6		%

Future minimum lease payments under leases for remaining periods as of December 31, 2023 are as follows:

	Operating Leases
	(millions)
2024	$	15
2025	9
2026	7
2027	7
2028	2
2029 and thereafter	4
Total future minimum lease payments	44
Imputed interest	(4)
Lease liabilities	$	40

Lessor

We lease assets under an operating lease for a pipeline which commenced in December 2018. The lease is comprised of fixed payments with a remaining term of 15 years. The operating lease does not have renewal provisions or options to purchase the assets at the end of the lease and does not have termination for convenience provisions. The lease term extends to the end of the estimated economic life of the leased assets, thereby resulting in no residual value.

A lease exists when we have provided other parties with the right to control the use of identified property, plant or equipment, as conveyed through a contract, for a certain time period and consideration received. The right to control is deemed to occur when we have provided other parties with the right to obtain substantially all of the economic benefits of the identified assets and the right to direct the use of such assets.

Fixed lease income associated with the operating lease was $7 million, $10 million, and $9 million for the years ended December 31, 2023, 2022 and 2021, respectively. Fixed lease income is reported in Operating revenues in our Consolidated Statements of Operations. Depreciation expense associated with the property under the operating lease was $3 million for each of the years ended December 31, 2023, 2022 and 2021.

Future minimum rental revenues for remaining periods as of December 31, 2023 are as follows:

	Operating Lease
	(millions)
2024	$	9
2025	9
2026	9
2027	9
2028	9
2029 and thereafter	88
Total future minimum rental revenues	$	133

Property under the operating lease is as follows:

	December 31,
	2023		2022
	(millions)
Gross property under operating leases	$	58	$	58
Accumulated amortization of property under operating leases	$	15	$	12

Leases

LEASES

Lessee

Our leases are primarily comprised of equipment and buildings with terms ranging from approximately 3 to 11 years.

A lease exists when we have the right to control the use of identified property, plant or equipment, as conveyed through a contract, for a certain time period and consideration paid. The right to control is deemed to occur when we have the right to obtain substantially all of the economic benefits of the identified assets and the right to direct the use of such assets.

Lease liabilities are calculated utilizing a discount rate to determine the present values of lease payments. GAAP requires the use of the rate implicit in the lease if it is readily determinable. When the rate implicit in the lease is not readily determinable, the incremental borrowing rate is used. The incremental borrowing rate is based upon the rate of interest that would have been paid on a collateralized basis over similar contract terms to that of the leases. The incremental borrowing rates have been determined utilizing an implied secured borrowing rate based upon an unsecured rate for a similar time period of remaining lease terms, which is then adjusted for the estimated impact of collateral. We have leases with non-index-based escalation clauses for fixed dollar or percentage increases over the contract term.

We have certain leases which contain purchase options. Based upon the nature of the leased property and terms of the purchase options, we have determined it is not reasonably certain that such purchase options will be exercised. Thus, the impact of the purchase options has not been included in the determination of right-of-use assets and lease liabilities for the subject leases.

We have certain leases which contain renewal options. Where the renewal options were deemed reasonably certain to occur, the impacts of such options were included in the determination of the right-of-use assets and lease liabilities for the subject leases.

We have agreements with lease and non-lease components, which are generally accounted for separately. Consideration in a lease is allocated between lease and non-lease components based upon the estimated relative standalone prices.

The components of lease cost for the following years includes:

	Year Ended December 31,
	2023		2022		2021
	(millions)
Operating lease cost	$	20	$	20	$	19
Short-term lease cost	3		3		1
	$	23	$	23	$	20

Operating lease cost includes amortization of operating lease right-of-use assets and other related costs. We have elected not to apply the lease balance sheet recognition requirements to short-term leases with a term of 12 months or less. Operating and short-term lease costs are recorded to operation and maintenance in our Consolidated Statements of Operations.

Other relevant information related to leases for the following years includes:

	Year Ended December 31,
	2023			2022			2021
Supplemental Cash Flows Information	(millions, except years and percentages)
Cash paid for amounts included in the measurement of these liabilities:
Operating cash flows for operating leases	$	21		$	18		$	19
Right-of-use assets obtained in exchange for lease obligations:
Operating leases	$	25		$	14		$	9
Weighted Average Remaining Lease Term
Operating leases	4.4 years			4.0 years			4.4 years
Weighted Average Discount Rate
Operating leases	4.8		%	3.5		%	2.6		%

Future minimum lease payments under leases for remaining periods as of December 31, 2023 are as follows:

	Operating Leases
	(millions)
2024	$	15
2025	9
2026	7
2027	7
2028	2
2029 and thereafter	4
Total future minimum lease payments	44
Imputed interest	(4)
Lease liabilities	$	40

Lessor

We lease assets under an operating lease for a pipeline which commenced in December 2018. The lease is comprised of fixed payments with a remaining term of 15 years. The operating lease does not have renewal provisions or options to purchase the assets at the end of the lease and does not have termination for convenience provisions. The lease term extends to the end of the estimated economic life of the leased assets, thereby resulting in no residual value.

A lease exists when we have provided other parties with the right to control the use of identified property, plant or equipment, as conveyed through a contract, for a certain time period and consideration received. The right to control is deemed to occur when we have provided other parties with the right to obtain substantially all of the economic benefits of the identified assets and the right to direct the use of such assets.

Fixed lease income associated with the operating lease was $7 million, $10 million, and $9 million for the years ended December 31, 2023, 2022 and 2021, respectively. Fixed lease income is reported in Operating revenues in our Consolidated Statements of Operations. Depreciation expense associated with the property under the operating lease was $3 million for each of the years ended December 31, 2023, 2022 and 2021.

Future minimum rental revenues for remaining periods as of December 31, 2023 are as follows:

	Operating Lease
	(millions)
2024	$	9
2025	9
2026	9
2027	9
2028	9
2029 and thereafter	88
Total future minimum rental revenues	$	133

Property under the operating lease is as follows:

	December 31,
	2023		2022
	(millions)
Gross property under operating leases	$	58	$	58
Accumulated amortization of property under operating leases	$	15	$	12

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Commitments and Contingencies

12 Months Ended

Dec. 31, 2023

Commitments and Contingencies Disclosure [Abstract]

Commitments and Contingencies

COMMITMENTS AND CONTINGENCIES

From time to time, we are subject to legal, administrative and environmental proceedings before various courts, arbitration panels and governmental agencies concerning claims arising in the ordinary course of business. These proceedings include certain contract disputes, additional environmental reviews and investigations, audits and pending judicial matters. We cannot predict the final disposition of such proceedings. We regularly review legal matters and records provisions for claims that we can estimate and are considered probable of loss. The amount or range of reasonably possible losses is not anticipated to, either individually or in the aggregate, materially adversely affect our business, financial condition and results of operations.

Guarantees

In certain limited circumstances, we enter into contractual guarantees. We may guarantee another entity's obligation in the event it fails to perform and may provide guarantees in certain indemnification agreements. We did not have any guarantees of other parties' obligations as of December 31, 2023.

Purchase Commitments

As of December 31, 2023, we were party to long-term purchase commitments relating to a variety of goods and services required for our business. We estimate lifetime purchase commitments of approximately $103 million, due in the periods shown below.

	(millions)
2024	$	14
2025	13
2026	12
2027	11
2028	11
2029 and thereafter	42
Total	$	103

Surety Bonds

In certain limited circumstances, we enter into contracts that require us to obtain external surety bonds to secure our payment and performance. We agree to indemnify the issuers of these surety bonds for amounts, if any, paid by them under these agreements. In the event that any surety bonds are called for non-performance, we would be obligated to reimburse the issuer of the surety bond. The maximum potential indemnification under our surety bond agreements as of December 31, 2023 is $32 million.

Vector Line of Credit

We are the lender under a revolving term credit facility to Vector, the borrower, in the amount of Canadian $70 million. The credit facility was executed in response to the passage of Canadian regulations requiring oil and gas pipelines to demonstrate their financial ability to respond to a catastrophic event and exists for the sole purpose of satisfying these regulations. Vector may only draw upon the facility if the funds are required to respond to a catastrophic event. The maximum potential payout as of December 31, 2023 is USD $53 million. The funding of a loan under the terms of the revolving term credit facility is considered remote.

Contingent Liability

In order to comply with certain state environmental regulations, we have an obligation to restore pipeline right-of-way slope failures that may arise in the ordinary course of business in the Utica and Marcellus formations. We conducted an evaluation, which was prioritized based on the severity and proximity of remaining locations, and used updated cost information to assess the adequacy of the estimate for the contingent liability accrual. Based on this evaluation, we recorded a reduction to the contingent liability accrual and decrease to operation and maintenance expense of $6 million during the year ended December 31, 2023. As of December 31, 2023 and 2022, we had accrued contingent liabilities of $13 million and $19 million, respectively, for future slope restoration expenditures. The accrual is included in other current liabilities and other liabilities in the Consolidated Statements of Financial Position. While restoration and continued evaluation is ongoing, we believe the accrued amounts are sufficient to cover estimated future expenditures.

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Stock-based Compensation and Defined Contribution Plans

12 Months Ended

Dec. 31, 2023

Share-Based Payment Arrangement [Abstract]

Stock-based Compensation and Defined Contribution Plans

STOCK-BASED COMPENSATION AND DEFINED CONTRIBUTION PLANS

The DT Midstream, Inc. Long-Term Incentive Plan ("DT Midstream Plan") permits the grant of incentive and nonqualified stock options, stock appreciation rights, restricted stock awards and restricted stock units, performance share awards, and performance units to employees, consultants and members of DT Midstream's Board of Directors. As a result of a restricted stock award grant, restricted stock unit or performance share award settlement, or by exercise of a stock option, we may issue common stock from our authorized but unissued common stock and/or from outstanding common stock acquired by or on behalf of DT Midstream in the participant's name. The DT Midstream Plan began on the Separation date. Key provisions of the DT Midstream Plan are:

•Authorized limit as of December 31, 2023 was 6,500,000 shares of common stock. The authorized limit increases annually on January 1 by the lesser of 1,750,000 shares of common stock or the amount determined by the DT Midstream Board of Directors.

•Prohibits the grant of a stock option with an exercise price that is less than the fair market value of DT Midstream's stock on the grant date.

Prior to the Separation, our employees participated in DTE Energy's Long-Term Incentive Plan. At the Separation, outstanding DT Midstream employee restricted stock awards and performance share awards were modified or settled as follows:

•DTE Energy restricted stock awards were converted into DT Midstream restricted stock units;

•Unsettled DTE Energy performance share awards were converted into DT Midstream performance share awards.

The restricted stock awards and performance share awards were converted using a formula designed to preserve the fair value of the awards immediately prior to the Separation. All converted awards retained the vesting schedule of the original awards. The conversion of the restricted stock awards and performance share awards qualified as an accounting modification under GAAP. The pre- and post- Separation fair value of the awards was compared, and any incremental fair value was added to the original grant date fair value of the awards. The Separation modification gave rise to incremental fair value of approximately $1 million for the performance share awards granted in January 2021 and is reflected in the compensation cost and the unrecognized compensation costs described below. The Separation modification did not result in incremental fair value for any other converted restricted stock awards or performance share awards.

Prior to the Separation, we received an allocation of costs from DTE Energy associated with stock-based compensation. Allocated costs for the first six months of 2021 are included in the table below. No costs were allocated after July 1, 2021. The following table summarizes our stock-based compensation expense and the related income tax benefit:

	Year Ended December 31,
	2023		2022		2021
	(millions)
Stock-based compensation expense	$	20	$	17	$	12
Tax benefit	$	5	$	4	$	3

Restricted Stock Units

Restricted stock units granted under the DT Midstream Plan are for a specified number of shares of DT Midstream common stock that entitle the holder to receive common stock, a cash payment, or a combination thereof at the end of the specified vesting period, which is generally three or four years. Restricted stock units are deemed to be equity awards. The fair value of restricted stock units is based on DT Midstream's closing common stock price on the grant date. The fair value is amortized to stock-based compensation expense using a graded vesting schedule over the vesting period. Restricted stock units are settled with DT Midstream common stock and fractional shares are settled in cash.

During the vesting period, the number of restricted stock units granted will increase, assuming full dividend reinvestment on each dividend payment date. The recipient of a restricted stock unit has no shareholder rights during the vesting period. Restricted stock units are nontransferable and subject to risk of forfeiture during the vesting period. Forfeitures are recognized in the period they occur.

The following table summarizes restricted stock unit activity for the year ended December 31, 2023:

	Restricted Stock Units	Weighted- Average Grant Date Fair Value
	(thousands)	(per share)
Nonvested as of December 31, 2022	468	$	43.28
Granted (a)	103	51.28
Forfeited	(5)	47.80
Vested	(149)	41.52
Nonvested as of December 31, 2023	417	$	45.68

_____________________________________

(a)Includes initial grants and dividends reinvested.

The weighted-average grant date fair value of restricted stock units granted, excluding dividends reinvested, during the years ended December 31, 2023 and 2022 was $52.66 and $52.25, respectively. No restricted stock units were granted during the year ended December 31, 2021. The intrinsic value of restricted stock units vested and issued during the years ended December 31, 2023, 2022 and 2021 was $8 million, $3.3 million, and $0.1 million, respectively.

Performance Share Awards

Performance share awards granted under the DT Midstream Plan are for a specified number of shares of DT Midstream common stock that entitle the holder to receive common stock, a cash payment, or a combination thereof at the end of the specified vesting period, which is generally three years. Performance share awards are deemed to be equity awards. Performance share stock-based compensation expense is accrued over the vesting period based on the grant date fair value calculated using: (i) DT Midstream's closing common stock price on the grant date; (ii) the grant date fair value of the market condition; and (iii) the probable achievement of performance objectives. For the performance share awards converted at the Separation, the grant date fair value was based on DTE Energy's stock price and market conditions at grant date. The number of shares issued at settlement is determined based on market conditions and the achievement of certain DT Midstream performance objectives. Performance share awards are settled with DT Midstream common stock and fractional shares are settled in cash.

During the vesting period, the number of performance share awards granted will increase, assuming full dividend reinvestment on each dividend payment date. The recipient of a performance share award has no shareholder rights during the vesting period. Performance share awards are nontransferable and are subject to risk of forfeiture during the vesting period. Forfeitures are recognized in the period they occur.

The following table summarizes performance share award activity for the year ended December 31, 2023:

	Performance Share Awards	Weighted- Average Grant Date Fair Value
	(thousands)	(per share)
Nonvested as of December 31, 2022	409	$	56.55
Granted (a)	334	59.02
Forfeited	(19)	62.31
Settled	(167)	34.83
Nonvested as of December 31, 2023	557	$	64.36

_____________________________________

(a)Includes initial grants, dividends reinvested and shares added for achievement of final performance objectives on settled awards.

The weighted-average grant date fair value of performance share awards granted, excluding dividends reinvested, during the years ended December 31, 2023 and 2022 was $53.74 and $72.97, respectively. The intrinsic value of performance share awards settled during the years ended December 31, 2023 and 2022 was $9 million and $4 million, respectively. No performance share awards were granted or settled by DT Midstream during the year ended December 31, 2021.

Unrecognized Compensation Costs

As of December 31, 2023, we had $23 million of total unrecognized compensation costs related to non-vested stock incentive plan arrangements. The cost is expected to be recognized over a weighted-average period of 1.67 years.

Defined Contribution Plans

We sponsor defined contribution retirement savings plans, and participation in one of these plans is available to substantially all employees. We match employee contributions up to certain predefined and Internal Revenue Service limits based on eligible compensation and each employee's contribution rate, and contributes additional amounts in lieu of traditional pension and post-employment healthcare benefits. Prior to the Separation, we participated in the defined contribution retirement savings plans of DTE Energy. DT Midstream's cost for these plans was $7 million, $5 million and $3 million for the years ended December 31, 2023, 2022 and 2021, respectively.

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Segment and Related Information

12 Months Ended

Dec. 31, 2023

Segment Reporting [Abstract]

Segment and Related Information

SEGMENT AND RELATED INFORMATION

We set strategic goals, allocate resources, and evaluate performance based on the following structure:

The Pipeline segment owns and operates interstate and intrastate natural gas pipelines, storage systems, and natural gas gathering lateral pipelines. The Pipeline segment also has interests in equity method investees that own and operate interstate natural gas pipelines. The segment is engaged in the transportation and storage of natural gas for intermediate and end user customers. During the three months ended March 31, 2023, we completed the conversion of the Michigan System from gathering to dry gas transmission service and began providing services under a new long-term dry gas transmission contract. For the year ended December 31, 2023, the Michigan System financial results are presented in the Pipeline segment. The prior years' comparative activity was for gathering services and therefore was not revised from presentation in the Gathering segment.

The Gathering segment owns and operates gas gathering systems. The segment is engaged in collecting natural gas from points at or near customers’ wells for delivery to plants for treating, to gathering pipelines for further gathering, or to pipelines for transportation, as well as associated ancillary services, including compression, dehydration, gas treatment, water impoundment, water transportation, water disposal, and sand mining.

Inter-segment billing for goods and services exchanged between segments is based upon contracted prices of the provider. Inter-segment billings were not significant for the years ended December 31, 2023, 2022 and 2021.

Financial data for our business segments follows:

	Year Ended December 31, 2023
	Pipeline		Gathering		Eliminations		Total
	(millions)
Operating revenues	$	377	$	545	$	—	$	922
Operation and maintenance	55		190		—		245
Depreciation and amortization	69		113		—		182
Taxes other than income	15		13		—		28
Asset (gains) losses and impairments, net	(4)		—		—		(4)
Operating Income	242		229		—		471
Interest expense	55		95		—		150
Interest income	(1)		—		—		(1)
Earnings from equity method investees	(177)		—		—		(177)
Other (income) and expense	—		(1)		—		(1)
Income Tax Expense	75		29		—		104
Net Income	290		106		—		396
Less: Net Income Attributable to Noncontrolling Interests	12		—		—		12
Net Income Attributable to DT Midstream	$	278	$	106	$	—	$	384
Capital expenditures	$	255	$	517	$	—	$	772
	December 31, 2023
Investments in equity method investees	$	1,762	$	—	$	—	$	1,762
Goodwill	53		420		—		473
Total Assets	$	4,439	$	4,543	$	—	$	8,982

	Year Ended December 31, 2022
	Pipeline		Gathering		Eliminations		Total
	(millions)
Operating revenues	$	339	$	581	$	—	$	920
Operation and maintenance	54		213		—		267
Depreciation and amortization	63		107		—		170
Taxes other than income	14		14		—		28
Asset (gains) losses and impairments, net	(6)		(17)		—		(23)
Operating Income	214		264		—		478
Interest expense	57		80		—		137
Interest income	(1)		(2)		—		(3)
Earnings from equity method investees	(150)		—		—		(150)
Loss from financing activities	6		7		—		13
Other (income) and expense	—		(1)		—		(1)
Income Tax Expense	62		38		—		100
Net Income	240		142		—		382
Less: Net Income Attributable to Noncontrolling Interests	12		—		—		12
Net Income Attributable to DT Midstream	$	228	$	142	$	—	$	370
Capital expenditures and acquisitions	$	638	$	252	$	—	$	890
	December 31, 2022
Investments in equity method investees	$	2,200	$	—	$	—	$	2,200
Goodwill	53		420		—		473
Total Assets	$	4,625	$	4,208	$	—	$	8,833

	Year Ended December 31, 2021
	Pipeline		Gathering		Eliminations		Total
	(millions)
Operating revenues	$	307	$	534	$	(1)	$	840
Operation and maintenance	59		173		(1)		231
Depreciation and amortization	63		103		—		166
Taxes other than income	13		11		—		24
Asset (gains) losses and impairments, net	—		17		—		17
Operating Income	172		230		—		402
Interest expense	51		61		—		112
Interest income	(1)		(3)		—		(4)
Earnings from equity method investees	(126)		—		—		(126)
Other (income) and expense	(3)		1		—		(2)
Income Tax Expense	62		42		—		104
Net Income	189		129		—		318
Less: Net Income Attributable to Noncontrolling Interests	11		—		—		11
Net Income Attributable to DT Midstream	$	178	$	129	$	—	$	307
Capital expenditures	$	20	$	120	$	—	$	140
	December 31, 2021
Investments in equity method investees	$	1,691	$	—	$	—	$	1,691
Goodwill	53		420		—		473
Total Assets	$	4,165	$	4,001	$	—	$	8,166

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Related Party Transactions

12 Months Ended

Dec. 31, 2023

Related Party Transactions [Abstract]

Related Party Transactions

RELATED PARTY TRANSACTIONS

Transactions between DT Midstream and DTE Energy prior to the Separation, as well as all transactions between DT Midstream and our equity method investees, have been presented as related party transactions in the accompanying Consolidated Financial Statements.

Prior to the Separation, DTE Energy and its subsidiaries provided physical operations, maintenance, and technical support pursuant to an operating agreement for our facilities. We also utilized various services performed by DTE Energy and its subsidiaries including marketing and capacity optimization services.

Prior to the Separation, interest expense recorded in the Consolidated Statements of Operations was primarily related to interest on the Short-term borrowings due to DTE Energy, amounts of which are shown in the table below. The working capital loan agreement had an interest rate of 3.3% for 2021 and a term of one year. No interest expense on Short-term borrowings due to DTE Energy was incurred after the Separation.

In June 2021, we made the following cash payments:

•Settled Short-term borrowings due to DTE Energy as of June 30, 2021 of $2,537 million

•Settled Accounts receivable due from DTE Energy and Accounts payable due to DTE Energy as of June 30, 2021 for net cash of $9 million

•Provided a one-time special dividend to DTE Energy

On July 1, 2021, DTE Energy completed the Separation through the distribution of 96,732,466 shares of DT Midstream common stock to DTE Energy shareholders. After the Separation, DTE Energy is not considered a related party of DT Midstream.

The following is a summary of our balances with related parties:

	December 31,
	2023		2022
	(millions)
Notes receivable from Vector — long-term	$	4	$	4
Current Liabilities — Other	1		3

The following is a summary of our transactions with related parties:

	Year Ended December 31,
	2023		2022		2021
	(millions)
Revenues
Pipeline	$	—	$	—	$	5
Gathering	—		—		10
Other Costs
Interest income	—		—		(5)
Interest expense	—		—		43
Operation and maintenance and Other expense	(1)		(1)		43
Other
Notes receivable (due from) repaid by DTE Energy	—		—		263
Short-term borrowings (repayment of borrowings) from DTE Energy	—		—		(3,175)
Dividend to DTE Energy	—		—		(501)
Contributions from DTE Energy	—		—		110
Non-cash distributions to DTE Energy	—		—		(10)

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Subsequent Event

12 Months Ended

Dec. 31, 2023

Subsequent Events [Abstract]

Subsequent Event

SUBSEQUENT EVENT

Dividend Declaration

On February 16, 2024, we announced that our Board of Directors declared a quarterly dividend of $0.735 per share of common stock. The dividend is payable to stockholders of record as of March 18, 2024 and is expected to be paid on April 15, 2024.

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Pay vs Performance Disclosure - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2023	Dec. 31, 2022	Dec. 31, 2021
Pay vs Performance Disclosure
Net Income Attributable to DT Midstream	$ 384	$ 370	$ 307

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Insider Trading Arrangements	3 Months Ended
	Dec. 31, 2023
Trading Arrangements, by Individual
Rule 10b5-1 Arrangement Adopted	false
Non-Rule 10b5-1 Arrangement Adopted	false
Rule 10b5-1 Arrangement Terminated	false
Non-Rule 10b5-1 Arrangement Terminated	false

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Significant Accounting Policies (Policies)

12 Months Ended

Dec. 31, 2023

Accounting Policies [Abstract]

Basis of Presentation

Basis of Presentation

The Consolidated Financial Statements and Notes to Consolidated Financial Statements as of and for the periods presented subsequent to July 1, 2021, the date of the Separation, reflect the consolidated financial position, results of operations and cash flows for DT Midstream as an independent company. Prior to the Separation, we operated as a consolidated entity of DTE Energy and not as a standalone company. For the periods prior to the Separation, the Consolidated Financial Statements and Notes to Consolidated Financial Statements were prepared on a carve-out basis using the consolidated financial statements and accounting records of DTE Energy. The carve-out basis financial statements represent our historical financial position, results of operations, and cash flows as they were historically managed in accordance with GAAP and reflect significant assumptions and allocations. The carve-out financial statements may not include all expenses that would have been incurred had we existed as a standalone entity.

GAAP requires management to use estimates and assumptions that impact reported amounts of assets, liabilities, revenues and expenses, and the disclosure of contingent assets and liabilities. Actual results may differ from our estimates. We believe the assumptions underlying these financial statements are reasonable.

Principles of Consolidation

Principles of Consolidation

We consolidate all majority-owned subsidiaries and investments in entities in which we have a controlling influence. Non-controlled investments are accounted for using the equity method of accounting when we are able to significantly influence the operating policies of the investee. When we do not influence the operating policies of an investee, the equity investment is measured at fair value, if readily determinable, or if not readily determinable, at cost less impairment, if applicable. We eliminate all intercompany balances and transactions.

We evaluate whether an entity is a VIE whenever reconsideration events occur. We consolidate VIEs for which we are the primary beneficiary. If we are not the primary beneficiary and an ownership interest is held, the VIE is accounted for under the equity method of accounting. When assessing the determination of the primary beneficiary, we consider all relevant facts and circumstances, including: the power, through voting or similar rights, to direct the activities of the VIE that most significantly impact the VIE's economic performance and the obligation to absorb the expected losses and/or the right to receive the expected returns of the VIE. We perform ongoing reassessments of all VIEs to determine if the primary beneficiary status has changed.

We own an 85% interest in the Stonewall VIE and are the primary beneficiary, therefore Stonewall is consolidated. We own a 50% interest in the South Romeo VIE and are the primary beneficiary, therefore South Romeo is consolidated.

Cash and Cash Equivalents

Cash and Cash Equivalents

Cash and cash equivalents include cash in banks and highly liquid money market investments with remaining maturities of three months or less, when purchased. Cash equivalents are stated at cost, which approximates fair value.

Financing Receivables

Financing Receivables

Financing receivables are primarily composed of trade accounts receivable and notes receivable, which are stated at net realizable value.

We regularly monitor the credit quality of our financing receivables by reviewing counterparty credit quality indicators and monitoring for triggering events, such as a credit rating downgrade or bankruptcy. We have three internal grades of credit quality, with internal grade 1 as the lowest risk and internal grade 3 as the highest risk. The related credit quality indicators and risk ratings utilized to develop the internal grades have been updated through December 31, 2023. As of December 31, 2023, the Notes receivable — related party of $4 million, which originated prior to 2021, was classified as internal grade 1. There are no notes receivable on nonaccrual status and no past due financing receivables as of December 31, 2023.

Notes receivable are typically considered delinquent (past due) when payment is not received for periods ranging from 60 to 120 days. We cease accruing interest income (nonaccrual status) and may either write off or establish an allowance for expected credit loss for the note receivable when it is expected that all contractual principal or interest amounts due will not be collected. In determining an allowance for expected credit losses for or the write off of notes receivable, we consider the historical payment experience and other factors that are expected to have a specific impact on collection, including existing and future economic conditions. Cash receipts for notes receivable on nonaccrual status that do not bring the account contractually current are first applied to contractually owed past due interest, with any remainder applied to principal. Recognition of interest income is generally resumed when the note receivable becomes contractually current.

We had an investment in certain assets in the Utica Shale region which was accounted for as a note receivable — third party. In the second quarter 2021, we assessed the note receivable for expected loss and recorded a $19 million loss on the note receivable to Asset (gains) losses and impairments, net on the Consolidated Statement of Operations. Additionally, we ceased accruing interest on the note receivable balance and reclassified the note to an Internal grade 3 receivable. Subsequently, as cash payments were received, a portion was recognized as interest income. A third party purchased our investment in certain assets in the Utica Shale region based on significantly improved commodity pricing during the second quarter 2022 for proceeds of $22 million. This resulted in a gain of $17 million recorded in Asset (gains) losses and impairments, net on the Consolidated Statement of Operations. We maintain no continuing involvement with the note receivable.

For trade accounts receivable, the customer allowance for expected credit loss is calculated based on specific review of future collections based on receivable balances generally in excess of 30 days. Existing and future economic conditions, historical loss rates, customer trends and other relevant factors that may affect our ability to collect are also considered. Receivables are written off on a specific identification basis and determined based on the particular circumstances of the associated receivable.

Property, Plant, and Equipment

Property, Plant, and Equipment

Property is stated at cost and includes construction-related labor, materials, and overhead. Expenditures for maintenance and repairs are charged to expense when incurred. Property, plant and equipment is depreciated over its estimated useful life using the straight-line method.

Intangible Assets and Long-Lived Assets

Intangible Assets

Intangible assets with finite useful lives are amortized on a straight-line basis over the periods benefited. See Note 6, "Property, Plant, and Equipment and Intangible Assets" to the Consolidated Financial Statements.

Long-Lived Assets

Long-lived assets are reviewed for impairment whenever events or changes in circumstances indicate the carrying amount of an asset may not be recoverable. If the carrying amount of the asset exceeds the expected undiscounted future cash flows generated by the asset, an impairment loss is recognized resulting in the asset being written down to its estimated fair value. Assets to be disposed of are reported at the lower of the carrying amount or fair value, less costs to sell.

Operations and Maintenance

Operation and Maintenance

Operation and maintenance is primarily comprised of costs for labor and employee benefits, outside services, materials, compression, purchased natural gas, operating lease costs, office costs, and other operating and maintenance costs. For the year ended December 31, 2021, general corporate expense allocations from DTE Energy of $32 million, including $20 million of Separation-related transaction costs for legal, accounting, auditing and other professional services DTE Energy incurred for the benefit of DT Midstream, were also included in operation and maintenance. Effective July 1, 2021, with the completion of the Separation, we no longer received corporate allocations from DTE Energy.

Depreciation and Amortization

Depreciation and Amortization

Depreciation and amortization is related to Property, plant and equipment and Customer relationships and other intangible assets, net, used in our transportation, storage and gathering businesses.

Recently Issued Pronouncements

Recently Issued Pronouncements

In November 2023, the FASB issued ASU No. 2023-07, Segment Reporting (Topic 280) - Improvements to Reportable Segment Disclosures. The amendments improve reportable segment disclosure requirements, primarily through enhanced disclosures about significant segment expenses and interim disclosure requirements. The amendments are effective for fiscal years beginning after December 15, 2023 and interim periods within fiscal years beginning after December 15, 2024. Early adoption is permitted. The adoption of this standard is not expected to have a significant impact on our Consolidated Financial Statements.

In December 2023, the FASB issued ASU No. 2023-09, Income Taxes (Topic 740) - Improvements to Income Tax Disclosures. The amendments improve transparency of income tax disclosure requirements, primarily through enhanced disclosures of rate reconciliation and income taxes paid. The amendments are effective for annual periods beginning after December 15, 2024. Early adoption is permitted. The adoption of this standard is not expected to have a significant impact on our Consolidated Financial Statements.

Accounting for Income Taxes

Significant Accounting Policy – Accounting for Income Taxes

We record the effect of income taxes in accordance with GAAP, which provides for the use of an asset and liability approach. Deferred income tax assets and liabilities are recognized for temporary differences between the basis of assets and liabilities for financial reporting and tax purposes and measured using enacted tax rates in effect for the year in which those temporary differences are expected to be recovered or settled. The effect on deferred tax assets and liabilities as a result of changes in the enacted tax rates is recognized in earnings in the period of enactment. Our recognition of deferred tax assets is based upon a more-likely-than-not criterion. We routinely assess realizability based on objectively-weighted, available positive and negative evidence.

We account for uncertainties in income taxes using a benefit recognition model with a two-step approach: a more-likely-than-not recognition criterion, and a measurement attribute that measures the position as the largest amount of tax benefit that is greater than a 50% likelihood of being realized upon ultimate settlement. If the benefit does not meet the more likely than not criteria for being sustained on its technical merits, no benefit will be recorded. Uncertain tax positions that relate only to timing of when an item is included on a tax return are considered to have met the recognition threshold.

Revenue

Significant Accounting Policy – Revenue

Pipeline revenues consist of services related to the gathering, transportation and/or storage of natural gas. Gathering revenues consist of services related to the gathering, processing, and/or treating of natural gas. Revenue is measured based upon the pricing or consideration for such services specified in the contract with a customer. Consideration may consist of both fixed components including fixed demand charges and fixed deficiency fee rates for MVCs, and variable components including fixed rates for the actual volumes flowed under interruptible services and other associated fees.

Our contracts with customers generally contain a single performance obligation, which is a promise to deliver either a distinct service or a series of distinct services to the customer. When multiple performance obligations exist, the contract consideration is allocated between the performance obligations based on the relative standalone selling price, which is determined by prices charged to customers or the adjusted market assessment approach. The adjusted market assessment approach involves evaluating the market in which we sell services and estimating the price that a customer in that market would be willing to pay.

Revenue is recognized when performance obligations are satisfied by delivering a service to a customer, which occurs when the service is provided to the customer. When a customer simultaneously receives and consumes the service provided, revenue is recognized over time. Alternatively, if it is determined that the criteria for recognition of revenue over time is not met, the revenue is considered to be recognized at a point in time. Our revenues, including estimated unbilled amounts, are generally recognized over time as actual services are provided, or ratably over time when providing a stand-ready service. Unbilled amounts are generally determined using preliminary meter data volumes and contracted pricing, and typically result in minor adjustments. Generally, uncertainties in the variable consideration components are resolved and revenue amounts are known at the time of recognition. We have determined that the above methods represent a faithful depiction of delivering a service to the customer. Revenues are typically billed and consideration received monthly, however, certain deficiency fees related to MVCs are billed quarterly or annually.

Lessee

Lessee

Our leases are primarily comprised of equipment and buildings with terms ranging from approximately 3 to 11 years.

A lease exists when we have the right to control the use of identified property, plant or equipment, as conveyed through a contract, for a certain time period and consideration paid. The right to control is deemed to occur when we have the right to obtain substantially all of the economic benefits of the identified assets and the right to direct the use of such assets.

Lease liabilities are calculated utilizing a discount rate to determine the present values of lease payments. GAAP requires the use of the rate implicit in the lease if it is readily determinable. When the rate implicit in the lease is not readily determinable, the incremental borrowing rate is used. The incremental borrowing rate is based upon the rate of interest that would have been paid on a collateralized basis over similar contract terms to that of the leases. The incremental borrowing rates have been determined utilizing an implied secured borrowing rate based upon an unsecured rate for a similar time period of remaining lease terms, which is then adjusted for the estimated impact of collateral. We have leases with non-index-based escalation clauses for fixed dollar or percentage increases over the contract term.

We have certain leases which contain purchase options. Based upon the nature of the leased property and terms of the purchase options, we have determined it is not reasonably certain that such purchase options will be exercised. Thus, the impact of the purchase options has not been included in the determination of right-of-use assets and lease liabilities for the subject leases.

We have certain leases which contain renewal options. Where the renewal options were deemed reasonably certain to occur, the impacts of such options were included in the determination of the right-of-use assets and lease liabilities for the subject leases.

We have agreements with lease and non-lease components, which are generally accounted for separately. Consideration in a lease is allocated between lease and non-lease components based upon the estimated relative standalone prices.

Lessor

Lessor

We lease assets under an operating lease for a pipeline which commenced in December 2018. The lease is comprised of fixed payments with a remaining term of 15 years. The operating lease does not have renewal provisions or options to purchase the assets at the end of the lease and does not have termination for convenience provisions. The lease term extends to the end of the estimated economic life of the leased assets, thereby resulting in no residual value.

A lease exists when we have provided other parties with the right to control the use of identified property, plant or equipment, as conveyed through a contract, for a certain time period and consideration received. The right to control is deemed to occur when we have provided other parties with the right to obtain substantially all of the economic benefits of the identified assets and the right to direct the use of such assets.

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Description of the Business and Basis of Presentation (Tables)

12 Months Ended

Dec. 31, 2023

Organization, Consolidation and Presentation of Financial Statements [Abstract]

Schedule of Variable Interest Entities

The following table summarizes the major line items in the Consolidated Statements of Financial Position for consolidated VIEs as of December 31, 2023 and 2022. All assets and liabilities of a consolidated VIE are included in the table when it has been determined that a consolidated VIE has either (1) assets that can be used only to settle obligations of the VIE or (2) liabilities for which creditors do not have recourse to the general credit of the primary beneficiary. The assets and liabilities of consolidated VIEs that meet the definition of a business and whose assets can be used for purposes other than the settlement of the VIEs' obligations have been excluded from the table below.

	December 31,
	2023		2022
	(millions)
ASSETS (a)
Cash	$	13	$	27
Accounts receivable	10		9
Other current assets	2		3
Intangible assets, net	483		498
Property, plant and equipment, net	391		403
Goodwill	25		25
	$	924	$	965
LIABILITIES (a)
Accounts payable and other current liabilities	$	4	$	4
Other noncurrent liabilities	3		4
	$	7	$	8

_____________________________________

(a)Amounts shown are 100% of the consolidated VIEs' assets and liabilities.

Schedule of Equity Method Investments

Equity method investees are described below:

	Investments As of				% Owned As of
	December 31,				December 31,
Equity Method Investee	2023		2022		2023	2022
	(millions)
NEXUS	$	900	$	1,313	50%	50%
Vector	135		135		40%	40%
Millennium	727		752		52.5%	52.5%
Total investments in equity method investees	$	1,762	$	2,200

The following tables present summarized financial information of our non-consolidated equity method investees. The amounts included below represent 100% of the results of continuing operations of such entities, including the portion owned by other parties.

Summarized balance sheet data is as follows:

	December 31,
	2023		2022
	(millions)
Current assets	$	159	$	198
Noncurrent assets	4,057		4,160
Current liabilities	208		206
Noncurrent liabilities	$	1,177	$	476

Summarized income statement data is as follows:

	Year Ended December 31,
	2023		2022		2021
	(millions)
Operating revenues	$	823	$	800	$	738
Operating expenses	377		396		371
Net Income	$	392	$	372	$	333

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Significant Accounting Policies (Tables)

12 Months Ended

Dec. 31, 2023

Accounting Policies [Abstract]

Schedule of Roll-Forward of Activity for Financing Receivables Allowance for Expected Credit Loss

Our collections on accounts receivable from customers are current, and no material rate of historical loss was noted, which resulted in no allowance for expected credit loss as of December 31, 2023 or 2022.

The following table presents a roll-forward of the activity for the notes receivables' allowance for expected credit loss. The balance, if any, is shown as a deduction from the notes receivables' balance in the Consolidated Statements of Financial Position.

	2023		2022		2021
Allowance for expected credit loss- Notes Receivable	(millions)
Balance as of January 1	$	—	$	—	$	—
Additions: Charged to costs, expenses, and other accounts	—		—		19
Deductions: Current period provision and write-offs charged against allowance	—		—		(19)
Balance as of December 31	$	—	$	—	$	—

Other Accounting Policies

Other Accounting Policies

Footnote	Title
Note 4	Revenue
Note 7	Income Taxes
Note 9	Fair Value
Note 11	Leases

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Revenue (Tables)

12 Months Ended

Dec. 31, 2023

Revenue from Contract with Customer [Abstract]

Disaggregation of Revenue

The following is a summary of revenues disaggregated by segment:

	Year Ended December 31,
	2023		2022		2021
	(millions)
Pipeline (a)	$	377	$	339	$	307
Gathering	545		581		534
Elimination of Inter-segment Revenue	—		—		(1)
Total operating revenues	$	922	$	920	$	840

__________________________________

(a)Includes revenues outside the scope of ASC 606 primarily related to contracts accounted for as leases of $7 million, $10 million and $9 million for the years ended December 31, 2023, 2022 and 2021, respectively.

Summary of Contact Liability Activity

The following is a summary of contract liability activity:

	2023		2022
	(millions)
Balance as of January 1	$	32	$	28
Increases due to cash received or receivable, excluding amounts recognized as revenue during the period (a)	101		13
Revenue recognized that was included in the balance at the beginning of the period	(4)		(9)
Balance as of December 31	$	129	$	32

____________________________________

(a) During the year ended December 31, 2023, we collected prepayment amounts from customers under various long-term revenue contracts on Ohio Utica Gathering, Appalachia Gathering, Blue Union Gathering and LEAP.

Revenue Expected to be Recognized in Future Periods

The following table presents contract liability amounts as of December 31, 2023 that are expected to be recognized as revenue in future periods:

	(millions)
2024	$	18
2025	20
2026	19
2027	18
2028	16
2029 and thereafter	38
Total	$	129

The following table presents revenue amounts related to fixed consideration associated with unsatisfied performance obligations as of December 31, 2023 that are expected to be recognized as revenue in future periods:

	(millions)
2024	$	131
2025	138
2026	109
2027	77
2028	52
2029 and thereafter	202
Total	$	709

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Goodwill (Tables)

12 Months Ended

Dec. 31, 2023

Goodwill and Intangible Assets Disclosure [Abstract]

Schedule of Goodwill

The following is the summary of the carrying value of goodwill:

	Year Ended December 31,
	2023		2022
	(millions)
Pipeline	$	53	$	53
Gathering	420		420
Total goodwill	$	473	$	473

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Property, Plant, and Equipment and Intangible Assets (Tables)

12 Months Ended

Dec. 31, 2023

Property, Plant and Equipment [Abstract]

Schedule of Property, Plant and Equipment

The following is a summary of Property, plant, and equipment by classification:

	Average Estimated Useful Life	December 31,
		2023		2022
	(years)	(millions)
Property, plant, and equipment
Land and other non-depreciable assets	N/A	$	96	$	97
Rights of way and easements	25 to 40	103		103
Pipelines and interconnects	25 to 40	3,460		2,845
Facilities and processing plants	7 to 40	1,234		998
Wells and well equipment	40 to 70	70		70
General plant	3 to 40	40		32
Construction in progress	N/A	279		389
Total Property, plant, and equipment		$	5,282	$	4,534
Less accumulated depreciation		(848)		(728)
Net Property, plant, and equipment		$	4,434	$	3,806

Schedule of Intangible Assets

The following is a summary of Intangible Assets by classification:

		December 31, 2023						December 31, 2022
	Useful Lives	Gross Carrying Value		Accumulated Amortization		Net Carrying Value		Gross Carrying Value		Accumulated Amortization		Net Carrying Value
		(millions)
Intangible assets subject to amortization
Customer relationships	25 - 40 years (a)	$	2,252	$	(289)	$	1,963	$	2,252	$	(233)	$	2,019
Contract intangibles	14 - 26 years	18		(13)		5		18		(12)		6
Total		$	2,270	$	(302)	$	1,968	$	2,270	$	(245)	$	2,025

_____________________________________

(a) The useful lives of the customer relationship intangible assets are based on the number of years in which the assets are expected to economically contribute to the business. The expected economic benefit incorporates existing customer contracts and expected renewal rates based on the estimated volume and production lives of natural gas resources in each region.

Schedule of Estimated Intangibles Assets Amortization Expense

The following table summarizes estimated customer relationships and contract intangibles amortization expense to be recognized during each year through 2028:

	2024		2025		2026		2027		2028
	(millions)
Estimated amortization expense	$	57	$	57	$	57	$	57	$	57

Schedule of Depreciation and Amortization

The following is a summary of depreciation and amortization expense by asset type:

	Year Ended December 31,
	2023		2022		2021
	(millions)
Property, plant, and equipment	$	125	$	113	$	108
Customer relationships and other intangible assets, net	57		57		58
Total Depreciation and amortization	$	182	$	170	$	166

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Income Taxes (Tables)

12 Months Ended

Dec. 31, 2023

Income Tax Disclosure [Abstract]

Schedule of Effective Income Tax Rate Reconciliation

Our total Income Tax Expense varied from the statutory federal income tax rate for the following reasons:

	Year Ended December 31,
	2023			2022			2021
	(millions)
Income Before Income Taxes	$	500		$	482		$	422
Income tax expense at statutory rate	105			101			89
State and local income taxes, net of federal benefit	18			24			17
State tax rate changes	(18)			(25)			(3)
Other, net	(1)			—			1
Income Tax Expense	$	104		$	100		$	104
Effective income tax rate	20.9		%	20.7		%	24.7		%

Schedule of Income Tax Expense

Components of Income Tax Expense were as follows:

	Year Ended December 31,
	2023		2022		2021
	(millions)
Current income tax expense
Federal	$	(4)	$	16	$	1
State and other income tax	(2)		14		(1)
Total current income taxes	(6)		30		—
Deferred income tax expense
Federal	109		86		85
State and other income tax	1		(16)		19
Total deferred income tax	110		70		104
	$	104	$	100	$	104

Schedule of Deferred Tax Assets (Liabilities)

Deferred tax assets (liabilities) were comprised of the following:

	December 31,
	2023		2022
	(millions)
Deferred income tax balance components
Property, plant, and equipment	$	(369)	$	(336)
Federal net operating loss carry-forward	184		129
State and local net operating loss carry-forward, net of federal	102		79
Investment in equity method investees and partnerships	(979)		(811)
Other	31		16
Net deferred income tax asset / (liability)	$	(1,031)	$	(923)
Total deferred income tax assets and liabilities
Deferred income tax assets	$	319	$	234
Deferred income tax liabilities	(1,350)		(1,157)
Net deferred income tax asset / (liability)	$	(1,031)	$	(923)

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Earnings Per Share and Dividends (Tables)

12 Months Ended

Dec. 31, 2023

Earnings Per Share [Abstract]

Reconciliation of Basic and Diluted Earnings Per Share

The following is a reconciliation of basic and diluted earnings per share:

	Year Ended December 31,
	2023		2022		2021
	(millions, except per share amounts)
Basic and Diluted Earnings per Common Share
Net Income Attributable to DT Midstream	$	384	$	370	$	307
Average number of common shares outstanding — basic	96.9		96.7		96.7
Incremental shares attributable to:
Average dilutive restricted stock units and performance share awards	0.6		0.5		0.2
Average number of common shares outstanding — diluted	97.5		97.2		96.9
Basic Earnings per Common Share	$	3.97	$	3.83	$	3.17
Diluted Earnings per Common Share	$	3.94	$	3.81	$	3.16

Schedule of Cash Dividends Declared

We declared the following cash dividends:

Dividends Declared	Dividend Amount				Dividend Payment Date
(quarter ended)	(per-share)		(millions)
2021
September 30	$	0.60	$	58	October 2021
December 31	$	0.60	$	58	January 2022
2022
March 31	$	0.64	$	62	April 2022
June 30	$	0.64	$	62	July 2022
September 30	$	0.64	$	62	October 2022
December 31	$	0.64	$	62	January 2023
2023
March 31	$	0.69	$	67	April 2023
June 30	$	0.69	$	67	July 2023
September 30	$	0.69	$	67	October 2023
December 31	$	0.69	$	67	January 2024

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Fair Value (Tables)

12 Months Ended

Dec. 31, 2023

Fair Value Disclosures [Abstract]

Carrying Amount of Fair Value of Financial Instruments

The following table presents the carrying amount and fair value of financial instruments:

	December 31, 2023								December 31, 2022
	Carrying		Fair Value						Carrying		Fair Value
	Amount		Level 1		Level 2		Level 3		Amount		Level 1		Level 2		Level 3
	(millions)
Cash equivalents (a)	$	36	$	—	$	36	$	—	$	—	$	—	$	—	$	—
Long-term notes receivable — related party	4		—		—		4		4		—		—		4
Short-term borrowings (a)	165		—		165		—		330		—		330		—
Long-term debt (b)	$	3,065	$	—	$	2,850	$	—	$	3,059	$	—	$	2,701	$	—

______________________________________

(a)Short-term borrowings and money market cash equivalents are stated at cost, which approximates fair value.

(b)Carrying value represents principal of $3,099 million, net of unamortized debt discounts and issuance costs.

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Debt (Tables)

12 Months Ended

Dec. 31, 2023

Debt Disclosure [Abstract]

Schedule of Long-term Debt Outstanding

The following is a summary of long-term debt:

			Maturity	December 31,		December 31,
Title	Type	Interest Rate	Date	2023		2022
				(millions)
2029 Notes	Senior Notes (a)	4.125%	2029	$	1,100	$	1,100
2031 Notes	Senior Notes (a)	4.375%	2031	1,000		1,000
2032 Notes	Senior Secured Notes (b)	4.300%	2032	600		600
Term Loan Facility	Term Loan Facility	Variable (c)	2028	399		399
Long-term debt principal				3,099		3,099
Unamortized debt discount				(2)		(3)
Unamortized debt issuance costs				(32)		(37)
Long-term debt, net				$	3,065	$	3,059

______________________________

(a) Interest payable semi-annually in arrears each June 15 and December 15.

(b) Interest payable semi-annually in arrears each April 15 and October 15.

(c) Variable rate is SOFR plus 2.11% for a one-month interest period as of December 31, 2023.

Schedule of Debt Maturities

The following table presents scheduled debt maturities, excluding any unamortized discount on debt:

		2024		2025	2026	2027	2028 and Thereafter	Total
	(millions)
Debt maturities		$	—	—	—	—	3,099	$	3,099

Schedule of Availability Under the Revolving Credit Facility

The following table presents the availability under the Revolving Credit Facility:

	December 31,
	2023
	(millions)
Total availability
Revolving Credit Facility, expiring October 2027	$	1,000
Amounts outstanding
Revolving Credit Facility borrowings (a)	165
Letters of credit	16
	181
Net availability	$	819

______________________________

(a) The weighted average interest rate for Revolving Credit Facility borrowings outstanding is 6.72%.

Schedule of Interest Income and Interest Expense

The following table summarizes our interest expense:

	Year Ended December 31,
	2023		2022		2021
	(millions)
Interest expense	$	170	$	142	$	113
Capitalized interest	(20)		(5)		(1)
Total interest expense, net	$	150	$	137	$	112

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Leases (Tables)

12 Months Ended

Dec. 31, 2023

Leases [Abstract]

Schedule of Components of Lease Cost and Other Relevant Information Related to Leases

for the following years includes:

	Year Ended December 31,
	2023		2022		2021
	(millions)
Operating lease cost	$	20	$	20	$	19
Short-term lease cost	3		3		1
	$	23	$	23	$	20

Other relevant information related to leases for the following years includes:

	Year Ended December 31,
	2023			2022			2021
Supplemental Cash Flows Information	(millions, except years and percentages)
Cash paid for amounts included in the measurement of these liabilities:
Operating cash flows for operating leases	$	21		$	18		$	19
Right-of-use assets obtained in exchange for lease obligations:
Operating leases	$	25		$	14		$	9
Weighted Average Remaining Lease Term
Operating leases	4.4 years			4.0 years			4.4 years
Weighted Average Discount Rate
Operating leases	4.8		%	3.5		%	2.6		%

Schedule of Future Minimum Lease Payments Under Leases

uture minimum lease payments under leases for remaining periods as of December 31, 2023 are as follows:

	Operating Leases
	(millions)
2024	$	15
2025	9
2026	7
2027	7
2028	2
2029 and thereafter	4
Total future minimum lease payments	44
Imputed interest	(4)
Lease liabilities	$	40

Schedule of Future Minimum Rental Revenues

uture minimum rental revenues for remaining periods as of December 31, 2023 are as follows:

	Operating Lease
	(millions)
2024	$	9
2025	9
2026	9
2027	9
2028	9
2029 and thereafter	88
Total future minimum rental revenues	$	133

Schedule of Property Under Operating Leases

Property under the operating lease is as follows:

	December 31,
	2023		2022
	(millions)
Gross property under operating leases	$	58	$	58
Accumulated amortization of property under operating leases	$	15	$	12

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Commitment and Contingencies (Tables)

12 Months Ended

Dec. 31, 2023

Commitments and Contingencies Disclosure [Abstract]

Schedule of Purchase Commitments

We estimate lifetime purchase commitments of approximately $103 million, due in the periods shown below.

	(millions)
2024	$	14
2025	13
2026	12
2027	11
2028	11
2029 and thereafter	42
Total	$	103

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Stock-based Compensation and Defined Contribution Plans (Tables)

12 Months Ended

Dec. 31, 2023

Share-Based Payment Arrangement [Abstract]

Summary of Stock-based Compensation Expense

The following table summarizes our stock-based compensation expense and the related income tax benefit:

	Year Ended December 31,
	2023		2022		2021
	(millions)
Stock-based compensation expense	$	20	$	17	$	12
Tax benefit	$	5	$	4	$	3

Summary of Restricted Stock Unit Activity

The following table summarizes restricted stock unit activity for the year ended December 31, 2023:

	Restricted Stock Units	Weighted- Average Grant Date Fair Value
	(thousands)	(per share)
Nonvested as of December 31, 2022	468	$	43.28
Granted (a)	103	51.28
Forfeited	(5)	47.80
Vested	(149)	41.52
Nonvested as of December 31, 2023	417	$	45.68

_____________________________________

(a)Includes initial grants and dividends reinvested.

Summary of Performance Shares Activity

The following table summarizes performance share award activity for the year ended December 31, 2023:

	Performance Share Awards	Weighted- Average Grant Date Fair Value
	(thousands)	(per share)
Nonvested as of December 31, 2022	409	$	56.55
Granted (a)	334	59.02
Forfeited	(19)	62.31
Settled	(167)	34.83
Nonvested as of December 31, 2023	557	$	64.36

_____________________________________

(a)Includes initial grants, dividends reinvested and shares added for achievement of final performance objectives on settled awards.

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Segment and Related Information (Tables)

12 Months Ended

Dec. 31, 2023

Segment Reporting [Abstract]

Schedule of Inter-segment Billing and Financial Data by Business Segment

Financial data for our business segments follows:

	Year Ended December 31, 2023
	Pipeline		Gathering		Eliminations		Total
	(millions)
Operating revenues	$	377	$	545	$	—	$	922
Operation and maintenance	55		190		—		245
Depreciation and amortization	69		113		—		182
Taxes other than income	15		13		—		28
Asset (gains) losses and impairments, net	(4)		—		—		(4)
Operating Income	242		229		—		471
Interest expense	55		95		—		150
Interest income	(1)		—		—		(1)
Earnings from equity method investees	(177)		—		—		(177)
Other (income) and expense	—		(1)		—		(1)
Income Tax Expense	75		29		—		104
Net Income	290		106		—		396
Less: Net Income Attributable to Noncontrolling Interests	12		—		—		12
Net Income Attributable to DT Midstream	$	278	$	106	$	—	$	384
Capital expenditures	$	255	$	517	$	—	$	772
	December 31, 2023
Investments in equity method investees	$	1,762	$	—	$	—	$	1,762
Goodwill	53		420		—		473
Total Assets	$	4,439	$	4,543	$	—	$	8,982

	Year Ended December 31, 2022
	Pipeline		Gathering		Eliminations		Total
	(millions)
Operating revenues	$	339	$	581	$	—	$	920
Operation and maintenance	54		213		—		267
Depreciation and amortization	63		107		—		170
Taxes other than income	14		14		—		28
Asset (gains) losses and impairments, net	(6)		(17)		—		(23)
Operating Income	214		264		—		478
Interest expense	57		80		—		137
Interest income	(1)		(2)		—		(3)
Earnings from equity method investees	(150)		—		—		(150)
Loss from financing activities	6		7		—		13
Other (income) and expense	—		(1)		—		(1)
Income Tax Expense	62		38		—		100
Net Income	240		142		—		382
Less: Net Income Attributable to Noncontrolling Interests	12		—		—		12
Net Income Attributable to DT Midstream	$	228	$	142	$	—	$	370
Capital expenditures and acquisitions	$	638	$	252	$	—	$	890
	December 31, 2022
Investments in equity method investees	$	2,200	$	—	$	—	$	2,200
Goodwill	53		420		—		473
Total Assets	$	4,625	$	4,208	$	—	$	8,833

	Year Ended December 31, 2021
	Pipeline		Gathering		Eliminations		Total
	(millions)
Operating revenues	$	307	$	534	$	(1)	$	840
Operation and maintenance	59		173		(1)		231
Depreciation and amortization	63		103		—		166
Taxes other than income	13		11		—		24
Asset (gains) losses and impairments, net	—		17		—		17
Operating Income	172		230		—		402
Interest expense	51		61		—		112
Interest income	(1)		(3)		—		(4)
Earnings from equity method investees	(126)		—		—		(126)
Other (income) and expense	(3)		1		—		(2)
Income Tax Expense	62		42		—		104
Net Income	189		129		—		318
Less: Net Income Attributable to Noncontrolling Interests	11		—		—		11
Net Income Attributable to DT Midstream	$	178	$	129	$	—	$	307
Capital expenditures	$	20	$	120	$	—	$	140
	December 31, 2021
Investments in equity method investees	$	1,691	$	—	$	—	$	1,691
Goodwill	53		420		—		473
Total Assets	$	4,165	$	4,001	$	—	$	8,166

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Related Party Transactions (Tables)

12 Months Ended

Dec. 31, 2023

Related Party Transactions [Abstract]

Schedule of Transactions with Related Parties

The following is a summary of our balances with related parties:

	December 31,
	2023		2022
	(millions)
Notes receivable from Vector — long-term	$	4	$	4
Current Liabilities — Other	1		3

The following is a summary of our transactions with related parties:

	Year Ended December 31,
	2023		2022		2021
	(millions)
Revenues
Pipeline	$	—	$	—	$	5
Gathering	—		—		10
Other Costs
Interest income	—		—		(5)
Interest expense	—		—		43
Operation and maintenance and Other expense	(1)		(1)		43
Other
Notes receivable (due from) repaid by DTE Energy	—		—		263
Short-term borrowings (repayment of borrowings) from DTE Energy	—		—		(3,175)
Dividend to DTE Energy	—		—		(501)
Contributions from DTE Energy	—		—		110
Non-cash distributions to DTE Energy	—		—		(10)

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Description of the Business and Basis of Presentation - Narrative (Details)			1 Months Ended				12 Months Ended
	Jul. 01, 2021 shares	Jun. 30, 2021 shares	May 31, 2023 USD ($)	Oct. 31, 2022 USD ($)	Jun. 30, 2021 shares	Jan. 31, 2021 shares	Dec. 31, 2023 USD ($) segment $ / shares shares	Dec. 31, 2022 USD ($) $ / shares shares	Dec. 31, 2021 USD ($) $ / shares shares		Jan. 13, 2021 $ / shares	Dec. 31, 2020 shares
Related Party Transaction [Line Items]
Number of segments | segment							2
Common stock, par value (in dollars per share) | $ / shares							$ 0.01	$ 0.01	$ 0.01		$ 0.01
Common stock, shares outstanding (in shares) | shares		96,732,466			96,732,466		96,971,021	96,754,549
Common stock, shares issued (in shares) | shares		96,732,466			96,732,466		96,971,021	96,754,549
Preferred stock, shares authorized (in shares) | shares							50,000,000	50,000,000
Preferred stock, par value (in dollars per share) | $ / shares							$ 0.01	$ 0.01
Preferred stock, shares outstanding (in shares) | shares							0	0
Preferred stock, shares issued (in shares) | shares							0	0
Operation and maintenance							$ 245,000,000	$ 267,000,000	$ 231,000,000
Separation related transaction costs									20,000,000
Amount by which the share of the underlying equity in the net assets exceeds the carrying amount							352,000,000	368,000,000
Undistributed earnings from equity method investments							0	43,000,000
Payments to acquire equity method investments							$ 7,000,000	$ 5,000,000	$ 11,000,000
Common Stock
Related Party Transaction [Line Items]
Issuance of common shares (in shares) | shares						1,000			1,000	[1]
Common stock, shares outstanding (in shares) | shares							96,971,000	96,755,000	96,734,000			0
Issuance of common shares to DTE Energy (in shares) | shares		96,731,466			96,731,466
Related Party
Related Party Transaction [Line Items]
Operation and maintenance									$ 32,000,000
Related Party | Common Stock
Related Party Transaction [Line Items]
Issuance of common shares (in shares) | shares	96,732,466								96,731,000	[2]
NEXUS Senior Unsecured Notes | Senior Notes
Related Party Transaction [Line Items]
Long-term debt issued			$ 750,000,000
Interest Rate			5.52%
Proceeds from issuance of debt			$ 371,000,000
Millennium
Related Party Transaction [Line Items]
Amount by which the share of the underlying equity in the net assets exceeds the carrying amount				$ 343,000,000
Payments to acquire equity method investments				$ 552,000,000
Additional ownership interest acquired				0.2625
Ownership percentage				52.50%			52.50%	52.50%
Variable Interest Entity, Primary Beneficiary, Stonewall Gas Gathering
Related Party Transaction [Line Items]
VIE ownership percentage							85.00%
Variable Interest Entity, Primary Beneficiary, South Romeo
Related Party Transaction [Line Items]
VIE ownership percentage							50.00%

[1] Issuance of common shares at $0.01 par value upon conversion to C Corporation from a single member LLC.

[2] Issuance of common shares to DTE Energy in anticipation of the Separation.

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Description of the Business and Basis of Presentation - Consolidated VIEs (Details) - USD ($) $ in Millions	Dec. 31, 2023	Dec. 31, 2022	Dec. 31, 2021
ASSETS
Cash	$ 56	$ 61
Accounts receivable	154	161
Intangible assets, net	1,968	2,025
Property, plant and equipment, net	4,434	3,806
Goodwill	473	473	$ 473
Total Assets	8,982	8,833	$ 8,166
LIABILITIES
Other noncurrent liabilities	1,203	1,006
Total Liabilities	4,702	4,679
Variable interest entity, primary beneficiary
ASSETS
Cash	13	27
Accounts receivable	10	9
Other current assets	2	3
Intangible assets, net	483	498
Property, plant and equipment, net	391	403
Goodwill	25	25
Total Assets	924	965
LIABILITIES
Accounts payable and other current liabilities	4	4
Other noncurrent liabilities	3	4
Total Liabilities	$ 7	$ 8

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Description of the Business and Basis of Presentation - Equity Method Investees (Details) - USD ($) $ in Millions	Dec. 31, 2023	Dec. 31, 2022	Oct. 31, 2022	Dec. 31, 2021
Schedule of Equity Method Investments [Line Items]
Investments As of	$ 1,762	$ 2,200		$ 1,691
NEXUS
Schedule of Equity Method Investments [Line Items]
Investments As of	$ 900	$ 1,313
% Owned As of	50.00%	50.00%
Vector
Schedule of Equity Method Investments [Line Items]
Investments As of	$ 135	$ 135
% Owned As of	40.00%	40.00%
Millennium
Schedule of Equity Method Investments [Line Items]
Investments As of	$ 727	$ 752
% Owned As of	52.50%	52.50%	52.50%

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Description of the Business and Basis of Presentation - Summarized Balance Sheet Data (Details) - USD ($) $ in Millions	Dec. 31, 2023	Dec. 31, 2022
Schedule of Equity Method Investments [Line Items]
Current assets	$ 272	$ 262
Current liabilities	434	614
Equity method investment, non-consolidated investees
Schedule of Equity Method Investments [Line Items]
Current assets	159	198
Non-current assets	4,057	4,160
Current liabilities	208	206
Non-current liabilities	$ 1,177	$ 476

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Description of the Business and Basis of Presentation - Summarized Income Statement Data (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2023	Dec. 31, 2022	Dec. 31, 2021
Schedule of Equity Method Investments [Line Items]
Operating revenues	$ 922	$ 920	$ 840
Net Income	396	382	318
Equity method investment, non-consolidated investees
Schedule of Equity Method Investments [Line Items]
Operating revenues	823	800	738
Operating expenses	377	396	371
Net Income	$ 392	$ 372	$ 333

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Significant Accounting Policies - Narrative (Details)	3 Months Ended		12 Months Ended
	Jun. 30, 2022 USD ($)	Jun. 30, 2021 USD ($)	Dec. 31, 2023 USD ($) internal_grade	Dec. 31, 2022 USD ($)	Dec. 31, 2021 USD ($)
Financing Receivable, Past Due [Line Items]
Number of internal grades of credit quality | internal_grade			3
Asset (gains) losses and impairments, net			$ 4,000,000	$ 23,000,000	$ (17,000,000)
Proceeds from sale of notes receivable			$ 0	22,000,000	0
Specific review of probable future collections based on receivable balances, threshold duration			30 days
Uncollectible expense (recovery)			$ 0	0	0
Allowance for expected credit loss related to accounts receivable			0	0
Operation and maintenance			245,000,000	$ 267,000,000	231,000,000
Separation related transaction costs					20,000,000
Related Party
Financing Receivable, Past Due [Line Items]
Operation and maintenance					$ 32,000,000
Past due
Financing Receivable, Past Due [Line Items]
Financing receivables			0
Notes receivable
Financing Receivable, Past Due [Line Items]
Financing receivables on nonaccrual status			$ 0
Asset (gains) losses and impairments, net	$ 17,000,000	$ 19,000,000
Proceeds from sale of notes receivable	$ 22,000,000
Notes receivable | Minimum
Financing Receivable, Past Due [Line Items]
Period past due			60 days
Notes receivable | Maximum
Financing Receivable, Past Due [Line Items]
Period past due			120 days
Notes receivable | Internal grade 1 | Related Party
Financing Receivable, Past Due [Line Items]
Financing receivable originated prior to 2021			$ 4,000,000

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Significant Accounting Policies - Activity for Financing Receivables Allowance for Expected Credit Loss (Details) - Notes Receivable - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2023	Dec. 31, 2022	Dec. 31, 2021
Financing Receivable, Allowance for Credit Loss [Line Items]
Beginning balance	$ 0	$ 0	$ 0
Additions: Charged to costs, expenses, and other accounts	0	0	19
Deductions: Current period provision and write-offs charged against allowance	0	0	(19)
Ending balance	$ 0	$ 0	$ 0

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Revenue - Disaggregation of Revenue (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2023	Dec. 31, 2022	Dec. 31, 2021
Disaggregation of Revenue [Line Items]
Total operating revenues	$ 922	$ 920	$ 840
Lease revenue outside scope of Topic 606	7	10	9
Eliminations
Disaggregation of Revenue [Line Items]
Total operating revenues	0	0	(1)
Pipeline
Disaggregation of Revenue [Line Items]
Lease revenue outside scope of Topic 606	7	10	9
Pipeline | Operating segments
Disaggregation of Revenue [Line Items]
Total operating revenues	377	339	307
Gathering | Operating segments
Disaggregation of Revenue [Line Items]
Total operating revenues	$ 545	$ 581	$ 534

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Revenue - Contract Liabilities (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2023	Dec. 31, 2022
Change In Contract With Customer, Liability [Roll Forward]
Beginning balance	$ 32	$ 28
Increases due to cash received or receivable, excluding amounts recognized as revenue during the period	101	13
Revenue recognized that was included in the balance at the beginning of the period	(4)	(9)
Ending balance	$ 129	$ 32

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Revenue - Expected Recognition of Contract Liabilities (Details) $ in Millions	Dec. 31, 2023 USD ($)
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Remaining performance obligation	$ 129
Fixed-price Contract
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Remaining performance obligation	709
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2024-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Remaining performance obligation	$ 18
Remaining performance obligation, expected timing of satisfaction	1 year
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2024-01-01 | Fixed-price Contract
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Remaining performance obligation	$ 131
Remaining performance obligation, expected timing of satisfaction	1 year
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2025-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Remaining performance obligation	$ 20
Remaining performance obligation, expected timing of satisfaction	1 year
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2025-01-01 | Fixed-price Contract
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Remaining performance obligation	$ 138
Remaining performance obligation, expected timing of satisfaction	1 year
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2026-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Remaining performance obligation	$ 19
Remaining performance obligation, expected timing of satisfaction	1 year
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2026-01-01 | Fixed-price Contract
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Remaining performance obligation	$ 109
Remaining performance obligation, expected timing of satisfaction	1 year
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2027-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Remaining performance obligation	$ 18
Remaining performance obligation, expected timing of satisfaction	1 year
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2027-01-01 | Fixed-price Contract
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Remaining performance obligation	$ 77
Remaining performance obligation, expected timing of satisfaction	1 year
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2028-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Remaining performance obligation	$ 16
Remaining performance obligation, expected timing of satisfaction	1 year
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2028-01-01 | Fixed-price Contract
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Remaining performance obligation	$ 52
Remaining performance obligation, expected timing of satisfaction	1 year
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2029-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Remaining performance obligation	$ 38
Remaining performance obligation, expected timing of satisfaction
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2029-01-01 | Fixed-price Contract
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Remaining performance obligation	$ 202
Remaining performance obligation, expected timing of satisfaction

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Revenue - Expected Timing of Performance Obligation Satisfaction Related to Fixed Consideration (Details) $ in Millions	Dec. 31, 2023 USD ($)
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Remaining performance obligation	$ 129
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2024-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Remaining performance obligation	18
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2025-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Remaining performance obligation	20
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2026-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Remaining performance obligation	19
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2027-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Remaining performance obligation	18
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2028-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Remaining performance obligation	16
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2029-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Remaining performance obligation	38
Fixed-price Contract
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Remaining performance obligation	709
Fixed-price Contract | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2024-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Remaining performance obligation	131
Fixed-price Contract | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2025-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Remaining performance obligation	138
Fixed-price Contract | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2026-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Remaining performance obligation	109
Fixed-price Contract | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2027-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Remaining performance obligation	77
Fixed-price Contract | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2028-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Remaining performance obligation	52
Fixed-price Contract | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2029-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Remaining performance obligation	$ 202

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Revenue - Narrative (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2023	Dec. 31, 2022	Dec. 31, 2021
Revenue from Contract with Customer [Abstract]
Capitalized contract cost, net	$ 18	$ 19
Capitalized contract cost, amortization expense (less than)	1	1	$ 1
Production-related operating expense, recovery	$ 53	$ 65	$ 38

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Revenue - Revenue by Major Customers (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2023	Dec. 31, 2022	Dec. 31, 2021
Revenue, Major Customer [Line Items]
Operating revenues	$ 922	$ 920	$ 840
Customer A | Revenue | Customer
Revenue, Major Customer [Line Items]
Operating revenues	$ 560	$ 596	$ 563
Percentage of total	60.00%	65.00%	67.00%
Customer B | Revenue | Customer
Revenue, Major Customer [Line Items]
Operating revenues			$ 84
Percentage of total			10.00%

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Goodwill (Details) - USD ($) $ in Millions	Dec. 31, 2023	Dec. 31, 2022	Dec. 31, 2021
Goodwill [Line Items]
Goodwill	$ 473	$ 473	$ 473
Operating segments | Pipeline
Goodwill [Line Items]
Goodwill	53	53	53
Operating segments | Gathering
Goodwill [Line Items]
Goodwill	$ 420	$ 420	$ 420

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Property, Plant, and Equipment and Intangible Assets - Summary of Property, Plant and Equipment by Classification (Details) - USD ($) $ in Millions	Dec. 31, 2023	Dec. 31, 2022
Property, Plant and Equipment [Line Items]
Property, plant, and equipment	$ 5,282	$ 4,534
Accumulated depreciation	(848)	(728)
Net Property, plant, and equipment	4,434	3,806
Land and other non-depreciable assets
Property, Plant and Equipment [Line Items]
Property, plant, and equipment	96	97
Rights of way and easements
Property, Plant and Equipment [Line Items]
Property, plant, and equipment	$ 103	103
Rights of way and easements | Minimum
Property, Plant and Equipment [Line Items]
Average Estimated Useful Life	25 years
Rights of way and easements | Maximum
Property, Plant and Equipment [Line Items]
Average Estimated Useful Life	40 years
Pipelines and interconnects
Property, Plant and Equipment [Line Items]
Property, plant, and equipment	$ 3,460	2,845
Pipelines and interconnects | Minimum
Property, Plant and Equipment [Line Items]
Average Estimated Useful Life	25 years
Pipelines and interconnects | Maximum
Property, Plant and Equipment [Line Items]
Average Estimated Useful Life	40 years
Facilities and processing plants
Property, Plant and Equipment [Line Items]
Property, plant, and equipment	$ 1,234	998
Facilities and processing plants | Minimum
Property, Plant and Equipment [Line Items]
Average Estimated Useful Life	7 years
Facilities and processing plants | Maximum
Property, Plant and Equipment [Line Items]
Average Estimated Useful Life	40 years
Wells and well equipment
Property, Plant and Equipment [Line Items]
Property, plant, and equipment	$ 70	70
Wells and well equipment | Minimum
Property, Plant and Equipment [Line Items]
Average Estimated Useful Life	40 years
Wells and well equipment | Maximum
Property, Plant and Equipment [Line Items]
Average Estimated Useful Life	70 years
General plant
Property, Plant and Equipment [Line Items]
Property, plant, and equipment	$ 40	32
General plant | Minimum
Property, Plant and Equipment [Line Items]
Average Estimated Useful Life	3 years
General plant | Maximum
Property, Plant and Equipment [Line Items]
Average Estimated Useful Life	40 years
Construction in progress
Property, Plant and Equipment [Line Items]
Property, plant, and equipment	$ 279	$ 389

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Property, Plant, and Equipment and Intangible Assets - Summary of Intangible Assets (Details) - USD ($) $ in Millions	Dec. 31, 2023	Dec. 31, 2022
Finite-Lived Intangible Assets [Line Items]
Gross Carrying Value	$ 2,270	$ 2,270
Accumulated Amortization	(302)	(245)
Net Carrying Value	1,968	2,025
Customer relationships
Finite-Lived Intangible Assets [Line Items]
Gross Carrying Value	2,252	2,252
Accumulated Amortization	(289)	(233)
Net Carrying Value	1,963	2,019
Contract intangibles
Finite-Lived Intangible Assets [Line Items]
Gross Carrying Value	18	18
Accumulated Amortization	(13)	(12)
Net Carrying Value	$ 5	$ 6
Minimum | Customer relationships
Finite-Lived Intangible Assets [Line Items]
Useful Lives	25 years
Minimum | Contract intangibles
Finite-Lived Intangible Assets [Line Items]
Useful Lives	14 years
Maximum | Customer relationships
Finite-Lived Intangible Assets [Line Items]
Useful Lives	40 years
Maximum | Contract intangibles
Finite-Lived Intangible Assets [Line Items]
Useful Lives	26 years

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Property, Plant, and Equipment and Intangible Assets - Estimated Intangibles Amortization Expense (Details) $ in Millions	Dec. 31, 2023 USD ($)
Property, Plant and Equipment [Abstract]
2024	$ 57
2025	57
2026	57
2027	57
2028	$ 57

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Property, Plant, and Equipment and Intangible Assets - Depreciation and Amortization Expense by Asset Type (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2023	Dec. 31, 2022	Dec. 31, 2021
Property, Plant and Equipment [Abstract]
Property, plant, and equipment	$ 125	$ 113	$ 108
Customer relationships and other intangible assets, net	57	57	58
Depreciation and amortization	$ 182	$ 170	$ 166

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Income Taxes - Narrative (Details) - USD ($)		12 Months Ended
	Jul. 08, 2022	Dec. 31, 2023	Dec. 31, 2022	Dec. 31, 2021
Income Tax Examination [Line Items]
State rate changes		$ 18,000,000	$ 25,000,000	$ 3,000,000
Deferred tax asset related to federal net operating loss carry-forwards		184,000,000	129,000,000
State and local deferred tax assets related to net operating loss carry-forwards		102,000,000	79,000,000
Unrecognized tax benefits		0	0
State and Local Jurisdiction
Income Tax Examination [Line Items]
Net operating loss carryforward, not subject to expiration		97,000,000
Net operating loss carryforward, subject to expiration		$ 5,000,000
Pennsylvania Department of Revenue
Income Tax Examination [Line Items]
State rate changes	$ (25,000,000)		$ 25,000,000

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Income Taxes - Effective Income Tax Rate Reconciliation (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2023	Dec. 31, 2022	Dec. 31, 2021
Income Tax Disclosure [Abstract]
Income Before Income Taxes	$ 500	$ 482	$ 422
Income tax expense at statutory rate	105	101	89
State and local income taxes, net of federal benefit	18	24	17
State tax rate changes	(18)	(25)	(3)
Other, net	(1)	0	1
Income Tax Expense	$ 104	$ 100	$ 104
Effective income tax rate	20.90%	20.70%	24.70%

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Income Taxes - Components of Income Tax Expense (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2023	Dec. 31, 2022	Dec. 31, 2021
Current income tax expense
Federal	$ (4)	$ 16	$ 1
State and other income tax	(2)	14	(1)
Total current income taxes	(6)	30	0
Deferred income tax expense
Federal	109	86	85
State and other income tax	1	(16)	19
Total deferred income tax	110	70	104
Income Tax Expense	$ 104	$ 100	$ 104

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Income Taxes - Components of Deferred Tax Assets (Liabilities) (Details) - USD ($) $ in Millions	Dec. 31, 2023	Dec. 31, 2022
Deferred income tax balance components
Property, plant, and equipment	$ (369)	$ (336)
Federal net operating loss carry-forward	184	129
State and local net operating loss carry-forward, net of federal	102	79
Investment in equity method investees and partnerships	(979)	(811)
Other	31	16
Net deferred income tax asset / (liability)	(1,031)	(923)
Total deferred income tax assets and liabilities
Deferred income tax assets	319	234
Deferred income tax liabilities	(1,350)	(1,157)
Net deferred income tax asset / (liability)	$ (1,031)	$ (923)

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Earnings Per Share and Dividends - Narrative (Details) - $ / shares		1 Months Ended		12 Months Ended
	Jun. 30, 2021	Jun. 30, 2021	Jan. 31, 2021	Dec. 31, 2021		Dec. 31, 2023	Dec. 31, 2022	Jan. 13, 2021	Dec. 31, 2020
Earnings Per Share, Basic, by Common Class, Including Two Class Method [Line Items]
Common stock, par value (in dollars per share)				$ 0.01		$ 0.01	$ 0.01	$ 0.01
Common stock, shares outstanding (in shares)	96,732,466	96,732,466				96,971,021	96,754,549
Common stock, shares issued (in shares)	96,732,466	96,732,466				96,971,021	96,754,549
Common Stock
Earnings Per Share, Basic, by Common Class, Including Two Class Method [Line Items]
Issuance of common shares (in shares)			1,000	1,000	[1]
Issuance of common shares to DTE Energy (in shares)	96,731,466	96,731,466
Common stock, shares outstanding (in shares)				96,734,000		96,971,000	96,755,000		0

[1] Issuance of common shares at $0.01 par value upon conversion to C Corporation from a single member LLC.

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Earnings Per Share and Dividends - Reconciliation of Basic and Diluted Earnings Per Share Calculation (Details) - USD ($) $ / shares in Units, shares in Millions, $ in Millions	12 Months Ended
	Dec. 31, 2023	Dec. 31, 2022	Dec. 31, 2021
Basic and Diluted Earnings per Common Share
Net Income Attributable to DT Midstream	$ 384	$ 370	$ 307
Average number of common shares outstanding — basic (in shares)	96.9	96.7	96.7
Incremental shares attributable to:
Average dilutive restricted stock units and performance share awards (in shares)	0.6	0.5	0.2
Average number of common shares outstanding — diluted (in shares)	97.5	97.2	96.9
Basic earnings per common share (in dollars per share)	$ 3.97	$ 3.83	$ 3.17
Diluted earnings per common share (in dollars per share)	$ 3.94	$ 3.81	$ 3.16

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Earnings Per Share and Dividends - Dividends Declared (Details) - USD ($) $ / shares in Units, $ in Millions	3 Months Ended										12 Months Ended
	Dec. 31, 2023	Sep. 30, 2023	Jun. 30, 2023	Mar. 31, 2023	Dec. 31, 2022	Sep. 30, 2022	Jun. 30, 2022	Mar. 31, 2022	Dec. 31, 2021	Sep. 30, 2021	Dec. 31, 2023	Dec. 31, 2022	Dec. 31, 2021
Earnings Per Share [Abstract]
Quarterly Dividend (in dollars per share)	$ 0.69	$ 0.69	$ 0.69	$ 0.69	$ 0.64	$ 0.64	$ 0.64	$ 0.64	$ 0.60	$ 0.60			$ 1.20
Dividend Amount	$ 67	$ 67	$ 67	$ 67	$ 62	$ 62	$ 62	$ 62	$ 58	$ 58	$ 268	$ 248	$ 116

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Fair Value (Details) - USD ($) $ in Millions	Dec. 31, 2023	Dec. 31, 2022
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term debt principal	$ 3,099	$ 3,099
Carrying Amount
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Short-term borrowings	165	330
Long-term debt	3,065	3,059
Carrying Amount | Related Party
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term notes receivable — related party	4	4
Carrying Amount | Recurring
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Cash equivalents	36	0
Fair Value | Level 1
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Short-term borrowings	0	0
Long-term debt	0	0
Fair Value | Level 1 | Related Party
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term notes receivable — related party	0	0
Fair Value | Level 1 | Recurring
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Cash equivalents	0	0
Fair Value | Level 2
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Short-term borrowings	165	330
Long-term debt	2,850	2,701
Fair Value | Level 2 | Related Party
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term notes receivable — related party	0	0
Fair Value | Level 2 | Recurring
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Cash equivalents	36	0
Fair Value | Level 3
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Short-term borrowings	0	0
Long-term debt	0	0
Fair Value | Level 3 | Related Party
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term notes receivable — related party	4	4
Fair Value | Level 3 | Recurring
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Cash equivalents	$ 0	$ 0

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Debt - Narrative (Details)	1 Months Ended		12 Months Ended
	Oct. 31, 2022 USD ($)	Apr. 30, 2022 USD ($)	Dec. 31, 2023 USD ($)	Dec. 31, 2022 USD ($)	Dec. 31, 2021 USD ($)	Jun. 30, 2021 USD ($)
Debt Instrument [Line Items]
Issuance of long-term debt, net of discount and issuance costs			$ 0	$ 591,000,000	$ 3,047,000,000
Repayment of long-term debt			$ 0	596,000,000	$ 5,000,000
Debt amendment cost				8,000,000
Maximum consolidated net leverage ratio			3.25
Debt service coverage ratio			8.3
Consolidated net leverage ratio			2.4
Interest coverage ratio			7.8
Performance surety bonds
Debt Instrument [Line Items]
Performance bonds outstanding			$ 23,000,000
Senior Notes
Debt Instrument [Line Items]
Dividend capacity remaining			$ 356,000,000
2029 Notes | Senior Notes
Debt Instrument [Line Items]
Long-term debt issued						$ 1,100,000,000
Interest Rate			4.125%
2031 Notes | Senior Notes
Debt Instrument [Line Items]
Long-term debt issued						$ 1,000,000,000
Interest Rate			4.375%
2032 Notes | Senior Notes
Debt Instrument [Line Items]
Long-term debt issued		$ 600,000,000
Interest Rate		4.30%	4.30%
Issuance of long-term debt, net of discount and issuance costs		$ 593,000,000
Term Loan Facility
Debt Instrument [Line Items]
Repayment of long-term debt		593,000,000
Prepayment cost		$ 0
Gain (loss) on extinguishment of debt, before write off of debt issuance cost and debt discount				(9,000,000)
Write-off of unamortized discount and issuance costs				$ 4,000,000
Minimum debt service coverage ratio			1.1
Revolving Credit Facility | Revolving Credit Facility, expiring October 2027
Debt Instrument [Line Items]
Increase in commitments	$ 250,000,000
Maximum borrowing capacity	$ 1,000,000,000		$ 1,000,000,000
Fees incurred			$ 6,000,000
Maximum consolidated net leverage ratio			5
Minimum interest coverage ratio			2.5

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Debt - Schedule of Interest Expense (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2023	Dec. 31, 2022	Dec. 31, 2021
Debt Disclosure [Abstract]
Interest expense	$ 170	$ 142	$ 113
Capitalized interest	(20)	(5)	(1)
Interest expense	$ 150	$ 137	$ 112

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Debt - Long-term Debt Outstanding (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2023	Dec. 31, 2022	Apr. 30, 2022
Debt Instrument [Line Items]
Long-term debt principal	$ 3,099	$ 3,099
Unamortized debt discount	(2)	(3)
Unamortized debt issuance costs	(32)	(37)
Long-term debt, net	$ 3,065	3,059
2029 Notes | Senior Notes
Debt Instrument [Line Items]
Interest Rate	4.125%
Long-term debt principal	$ 1,100	1,100
2031 Notes | Senior Notes
Debt Instrument [Line Items]
Interest Rate	4.375%
Long-term debt principal	$ 1,000	1,000
2032 Notes | Senior Notes
Debt Instrument [Line Items]
Interest Rate	4.30%		4.30%
Long-term debt principal	$ 600	600
Term Loan Facility
Debt Instrument [Line Items]
Long-term debt principal	$ 399	$ 399
Term Loan Facility | Secured Overnight Financing Rate (SOFR) Overnight Index Swap Rate
Debt Instrument [Line Items]
Basis spread on variable rate	2.11%

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Debt - Debt Maturities (Details) - USD ($) $ in Millions	Dec. 31, 2023	Dec. 31, 2022
Debt Disclosure [Abstract]
2024	$ 0
2025	0
2026	0
2027	0
2028 and Thereafter	3,099
Total	$ 3,099	$ 3,099

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Debt - Availability Under the Revolving Credit Facility (Details) - Revolving Credit Facility, expiring October 2027 - USD ($) $ in Millions	Dec. 31, 2023	Oct. 31, 2022
Line of Credit Facility [Line Items]
Amounts outstanding	$ 181
Net availability	819
Revolving Credit Facility
Line of Credit Facility [Line Items]
Total availability	1,000	$ 1,000
Amounts outstanding	$ 165
Weighted average interest rate	6.72%
Letters of credit
Line of Credit Facility [Line Items]
Amounts outstanding	$ 16

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Leases - Narrative (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2023	Dec. 31, 2022	Dec. 31, 2021
Lessee, Lease, Description [Line Items]
Lessor, operating lease term	15 years
Fixed lease income	$ 7	$ 10	$ 9
Depreciation expense associated with property under operating lease	$ 3	$ 3	$ 3
Minimum
Lessee, Lease, Description [Line Items]
Lessee, operating lease term	3 years
Maximum
Lessee, Lease, Description [Line Items]
Lessee, operating lease term	11 years

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Leases - Components of Lease Cost (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2023	Dec. 31, 2022	Dec. 31, 2021
Leases [Abstract]
Operating lease cost	$ 20	$ 20	$ 19
Short-term lease cost	3	3	1
Lease cost	$ 23	$ 23	$ 20

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Leases - Other Relevant Information Related to Leases (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2023	Dec. 31, 2022	Dec. 31, 2021
Cash paid for amounts included in the measurement of these liabilities:
Operating cash flows for operating leases	$ 21	$ 18	$ 19
Right-of-use assets obtained in exchange for lease obligations:
Operating leases	$ 25	$ 14	$ 9
Weighted Average Remaining Lease Term
Operating leases	4 years 4 months 24 days	4 years	4 years 4 months 24 days
Weighted Average Discount Rate
Operating leases	4.80%	3.50%	2.60%

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Leases - Future Minimum Lease Payments Under Leases (Details) $ in Millions	Dec. 31, 2023 USD ($)
Leases [Abstract]
2024	$ 15
2025	9
2026	7
2027	7
2028	2
2029 and thereafter	4
Total future minimum lease payments	44
Imputed interest	(4)
Lease liabilities	$ 40

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Leases - Future Minimum Rental Revenues (Details) $ in Millions	Dec. 31, 2023 USD ($)
Leases [Abstract]
2024	$ 9
2025	9
2026	9
2027	9
2028	9
2029 and thereafter	88
Total future minimum rental revenues	$ 133

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Leases - Property Under Operating Leases (Details) - USD ($) $ in Millions	Dec. 31, 2023	Dec. 31, 2022
Leases [Abstract]
Gross property under operating leases	$ 58	$ 58
Accumulated amortization of property under operating leases	$ 15	$ 12

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Commitments and Contingencies - Purchase Commitments (Details) $ in Millions	Dec. 31, 2023 USD ($)
Commitments and Contingencies Disclosure [Abstract]
2024	$ 14
2025	13
2026	12
2027	11
2028	11
2029 and thereafter	42
Total	$ 103

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Commitments and Contingencies - Narrative (Details) $ in Millions, $ in Millions	12 Months Ended
	Dec. 31, 2023 USD ($)	Dec. 31, 2023 CAD ($)	Dec. 31, 2022 USD ($)
Loss Contingencies [Line Items]
Accrual for environmental loss contingencies, revision in estimates	$ 6
Accrued contingent liabilities	13		$ 19
Performance surety bonds
Loss Contingencies [Line Items]
Guarantee value	32
Revolving Term Credit Facility | Vector
Loss Contingencies [Line Items]
Financing receivables		$ 70
Maximum potential payout under line of credit	$ 53

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Stock-based Compensation and Defined Contribution Plans - Narrative (Details) - USD ($) $ / shares in Units, $ in Millions		12 Months Ended
	Jul. 01, 2021	Dec. 31, 2023	Dec. 31, 2022	Dec. 31, 2021
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Authorized limit of common stock (in shares)		6,500,000
Maximum annual increase for authorized common stock (in shares)		1,750,000
Unrecognized compensation cost related to non-vested stock incentive plan arrangements		$ 23.0
Unrecognized compensation cost related to non-vested stock incentive plan arrangements, period for recognition		1 year 8 months 1 day
Defined contribution plan cost		$ 7.0	$ 5.0	$ 3.0
Performance Share Awards
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Award vesting period		3 years
Weighted average grant date, fair value, excluding reinvested dividends (in usd per share)		$ 53.74	$ 72.97
Grants (in shares)		334,000		0
Settled (in shares)		(167,000)		0
Intrinsic value settled stock		$ 9.0	$ 4.0
Performance Share Awards | 2021
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Plan modification, incremental cost	$ 1.0
Restricted Stock Units
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Weighted average grant date, fair value, excluding reinvested dividends (in usd per share)		$ 52.66	$ 52.25
Intrinsic value vested stock		$ 8.0	$ 3.3	$ 0.1
Grants (in shares)		103,000		0
Restricted Stock Units | Minimum
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Award vesting period		3 years
Restricted Stock Units | Maximum
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Award vesting period		4 years

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Stock-based Compensation and Defined Contribution Plans - Stock-based Compensation Expense (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2023	Dec. 31, 2022	Dec. 31, 2021
Share-Based Payment Arrangement [Abstract]
Stock-based compensation expense	$ 20	$ 17	$ 12
Tax benefit	$ 5	$ 4	$ 3

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Stock-based Compensation and Defined Contribution Plans - Restricted Stock Unit and Performance Share Activity (Details) - USD ($) $ / shares in Units, $ in Millions	12 Months Ended
	Dec. 31, 2023	Dec. 31, 2022	Dec. 31, 2021
Weighted- Average Grant Date Fair Value
Settled (in dollars per share)	$ 34.83
Restricted Stock Units
Restricted Stock Units/Performance Shares
Beginning balance (in shares)	468,000
Grants (in shares)	103,000		0
Forfeitures (in shares)	(5,000)
Vested (in shares)	(149,000)
Ending balance (in shares)	417,000	468,000
Weighted- Average Grant Date Fair Value
Beginning balance (in dollars per share)	$ 43.28
Grants (in dollars per share)	51.28
Forfeitures (in dollars per share)	47.80
Vested and issued (in dollars per share)	41.52
Ending balance (in dollars per share)	$ 45.68	$ 43.28
Intrinsic value vested stock	$ 8.0	$ 3.3	$ 0.1
Performance Share Awards
Restricted Stock Units/Performance Shares
Beginning balance (in shares)	409,000
Grants (in shares)	334,000		0
Forfeitures (in shares)	(19,000)
Settled (in shares)	(167,000)		0
Ending balance (in shares)	557,000	409,000
Weighted- Average Grant Date Fair Value
Beginning balance (in dollars per share)	$ 56.55
Grants (in dollars per share)	59.02
Forfeitures (in dollars per share)	62.31
Ending balance (in dollars per share)	$ 64.36	$ 56.55

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Segment and Related Information - Financial Data for Business Segments (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2023	Dec. 31, 2022	Dec. 31, 2021
Segment Reporting Information [Line Items]
Operating revenues	$ 922	$ 920	$ 840
Operation and maintenance	245	267	231
Depreciation and amortization	182	170	166
Taxes other than income	28	28	24
Asset (gains) losses and impairments, net	(4)	(23)	17
Operating Income	471	478	402
Interest expense	150	137	112
Interest income	(1)	(3)	(4)
Earnings from equity method investees	(177)	(150)	(126)
Loss from financing activities	0	13	0
Other (income) and expense	(1)	(1)	(2)
Income Tax Expense	104	100	104
Net Income	396	382	318
Less: Net Income Attributable to Noncontrolling Interests	12	12	11
Net Income Attributable to DT Midstream	384	370	307
Capital expenditures	772	890	140
Investments in equity method investees	1,762	2,200	1,691
Goodwill	473	473	473
Total Assets	8,982	8,833	8,166
Operating segments | Pipeline
Segment Reporting Information [Line Items]
Operating revenues	377	339	307
Operation and maintenance	55	54	59
Depreciation and amortization	69	63	63
Taxes other than income	15	14	13
Asset (gains) losses and impairments, net	(4)	(6)	0
Operating Income	242	214	172
Interest expense	55	57	51
Interest income	(1)	(1)	(1)
Earnings from equity method investees	(177)	(150)	(126)
Loss from financing activities		6
Other (income) and expense	0	0	(3)
Income Tax Expense	75	62	62
Net Income	290	240	189
Less: Net Income Attributable to Noncontrolling Interests	12	12	11
Net Income Attributable to DT Midstream	278	228	178
Capital expenditures	255	638	20
Investments in equity method investees	1,762	2,200	1,691
Goodwill	53	53	53
Total Assets	4,439	4,625	4,165
Operating segments | Gathering
Segment Reporting Information [Line Items]
Operating revenues	545	581	534
Operation and maintenance	190	213	173
Depreciation and amortization	113	107	103
Taxes other than income	13	14	11
Asset (gains) losses and impairments, net	0	(17)	17
Operating Income	229	264	230
Interest expense	95	80	61
Interest income	0	(2)	(3)
Earnings from equity method investees	0	0	0
Loss from financing activities		7
Other (income) and expense	(1)	(1)	1
Income Tax Expense	29	38	42
Net Income	106	142	129
Less: Net Income Attributable to Noncontrolling Interests	0	0	0
Net Income Attributable to DT Midstream	106	142	129
Capital expenditures	517	252	120
Investments in equity method investees	0	0	0
Goodwill	420	420	420
Total Assets	4,543	4,208	4,001
Eliminations
Segment Reporting Information [Line Items]
Operating revenues	0	0	(1)
Operation and maintenance	0	0	(1)
Depreciation and amortization	0	0	0
Taxes other than income	0	0	0
Asset (gains) losses and impairments, net	0	0	0
Operating Income	0	0	0
Interest expense	0	0	0
Interest income	0	0	0
Earnings from equity method investees	0	0	0
Loss from financing activities		0
Other (income) and expense	0	0	0
Income Tax Expense	0	0	0
Net Income	0	0	0
Less: Net Income Attributable to Noncontrolling Interests	0	0	0
Net Income Attributable to DT Midstream	0	0	0
Capital expenditures	0	0	0
Investments in equity method investees	0	0	0
Goodwill	0	0	0
Total Assets	$ 0	$ 0	$ 0

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Related Party Transactions - Narrative (Details) - USD ($) $ in Millions		1 Months Ended		12 Months Ended
	Jul. 01, 2021	Jun. 30, 2021	Jan. 31, 2021	Dec. 31, 2021
Common Stock
Related Party Transaction [Line Items]
Issuance of common shares (in shares)			1,000	1,000	[1]
Related Party
Related Party Transaction [Line Items]
Related party interest rate				3.30%
Term of related party agreement				1 year
Repayment of term loan		$ 2,537
Net cash payment for accounts receivable due from and accounts payable due to DTE Energy		$ 9
Related Party | Common Stock
Related Party Transaction [Line Items]
Issuance of common shares (in shares)	96,732,466			96,731,000	[2]

[1] Issuance of common shares at $0.01 par value upon conversion to C Corporation from a single member LLC.

[2] Issuance of common shares to DTE Energy in anticipation of the Separation.

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Related Party Transactions - Summary of Related Party Balances (Details) - USD ($) $ in Millions	Dec. 31, 2023	Dec. 31, 2022
Related Party Transaction [Line Items]
Current Liabilities — Other	$ 1	$ 3
Related Party
Related Party Transaction [Line Items]
Notes receivable from Vector — long-term	$ 4	$ 4

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Related Party Transactions - Summary of Related Party Transactions (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2023	Dec. 31, 2022	Dec. 31, 2021
Related Party Transaction [Line Items]
Operating revenues	$ 922	$ 920	$ 840
Interest expense	150	137	112
Notes receivable repaid by DTE Energy	0	0	263
Contributions from DTE Energy	0	0	110
Related Party
Related Party Transaction [Line Items]
Interest income	0	0	(5)
Interest expense	0	0	43
Operation and maintenance and Other expense	(1)	(1)	43
Notes receivable repaid by DTE Energy	0	0	263
Repayment of borrowings from DTE Energy	0	0	(3,175)
Dividend to DTE Energy	0	0	(501)
Contributions from DTE Energy	0	0	110
Non-cash distributions to DTE Energy	0	0	(10)
Pipeline | Related Party
Related Party Transaction [Line Items]
Operating revenues	0	0	5
Gathering | Related Party
Related Party Transaction [Line Items]
Operating revenues	$ 0	$ 0	$ 10

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Subsequent Event (Details) - $ / shares		3 Months Ended										12 Months Ended
	Feb. 16, 2024	Dec. 31, 2023	Sep. 30, 2023	Jun. 30, 2023	Mar. 31, 2023	Dec. 31, 2022	Sep. 30, 2022	Jun. 30, 2022	Mar. 31, 2022	Dec. 31, 2021	Sep. 30, 2021	Dec. 31, 2021
Subsequent Event [Line Items]
Dividends declared on common stock (in dollars per share)		$ 0.69	$ 0.69	$ 0.69	$ 0.69	$ 0.64	$ 0.64	$ 0.64	$ 0.64	$ 0.60	$ 0.60	$ 1.20
Subsequent Event
Subsequent Event [Line Items]
Dividends declared on common stock (in dollars per share)	$ 0.735