EXHIBIT 99.1 DTE ENERGY SPIN OF DT MIDSTREAM J U N E 9 , 2 0 2 1EXHIBIT 99.1 DTE ENERGY SPIN OF DT MIDSTREAM J U N E 9 , 2 0 2 1

Safe harbor statement The information contained herein is as of the date of this document. DTE Energy expressly disclaims any current intention to update any forward-looking statements contained in this document as a result of new information or future events or developments. Words such as “anticipate,” “believe,” “expect,” “may,” “could,” “would,” “projected,” “aspiration,” “plans”, “target” and “goals” signify forward-looking statements. Forward-looking statements are not guarantees of future results and conditions but rather are subject to various assumptions, risks and uncertainties. This document contains forward-looking statements about DTE Energy’s and DT Midstream’s financial results and estimates of future prospects, and actual results may differ materially. This document contains forward-looking statements about DTE Energy’s intent to spin-off DT Midstream and DTE Energy’s preliminary strategic, operational and financial considerations related thereto. The statements with respect to the separation transaction are preliminary in nature and subject to change as additional information becomes available. The separation transaction will be subject to the satisfaction or waiver of a number of conditions, and there is no assurance that such separation transaction will in fact occur. Many factors impact forward-looking statements including, but not limited to, the following: risks related to the spin-off of DT Midstream, including that the process of exploring the transaction and potentially completing the transaction could disrupt or adversely affect the consolidated or separate businesses, results of operations and financial condition, that the transaction may not achieve some or all of any anticipated benefits with respect to either business, and that the transaction may not be completed in accordance with DTE Energy’s expected plans or anticipated timelines, or at all; the duration and impact of the COVID-19 pandemic on DTE Energy and customers, impact of regulation by the EPA, the EGLE, the FERC, the MPSC, the NRC, and for DTE Energy, the CFTC and CARB, as well as other applicable governmental proceedings and regulations, including any associated impact on rate structures; the amount and timing of cost recovery allowed as a result of regulatory proceedings, related appeals, or new legislation, including legislative amendments and retail access programs; economic conditions and population changes in our geographic area resulting in changes in demand, customer conservation, and thefts of electricity and, for DTE Energy, natural gas; the operational failure of electric or gas distribution systems or infrastructure; impact of volatility of prices in the oil and gas markets on DTE Energy’s gas storage and pipelines operations and the volatility in the short-term natural gas storage markets impacting third-party storage revenues related to DTE Energy; impact of volatility in prices in the international steel markets on DTE Energy’s power and industrial projects operations; the risk of a major safety incident; environmental issues, laws, regulations, and the increasing costs of remediation and compliance, including actual and potential new federal and state requirements; the cost of protecting assets against, or damage due to, cyber incidents and terrorism; health, safety, financial, environmental, and regulatory risks associated with ownership and operation of nuclear facilities; volatility in commodity markets, deviations in weather, and related risks impacting the results of DTE Energy’s energy trading operations; changes in the cost and availability of coal and other raw materials, purchased power, and natural gas; advances in technology that produce power, store power or reduce power consumption; changes in the financial condition of significant customers and strategic partners; the potential for losses on investments, including nuclear decommissioning and benefit plan assets and the related increases in future expense and contributions; access to capital markets and the results of other financing efforts which can be affected by credit agency ratings; instability in capital markets which could impact availability of short and long-term financing; the timing and extent of changes in interest rates; the level of borrowings; the potential for increased costs or delays in completion of significant capital projects; changes in, and application of, federal, state, and local tax laws and their interpretations, including the Internal Revenue Code, regulations, rulings, court proceedings, and audits; the effects of weather and other natural phenomena on operations and sales to customers, and purchases from suppliers; unplanned outages; employee relations and the impact of collective bargaining agreements; the availability, cost, coverage, and terms of insurance and stability of insurance providers; cost reduction efforts and the maximization of plant and distribution system performance; the effects of competition; changes in and application of accounting standards and financial reporting regulations; changes in federal or state laws and their interpretation with respect to regulation, energy policy, and other business issues; contract disputes, binding arbitration, litigation, and related appeals; and the risks discussed in DTE Energy’s public filings with the Securities and Exchange Commission. New factors emerge from time to time. We cannot predict what factors may arise or how such factors may cause results to differ materially from those contained in any forward-looking statement. Any forward-looking statements speak only as of the date on which such statements are made. We undertake no obligation to update any forward-looking statement to reflect events or circumstances after the date on which such statement is made or to reflect the occurrence of unanticipated events. This document should also be read in conjunction with the Forward-Looking Statements section of the joint DTE Energy and DTE Electric 2020 Form 10-K and 2021 Form 10-Q (which sections are incorporated by reference herein), and in conjunction with other SEC reports filed by DTE Energy and DTE Electric. 2Safe harbor statement The information contained herein is as of the date of this document. DTE Energy expressly disclaims any current intention to update any forward-looking statements contained in this document as a result of new information or future events or developments. Words such as “anticipate,” “believe,” “expect,” “may,” “could,” “would,” “projected,” “aspiration,” “plans”, “target” and “goals” signify forward-looking statements. Forward-looking statements are not guarantees of future results and conditions but rather are subject to various assumptions, risks and uncertainties. This document contains forward-looking statements about DTE Energy’s and DT Midstream’s financial results and estimates of future prospects, and actual results may differ materially. This document contains forward-looking statements about DTE Energy’s intent to spin-off DT Midstream and DTE Energy’s preliminary strategic, operational and financial considerations related thereto. The statements with respect to the separation transaction are preliminary in nature and subject to change as additional information becomes available. The separation transaction will be subject to the satisfaction or waiver of a number of conditions, and there is no assurance that such separation transaction will in fact occur. Many factors impact forward-looking statements including, but not limited to, the following: risks related to the spin-off of DT Midstream, including that the process of exploring the transaction and potentially completing the transaction could disrupt or adversely affect the consolidated or separate businesses, results of operations and financial condition, that the transaction may not achieve some or all of any anticipated benefits with respect to either business, and that the transaction may not be completed in accordance with DTE Energy’s expected plans or anticipated timelines, or at all; the duration and impact of the COVID-19 pandemic on DTE Energy and customers, impact of regulation by the EPA, the EGLE, the FERC, the MPSC, the NRC, and for DTE Energy, the CFTC and CARB, as well as other applicable governmental proceedings and regulations, including any associated impact on rate structures; the amount and timing of cost recovery allowed as a result of regulatory proceedings, related appeals, or new legislation, including legislative amendments and retail access programs; economic conditions and population changes in our geographic area resulting in changes in demand, customer conservation, and thefts of electricity and, for DTE Energy, natural gas; the operational failure of electric or gas distribution systems or infrastructure; impact of volatility of prices in the oil and gas markets on DTE Energy’s gas storage and pipelines operations and the volatility in the short-term natural gas storage markets impacting third-party storage revenues related to DTE Energy; impact of volatility in prices in the international steel markets on DTE Energy’s power and industrial projects operations; the risk of a major safety incident; environmental issues, laws, regulations, and the increasing costs of remediation and compliance, including actual and potential new federal and state requirements; the cost of protecting assets against, or damage due to, cyber incidents and terrorism; health, safety, financial, environmental, and regulatory risks associated with ownership and operation of nuclear facilities; volatility in commodity markets, deviations in weather, and related risks impacting the results of DTE Energy’s energy trading operations; changes in the cost and availability of coal and other raw materials, purchased power, and natural gas; advances in technology that produce power, store power or reduce power consumption; changes in the financial condition of significant customers and strategic partners; the potential for losses on investments, including nuclear decommissioning and benefit plan assets and the related increases in future expense and contributions; access to capital markets and the results of other financing efforts which can be affected by credit agency ratings; instability in capital markets which could impact availability of short and long-term financing; the timing and extent of changes in interest rates; the level of borrowings; the potential for increased costs or delays in completion of significant capital projects; changes in, and application of, federal, state, and local tax laws and their interpretations, including the Internal Revenue Code, regulations, rulings, court proceedings, and audits; the effects of weather and other natural phenomena on operations and sales to customers, and purchases from suppliers; unplanned outages; employee relations and the impact of collective bargaining agreements; the availability, cost, coverage, and terms of insurance and stability of insurance providers; cost reduction efforts and the maximization of plant and distribution system performance; the effects of competition; changes in and application of accounting standards and financial reporting regulations; changes in federal or state laws and their interpretation with respect to regulation, energy policy, and other business issues; contract disputes, binding arbitration, litigation, and related appeals; and the risks discussed in DTE Energy’s public filings with the Securities and Exchange Commission. New factors emerge from time to time. We cannot predict what factors may arise or how such factors may cause results to differ materially from those contained in any forward-looking statement. Any forward-looking statements speak only as of the date on which such statements are made. We undertake no obligation to update any forward-looking statement to reflect events or circumstances after the date on which such statement is made or to reflect the occurrence of unanticipated events. This document should also be read in conjunction with the Forward-Looking Statements section of the joint DTE Energy and DTE Electric 2020 Form 10-K and 2021 Form 10-Q (which sections are incorporated by reference herein), and in conjunction with other SEC reports filed by DTE Energy and DTE Electric. 2

Introduction DTE Energy DT Midstream Appendix 3Introduction DTE Energy DT Midstream Appendix 3

Strong strategic rationale for the separation of DTE and DTM Positions DTE as a high-growth, Positions DTM as a premier midstream C-Corp, predominantly pure-play, best-in-class with high-quality assets located in premium regulated Michigan based utility basins connected to major demand markets NYSE: DTE NYSE: DTM Creating two premier independent energy companies positioned for further growth and value for shareholders 4Strong strategic rationale for the separation of DTE and DTM Positions DTE as a high-growth, Positions DTM as a premier midstream C-Corp, predominantly pure-play, best-in-class with high-quality assets located in premium regulated Michigan based utility basins connected to major demand markets NYSE: DTE NYSE: DTM Creating two premier independent energy companies positioned for further growth and value for shareholders 4

Spin generates a combined dividend that is expected to be higher than DTE’s current, pre-transaction dividend ($ per share) Annualized dividend 3 ~$4.70 - $4.80 • Increased annualized dividend per share every year since 1 2010 $4.34 2x coverage 2 ratio floor • Spin generates a combined dividend that is expected to be higher than DTE’s forecasted, pre-transaction dividend − Expect 8% - 10% post-spin dividend increase from 2021 60% to 2022 versus planned 6% pre-spin payout $2.12 ratio − DTE will target a payout ratio of 60%, consistent with best-performing pure-play utilities, equivalent 2 to a 2021 annualized dividend of $3.30 DT Midstream DTE Energy − DTM plans to establish a growing dividend, targeting a 2 2x dividend coverage ratio floor that is competitive with midstream peers 2009 2021 2022E pre-spin More than 100 consecutive years of dividend payments 1. Annualized dividend is the current consolidated pre-spin version of DTE; the spin is currently expected to occur mid-year 2021 and any post-spin guidance is subject to final Board approval and will be provided later in the process 2. Subject to final Board approval 5 3. Reasonable proxy for combined annualized dividend - calculated using current disclosures; additional disclosures are expected to occur mid-year 2021 and any post-spin dividend guidance is subject to final Board approval and will be provided later in the processSpin generates a combined dividend that is expected to be higher than DTE’s current, pre-transaction dividend ($ per share) Annualized dividend 3 ~$4.70 - $4.80 • Increased annualized dividend per share every year since 1 2010 $4.34 2x coverage 2 ratio floor • Spin generates a combined dividend that is expected to be higher than DTE’s forecasted, pre-transaction dividend − Expect 8% - 10% post-spin dividend increase from 2021 60% to 2022 versus planned 6% pre-spin payout $2.12 ratio − DTE will target a payout ratio of 60%, consistent with best-performing pure-play utilities, equivalent 2 to a 2021 annualized dividend of $3.30 DT Midstream DTE Energy − DTM plans to establish a growing dividend, targeting a 2 2x dividend coverage ratio floor that is competitive with midstream peers 2009 2021 2022E pre-spin More than 100 consecutive years of dividend payments 1. Annualized dividend is the current consolidated pre-spin version of DTE; the spin is currently expected to occur mid-year 2021 and any post-spin guidance is subject to final Board approval and will be provided later in the process 2. Subject to final Board approval 5 3. Reasonable proxy for combined annualized dividend - calculated using current disclosures; additional disclosures are expected to occur mid-year 2021 and any post-spin dividend guidance is subject to final Board approval and will be provided later in the process

Introduction DTE Energy DT Midstream Appendix 6Introduction DTE Energy DT Midstream Appendix 6

DTE will be a predominantly pure-play utility upon spin execution DTE Electric DTE Gas ✓ 2.2 million customers✓ 1.3 million customers th ✓ Largest electric utility in Michigan✓ Nation’s 7 largest natural gas utility Non-utility ✓ Leading developer of energy-related projects including RNG and cogeneration Post-transaction Post-transaction 1 operating earnings 5-year capital investment plan 76% 70% Electric utility 90% 92% Gas utility utility utility Non-utility 20% 16% 10% 8% 1. Reconciliation of operating earnings (non-GAAP) to reported earnings included in the appendix 7DTE will be a predominantly pure-play utility upon spin execution DTE Electric DTE Gas ✓ 2.2 million customers✓ 1.3 million customers th ✓ Largest electric utility in Michigan✓ Nation’s 7 largest natural gas utility Non-utility ✓ Leading developer of energy-related projects including RNG and cogeneration Post-transaction Post-transaction 1 operating earnings 5-year capital investment plan 76% 70% Electric utility 90% 92% Gas utility utility utility Non-utility 20% 16% 10% 8% 1. Reconciliation of operating earnings (non-GAAP) to reported earnings included in the appendix 7

1 Maintaining long-term operating EPS growth of 5% - 7% (millions, except EPS) • 7.4% operating EPS growth (excluding DTM) from 2020 original 3 DTE annualized operating EPS guidance midpoint to 2021 guidance midpoint excluding Midstream • Continuing 5% - 7% long-term operating EPS growth through significant milestones − Generating 90% of future operating earnings from regulated utilities − Delivering higher than targeted 5-year average utility operating earnings growth in early years of plan − Converting $1.3 billion of mandatory equity in 2022 $5.51 − Sunsetting REF business after 2021 $5.13 2 2021 DTE guidance 2021 DTE guidance – continuing operations DTE Electric $826 - $840 DTE Gas 202 - 212 Power & Industrial Projects 147 - 163 2020 2021 2022E 2023E 2024E 2025E Energy Trading 15 - 25 original guidance guidance midpoint Corporate & Other (148) - (138) midpoint DTE Energy $1,042 - $1,102 Operating EPS $5.36 - $5.66 1. Reconciliation of operating earnings (non-GAAP) to reported earnings included in the appendix 2. Following the spin, January – June results for Midstream will be moved to discontinued operations beginning in 3Q 8 3. Reasonable proxy for DTE operating EPS excluding Midstream1 Maintaining long-term operating EPS growth of 5% - 7% (millions, except EPS) • 7.4% operating EPS growth (excluding DTM) from 2020 original 3 DTE annualized operating EPS guidance midpoint to 2021 guidance midpoint excluding Midstream • Continuing 5% - 7% long-term operating EPS growth through significant milestones − Generating 90% of future operating earnings from regulated utilities − Delivering higher than targeted 5-year average utility operating earnings growth in early years of plan − Converting $1.3 billion of mandatory equity in 2022 $5.51 − Sunsetting REF business after 2021 $5.13 2 2021 DTE guidance 2021 DTE guidance – continuing operations DTE Electric $826 - $840 DTE Gas 202 - 212 Power & Industrial Projects 147 - 163 2020 2021 2022E 2023E 2024E 2025E Energy Trading 15 - 25 original guidance guidance midpoint Corporate & Other (148) - (138) midpoint DTE Energy $1,042 - $1,102 Operating EPS $5.36 - $5.66 1. Reconciliation of operating earnings (non-GAAP) to reported earnings included in the appendix 2. Following the spin, January – June results for Midstream will be moved to discontinued operations beginning in 3Q 8 3. Reasonable proxy for DTE operating EPS excluding Midstream

Introduction DTE Energy DT Midstream Appendix 9Introduction DTE Energy DT Midstream Appendix 9

Spin is on track Achieved progress to date ✓ Board of Directors nominated ✓ SEC Form 10 effective ✓ Successful debt raise Upcoming milestones on track ❑ Virtual equity road show June 9 - 28 ❑ When-issued trading expected to begin on or about June 17 ❑ Record date for distribution of DTM shares on June 18 ❑ Distribution date for DTM shares expected July 1 10Spin is on track Achieved progress to date ✓ Board of Directors nominated ✓ SEC Form 10 effective ✓ Successful debt raise Upcoming milestones on track ❑ Virtual equity road show June 9 - 28 ❑ When-issued trading expected to begin on or about June 17 ❑ Record date for distribution of DTM shares on June 18 ❑ Distribution date for DTM shares expected July 1 10

Investment thesis • Positioned to capitalize on growing natural gas production volumes in the Marcellus / Utica and Haynesville, which are expected to produce a majority of U.S. gas by 2035 Integrated assets in premier dry gas basins serving key markets • Fully integrated platforms providing services from wellhead to key demand markets across the Gulf Coast, East Coast, Midwest and Eastern Canada • $3.1 billion of long-term debt with no significant debt maturities for seven years; additional $750 million committed revolver Stable balance sheet with low • Strong cash flow will be used for accretive growth investments and / or to de-lever the balance leverage sheet 1 • Targeting a long-term leverage ratio of under 4x and dividend distribution coverage of over 2x • Cash flow supported by diversified long-term, demand-based contracts with firm commitments; Predictable, robust contracted 2 over 90% of 2020 contribution from MVC / demand charges (take-or-pay) and flowing gas cash flows • Weighted average contract tenor of approximately nine years • Focused on environmental stewardship and maintaining a diverse and safe environment for our employees, customers and communities Mature environmental, social • Established ESG culture in place from our 20-year history as part of DTE Energy and governance leadership • Well positioned to benefit from energy transition; one of the first in the midstream sector to commit to net zero greenhouse gas emissions by 2050 1. Subject to DTM Board approval. The dividend coverage ratio represents the total distributable cash flow (“DCF”) divided by total dividends paid to investors. Definition of DCF (non-GAAP) included in the appendix 11 2. Reflects non-GAAP financial metric based on total contribution of company assets including proportionate interest in joint venturesInvestment thesis • Positioned to capitalize on growing natural gas production volumes in the Marcellus / Utica and Haynesville, which are expected to produce a majority of U.S. gas by 2035 Integrated assets in premier dry gas basins serving key markets • Fully integrated platforms providing services from wellhead to key demand markets across the Gulf Coast, East Coast, Midwest and Eastern Canada • $3.1 billion of long-term debt with no significant debt maturities for seven years; additional $750 million committed revolver Stable balance sheet with low • Strong cash flow will be used for accretive growth investments and / or to de-lever the balance leverage sheet 1 • Targeting a long-term leverage ratio of under 4x and dividend distribution coverage of over 2x • Cash flow supported by diversified long-term, demand-based contracts with firm commitments; Predictable, robust contracted 2 over 90% of 2020 contribution from MVC / demand charges (take-or-pay) and flowing gas cash flows • Weighted average contract tenor of approximately nine years • Focused on environmental stewardship and maintaining a diverse and safe environment for our employees, customers and communities Mature environmental, social • Established ESG culture in place from our 20-year history as part of DTE Energy and governance leadership • Well positioned to benefit from energy transition; one of the first in the midstream sector to commit to net zero greenhouse gas emissions by 2050 1. Subject to DTM Board approval. The dividend coverage ratio represents the total distributable cash flow (“DCF”) divided by total dividends paid to investors. Definition of DCF (non-GAAP) included in the appendix 11 2. Reflects non-GAAP financial metric based on total contribution of company assets including proportionate interest in joint ventures

Dry gas-focused independent midstream C-Corp with a diverse portfolio of pipeline and gathering assets 1 Q1 2021 adjusted EBITDA Pipeline and Other 52% Gathering DT Midstream, Inc. 48% Pipeline and Other Gathering Unconsolidated JV Consolidated pipelines Storage pipelines Appalachia NEXUS - 50% Bluestone Lateral Blue Union Vector - 40% LEAP Lateral Washington 10 Storage Michigan Gathering Complex - 91% Millennium - 26% Birdsboro Susquehanna Generation - 50% Stonewall Lateral - 85% Tioga 1. Definition of adjusted EBITDA (non-GAAP) included in the appendix 12Dry gas-focused independent midstream C-Corp with a diverse portfolio of pipeline and gathering assets 1 Q1 2021 adjusted EBITDA Pipeline and Other 52% Gathering DT Midstream, Inc. 48% Pipeline and Other Gathering Unconsolidated JV Consolidated pipelines Storage pipelines Appalachia NEXUS - 50% Bluestone Lateral Blue Union Vector - 40% LEAP Lateral Washington 10 Storage Michigan Gathering Complex - 91% Millennium - 26% Birdsboro Susquehanna Generation - 50% Stonewall Lateral - 85% Tioga 1. Definition of adjusted EBITDA (non-GAAP) included in the appendix 12

Experienced management team with a proven track record of success Robert Skaggs, Jr. David Slater Christopher Zona Executive Chairman President and CEO COO Over 28 years of experience in the energy Over 35 years of experience in the energy Over 30 years of experience in the energy industry; independent director on DTE board industry; joined DTE in 2011; prior to DTE, industry, working in operational, engineering, since 2017; prior to DTE, President and CEO held various senior management positions at construction and business development roles of NiSource from 2005 to 2015; executed the Goldman Sachs, Nexen Marketing, Engage spin of Columbia Pipeline in mid-2015 Energy and Union Gas Jeffrey Jewell Wendy Ellis Richard Redmond CFO General Counsel and Corporate Secretary CAO Over 25 years of experience in the energy Over 25 years of experience in the energy Over 40 years of experience in the energy industry, working in financial, accounting and industry, serving in various legal and general industry, working in natural gas exploration, risk management roles counsel capacities production, gathering and processing 13Experienced management team with a proven track record of success Robert Skaggs, Jr. David Slater Christopher Zona Executive Chairman President and CEO COO Over 28 years of experience in the energy Over 35 years of experience in the energy Over 30 years of experience in the energy industry; independent director on DTE board industry; joined DTE in 2011; prior to DTE, industry, working in operational, engineering, since 2017; prior to DTE, President and CEO held various senior management positions at construction and business development roles of NiSource from 2005 to 2015; executed the Goldman Sachs, Nexen Marketing, Engage spin of Columbia Pipeline in mid-2015 Energy and Union Gas Jeffrey Jewell Wendy Ellis Richard Redmond CFO General Counsel and Corporate Secretary CAO Over 25 years of experience in the energy Over 25 years of experience in the energy Over 40 years of experience in the energy industry, working in financial, accounting and industry, serving in various legal and general industry, working in natural gas exploration, risk management roles counsel capacities production, gathering and processing 13

Leading the industry with a mature environmental, social and governance program Environmental Social Governance • Targeting net zero greenhouse gas • Focusing on the safety, diversity, well- • Focusing on the oversight of emissions by 2050; among the first in being and success of our employees environmental sustainability, social the midstream sector to establish and governance practices such a goal • Serving our local communities through volunteering, foundation • Structuring as C-Corp with separate contributions and revitalizing Executive Chairman and CEO • Among the first U.S. companies to neighborhoods; ~$1.5 million in report methane intensity data as part of the Natural Gas Sustainability charitable contributions in 2019 / • Independent and diverse board Initiative (NGSI) 2020 • Providing incentive plans tied to • Delivering clean and reliable energy • Achieved top decile performance in safety and total shareholder return to customers and their communities the National Safety Council Safety Barometer Survey since 2015 14Leading the industry with a mature environmental, social and governance program Environmental Social Governance • Targeting net zero greenhouse gas • Focusing on the safety, diversity, well- • Focusing on the oversight of emissions by 2050; among the first in being and success of our employees environmental sustainability, social the midstream sector to establish and governance practices such a goal • Serving our local communities through volunteering, foundation • Structuring as C-Corp with separate contributions and revitalizing Executive Chairman and CEO • Among the first U.S. companies to neighborhoods; ~$1.5 million in report methane intensity data as part of the Natural Gas Sustainability charitable contributions in 2019 / • Independent and diverse board Initiative (NGSI) 2020 • Providing incentive plans tied to • Delivering clean and reliable energy • Achieved top decile performance in safety and total shareholder return to customers and their communities the National Safety Council Safety Barometer Survey since 2015 14

Fully integrated platform transporting production from leading low-cost dry gas formations to growing demand markets Pipeline and Other connect world-class basins to high-quality Eastern Canada Northeast markets • 900 miles of FERC-regulated interstate pipelines that have interconnections with multiple interstate pipelines and LDCs • Gas storage assets with 94 Bcf of capacity Marcellus / • 290 miles of lateral pipelines Midwest Utica • Modern pipeline assets requiring limited maintenance capital Mid-Atlantic & Gathering serves the fastest growing dry-gas basins in North LNG America Haynesville • Dry gas gathering assets serving growing gas production in the Southeast premier, low-cost production areas of the Marcellus / Utica and Haynesville • Over 1,000 miles of pipe, 113 compressor units with 234,000 Gulf Coast horsepower and 4.3 Bcf of dehydration and treating capacity 15Fully integrated platform transporting production from leading low-cost dry gas formations to growing demand markets Pipeline and Other connect world-class basins to high-quality Eastern Canada Northeast markets • 900 miles of FERC-regulated interstate pipelines that have interconnections with multiple interstate pipelines and LDCs • Gas storage assets with 94 Bcf of capacity Marcellus / • 290 miles of lateral pipelines Midwest Utica • Modern pipeline assets requiring limited maintenance capital Mid-Atlantic & Gathering serves the fastest growing dry-gas basins in North LNG America Haynesville • Dry gas gathering assets serving growing gas production in the Southeast premier, low-cost production areas of the Marcellus / Utica and Haynesville • Over 1,000 miles of pipe, 113 compressor units with 234,000 Gulf Coast horsepower and 4.3 Bcf of dehydration and treating capacity 15

Diversified asset base providing critical infrastructure and fully integrated wellhead to end market service 6% 7% 52% 40% 29% Q1 2021 adjusted Q1 2021 adjusted Q1 2021 adjusted 36% 1 EBITDA by segment EBITDA by demand area EBITDA by supply area 65% 48% 17% Pipeline and Other Gathering Gulf Coast Midwest Marcellus / Utica Haynesville Northeast & Mid-Atlantic Eastern Canada Michigan Operations 1. Definition of adjusted EBITDA (non-GAAP) included in the appendix 16 Note: Reflects non-GAAP financial metric based on total contribution of company assets including proportionate interest in joint venturesDiversified asset base providing critical infrastructure and fully integrated wellhead to end market service 6% 7% 52% 40% 29% Q1 2021 adjusted Q1 2021 adjusted Q1 2021 adjusted 36% 1 EBITDA by segment EBITDA by demand area EBITDA by supply area 65% 48% 17% Pipeline and Other Gathering Gulf Coast Midwest Marcellus / Utica Haynesville Northeast & Mid-Atlantic Eastern Canada Michigan Operations 1. Definition of adjusted EBITDA (non-GAAP) included in the appendix 16 Note: Reflects non-GAAP financial metric based on total contribution of company assets including proportionate interest in joint ventures

Supported by highly stable cash flows backed by long-term fee-based contracts Strong cash flow support Underpinned by long-term, fee-based contracts with average life of approximately % MVC / demand ~90% ~90% 2 nine years or flowing gas 1 • ~90% of total contribution is from MVCs / demand charges (take-or-pay) and currently flowing gas Contract credit • Significant credit provisions which are provisions durable to change of control events • Majority of producers flowing at or above Average contract ~9 ~10 MVC levels tenor (years) Pipeline and Other Gathering 1. Reflects non-GAAP financial metric based on total 2020 contribution of company assets including proportionate interest in joint ventures 17 2. Flowing gas represents proved developed producing reserves (PDPs) Supported by highly stable cash flows backed by long-term fee-based contracts Strong cash flow support Underpinned by long-term, fee-based contracts with average life of approximately % MVC / demand ~90% ~90% 2 nine years or flowing gas 1 • ~90% of total contribution is from MVCs / demand charges (take-or-pay) and currently flowing gas Contract credit • Significant credit provisions which are provisions durable to change of control events • Majority of producers flowing at or above Average contract ~9 ~10 MVC levels tenor (years) Pipeline and Other Gathering 1. Reflects non-GAAP financial metric based on total 2020 contribution of company assets including proportionate interest in joint ventures 17 2. Flowing gas represents proved developed producing reserves (PDPs)

Long history and strong working relationship with key customers Solid and improving credit profile 1 • Mix of demand pull and supply push customers across our assets Top 10 customers • Utility and pipeline customers provide strong demand pull • Financial health of producers continues to improve • Producers have offtake agreements to strong and growing markets which provides them durable cash flows Strong commercial structures DTM op 10 customers • Contractual credit enhancements applicable to non-investment grade counterparties • Durable acreage dedications in high-quality resource areas Actively managing credit position • Regular meetings with customers • Forecasting of customer cash flows and liquidity positions 18 1. Based on 2020 total contribution of company assets including proportionate interest in joint venturesLong history and strong working relationship with key customers Solid and improving credit profile 1 • Mix of demand pull and supply push customers across our assets Top 10 customers • Utility and pipeline customers provide strong demand pull • Financial health of producers continues to improve • Producers have offtake agreements to strong and growing markets which provides them durable cash flows Strong commercial structures DTM op 10 customers • Contractual credit enhancements applicable to non-investment grade counterparties • Durable acreage dedications in high-quality resource areas Actively managing credit position • Regular meetings with customers • Forecasting of customer cash flows and liquidity positions 18 1. Based on 2020 total contribution of company assets including proportionate interest in joint ventures

Visibility into highly accretive growth projects Platforms Growth Phase Growth opportunities Blue Union Gathering Early Gathering build-outs Tioga Gathering Early Gathering build-outs Appalachia Gathering Early / Mid Gathering build-outs Gathering Michigan Gathering Advanced Service conversions Susquehanna Gathering Advanced Gathering build-outs / compression NEXUS Pipeline Early Compression / market connections Generation Pipeline Early Compression / market connections LEAP Lateral Early Compression / market connections Stonewall Lateral Early / Mid Compression / market connections Pipeline and Other Bluestone Lateral Advanced Market connections Vector Pipeline Advanced Compression / bi-directional service / market connections Millennium Pipeline Advanced Compression / bi-directional service / market connections Washington 10 Storage Advanced Compression 19Visibility into highly accretive growth projects Platforms Growth Phase Growth opportunities Blue Union Gathering Early Gathering build-outs Tioga Gathering Early Gathering build-outs Appalachia Gathering Early / Mid Gathering build-outs Gathering Michigan Gathering Advanced Service conversions Susquehanna Gathering Advanced Gathering build-outs / compression NEXUS Pipeline Early Compression / market connections Generation Pipeline Early Compression / market connections LEAP Lateral Early Compression / market connections Stonewall Lateral Early / Mid Compression / market connections Pipeline and Other Bluestone Lateral Advanced Market connections Vector Pipeline Advanced Compression / bi-directional service / market connections Millennium Pipeline Advanced Compression / bi-directional service / market connections Washington 10 Storage Advanced Compression 19

Consistent track record of successful organic development and acquisitions underpinned by premium financial returns 1 Historical adjusted EBITDA growth $710 (millions) $82 2008 2009 2010 2011 2012 2013 2014 2015 2016 2017 2018 2019 2020 Asset growth timeline ✓ Washington 10 expansion✓ Bluestone lateral and gathering system in-✓ NEXUS Pipeline service ✓ Millennium Pipeline in-service✓ Birdsboro Pipeline ✓ Bluestone expansions ✓ Vector phase 2 expansion✓ Millennium valley lateral and eastern system ✓ Appalachia Gathering System (AGS) and upgrade Stonewall Gas Gathering System acquisition ✓ Generation Pipeline acquisition ✓ AGS expansions ✓ Blue Union acquisition ✓ LEAP Pipeline in-service 20 1. Definition of adjusted EBITDA (non-GAAP) included in the appendix✓ Vector Bluewater Energy Center PipelineConsistent track record of successful organic development and acquisitions underpinned by premium financial returns 1 Historical adjusted EBITDA growth $710 (millions) $82 2008 2009 2010 2011 2012 2013 2014 2015 2016 2017 2018 2019 2020 Asset growth timeline ✓ Washington 10 expansion✓ Bluestone lateral and gathering system in-✓ NEXUS Pipeline service ✓ Millennium Pipeline in-service✓ Birdsboro Pipeline ✓ Bluestone expansions ✓ Vector phase 2 expansion✓ Millennium valley lateral and eastern system ✓ Appalachia Gathering System (AGS) and upgrade Stonewall Gas Gathering System acquisition ✓ Generation Pipeline acquisition ✓ AGS expansions ✓ Blue Union acquisition ✓ LEAP Pipeline in-service 20 1. Definition of adjusted EBITDA (non-GAAP) included in the appendix✓ Vector Bluewater Energy Center Pipeline

Asset portfolio supported by long-term contracts leads to consistent growth Positioned for continued success with strong growth outlooks for 1 2 Adjusted EBITDA , operating earnings and EPS 2021 and 2022 (millions, except EPS) • Consistent with historical performance; on track to achieve 2021 ~7% adjusted EBITDA of $710 - $750 million, operating earnings guidance of $296 - $312 million and operating EPS guidance of $710 - $750 $3.06 - $3.22 $665 - $703 – Strong operational performance offsetting half-year of new public company expenses and interest costs of ~$20 million – For every two shares of DTE held there will be one share of DTM distributed; share count is expected to be ~97 million shares • Early outlook for 2022 adjusted EBITDA shows 5% - 7% growth from 2021 $296 - $312 $277 - $293 – Strong operational growth offsetting full-year public company expenses and interest costs 2020 2021 2022 • 2022 operating earnings are consistent with 2021, driven by strong original guidance guidance early outlook operational growth offsetting full-year of interest and public company Adjusted EBITDA Operating earnings expenses – Going forward, operating earnings will grow in line with 2021 Operating EPS $3.06 - $3.22 adjusted EBITDA 1. Definition of adjusted EBITDA (non-GAAP) included in the appendix 21 2. Reconciliation of operating earnings and operating earnings per share (non-GAAP) to reported earnings included in the appendix; EPS calculation based on average share count of 96.9 million shares outstandingAsset portfolio supported by long-term contracts leads to consistent growth Positioned for continued success with strong growth outlooks for 1 2 Adjusted EBITDA , operating earnings and EPS 2021 and 2022 (millions, except EPS) • Consistent with historical performance; on track to achieve 2021 ~7% adjusted EBITDA of $710 - $750 million, operating earnings guidance of $296 - $312 million and operating EPS guidance of $710 - $750 $3.06 - $3.22 $665 - $703 – Strong operational performance offsetting half-year of new public company expenses and interest costs of ~$20 million – For every two shares of DTE held there will be one share of DTM distributed; share count is expected to be ~97 million shares • Early outlook for 2022 adjusted EBITDA shows 5% - 7% growth from 2021 $296 - $312 $277 - $293 – Strong operational growth offsetting full-year public company expenses and interest costs 2020 2021 2022 • 2022 operating earnings are consistent with 2021, driven by strong original guidance guidance early outlook operational growth offsetting full-year of interest and public company Adjusted EBITDA Operating earnings expenses – Going forward, operating earnings will grow in line with 2021 Operating EPS $3.06 - $3.22 adjusted EBITDA 1. Definition of adjusted EBITDA (non-GAAP) included in the appendix 21 2. Reconciliation of operating earnings and operating earnings per share (non-GAAP) to reported earnings included in the appendix; EPS calculation based on average share count of 96.9 million shares outstanding

Financial strength is supported by strong balance sheet with no significant debt maturities for seven years 1 Debt maturity profile (billions) $1.4 $1.2 Maintaining flexible, well-capitalized balance sheet $1.1 $1.0 $1.0 $1.0 • No significant debt maturities for seven years from initial debt offering $0.8 • No external financing expected over the 5-year plan $0.6 • Strong interest in inaugural debt offering with both $0.4 term loan and senior notes being 4x over subscribed No significant maturities for 7 years leading to favorable pricing $0.2 – $1.0 billion term loan B $0.0 – $1.1 billion senior notes due 2029 2021 2022 2023 2024 2025 2026 2027 2028 2029 2030 2031 – $1.0 billion senior notes due 2031 Issuer ratings • $750 million committed revolver Capital instruments S&P Moody's Fitch 2 • Targeting a ceiling of ~4x debt / adjusted EBITDA Senior secured BBB- Baa2 BBB- 3 • Opening net debt / capitalization of ~42% Senior unsecured BB+ Ba2 BB+ 1. Term Loan B includes $10 million per year of amortization until maturity 22 2. Definition of adjusted EBITDA (non-GAAP) included in the appendix 3. Reflects Q1 2021 equity book value of $4,304 millionFinancial strength is supported by strong balance sheet with no significant debt maturities for seven years 1 Debt maturity profile (billions) $1.4 $1.2 Maintaining flexible, well-capitalized balance sheet $1.1 $1.0 $1.0 $1.0 • No significant debt maturities for seven years from initial debt offering $0.8 • No external financing expected over the 5-year plan $0.6 • Strong interest in inaugural debt offering with both $0.4 term loan and senior notes being 4x over subscribed No significant maturities for 7 years leading to favorable pricing $0.2 – $1.0 billion term loan B $0.0 – $1.1 billion senior notes due 2029 2021 2022 2023 2024 2025 2026 2027 2028 2029 2030 2031 – $1.0 billion senior notes due 2031 Issuer ratings • $750 million committed revolver Capital instruments S&P Moody's Fitch 2 • Targeting a ceiling of ~4x debt / adjusted EBITDA Senior secured BBB- Baa2 BBB- 3 • Opening net debt / capitalization of ~42% Senior unsecured BB+ Ba2 BB+ 1. Term Loan B includes $10 million per year of amortization until maturity 22 2. Definition of adjusted EBITDA (non-GAAP) included in the appendix 3. Reflects Q1 2021 equity book value of $4,304 million

Strong cash flow generation provides significant financial flexibility 1 Annualized proforma 2021 distributable cash flow (millions) $710 - $750 $500 - $550 $275 - $325 2 Adjusted EBITDA Interest Payments Maintenance Capital Other Distributable Cash Flow Dividend Value creation Considerations for 2022 and beyond optionality • Cash Interest • Modern assets • Includes cash • Targeting a 2x • Investment in expense expected to have taxes and a dividend coverage accretive growth 3 associated with low maintenance portion of ratio floor projects; $1.2 - $1.7 long-term capital capital needs unconsolidated • Targeting dividend billion through 5-year structure joint venture • Gathering yield comparable period contribution to • Additional contracts to midstream peers • Deleveraging adjusted EBITDA external capital structured to limit and dividend is balance sheet that is non-cash not expected capital obligations expected to grow in • Returning capital to given investment • Expected to be a line with financial shareholders plan will align with minimal cash results internal free cash taxpayer until end • Subject to DTM flow of 5-year period Board of Directors approval 1. Definition of distributable cash flow (Non-GAAP) in appendix 2. Definition of adjusted EBITDA (non-GAAP) included in the appendix 23 3. The dividend coverage ratio represents the total distributable cash flow (“DCF”) divided by total dividends paid to investors. Strong cash flow generation provides significant financial flexibility 1 Annualized proforma 2021 distributable cash flow (millions) $710 - $750 $500 - $550 $275 - $325 2 Adjusted EBITDA Interest Payments Maintenance Capital Other Distributable Cash Flow Dividend Value creation Considerations for 2022 and beyond optionality • Cash Interest • Modern assets • Includes cash • Targeting a 2x • Investment in expense expected to have taxes and a dividend coverage accretive growth 3 associated with low maintenance portion of ratio floor projects; $1.2 - $1.7 long-term capital capital needs unconsolidated • Targeting dividend billion through 5-year structure joint venture • Gathering yield comparable period contribution to • Additional contracts to midstream peers • Deleveraging adjusted EBITDA external capital structured to limit and dividend is balance sheet that is non-cash not expected capital obligations expected to grow in • Returning capital to given investment • Expected to be a line with financial shareholders plan will align with minimal cash results internal free cash taxpayer until end • Subject to DTM flow of 5-year period Board of Directors approval 1. Definition of distributable cash flow (Non-GAAP) in appendix 2. Definition of adjusted EBITDA (non-GAAP) included in the appendix 23 3. The dividend coverage ratio represents the total distributable cash flow (“DCF”) divided by total dividends paid to investors.

Clean assets, clean balance sheet, clean story Integrated assets in premier dry gas basins serving key markets Stable balance sheet with low leverage Predictable, robust contracted cash flows NYSE: DTM Mature environmental, social and governance leadership 24Clean assets, clean balance sheet, clean story Integrated assets in premier dry gas basins serving key markets Stable balance sheet with low leverage Predictable, robust contracted cash flows NYSE: DTM Mature environmental, social and governance leadership 24

Introduction DTE Energy DT Midstream Appendix 25Introduction DTE Energy DT Midstream Appendix 25

Committed to ethical and transparent governance practices Best-in-class governance practices • Structured as C-Corp with separate CEO and Executive Chairman Robert Skaggs, Jr. David Slater • Incentive plans tied to safety and total shareholder return targets Executive Chairman President and CEO • Board committee focused on ESG initiatives • Broad range of experience and diversity, with each director having a reputation for integrity, honesty and adherence to high ethical standards • Effective corporate controls where risks are anticipated, identified and Elaine Pickle Wright Lassiter, III mitigated Director Lead Independent Director • Financial and operating data reporting in accordance with industry standards Board diversity 4 ~43% 5 ~71% 3 gender or independent Peter Tumminello Dwayne Wilson Stephen Baker ethnically diverse 2 Director Director Director 26Committed to ethical and transparent governance practices Best-in-class governance practices • Structured as C-Corp with separate CEO and Executive Chairman Robert Skaggs, Jr. David Slater • Incentive plans tied to safety and total shareholder return targets Executive Chairman President and CEO • Board committee focused on ESG initiatives • Broad range of experience and diversity, with each director having a reputation for integrity, honesty and adherence to high ethical standards • Effective corporate controls where risks are anticipated, identified and Elaine Pickle Wright Lassiter, III mitigated Director Lead Independent Director • Financial and operating data reporting in accordance with industry standards Board diversity 4 ~43% 5 ~71% 3 gender or independent Peter Tumminello Dwayne Wilson Stephen Baker ethnically diverse 2 Director Director Director 26

Focusing on the diversity, safety, well-being and success of our employees, customers and communities Embodying a strong safety culture • Safety culture is built on empowerment, training, process safety, proactive risk mitigation and maintaining high safety standards 1 • Consistent safety performance – no employee recordables 6 out of the last 8 years • Achieving top decile performance in the National Safety Council Safety Barometer Survey since 2015 Serving our communities • Serving our local communities through volunteering, caring foundation contributions and revitalizing neighborhoods; $1.5 million in charitable contributions in 2019 / 2020 and over 1,200 volunteering hours Creating a diverse, equitable and inclusive workplace • Team is strengthened by individuals from many different backgrounds and experiences • Consistently high employee engagement feedback from the annual Gallup surveys • Creating an atmosphere where employees can thrive and make significant contributions Delivering reliable service to our customers • Recognized by industry peers as Northeast Midstream Company of the Year by the Oil and Gas Awards in 2019 • Compressor availability has been at top-decile levels of ~99% across our major operations 1. Includes 2021 27Focusing on the diversity, safety, well-being and success of our employees, customers and communities Embodying a strong safety culture • Safety culture is built on empowerment, training, process safety, proactive risk mitigation and maintaining high safety standards 1 • Consistent safety performance – no employee recordables 6 out of the last 8 years • Achieving top decile performance in the National Safety Council Safety Barometer Survey since 2015 Serving our communities • Serving our local communities through volunteering, caring foundation contributions and revitalizing neighborhoods; $1.5 million in charitable contributions in 2019 / 2020 and over 1,200 volunteering hours Creating a diverse, equitable and inclusive workplace • Team is strengthened by individuals from many different backgrounds and experiences • Consistently high employee engagement feedback from the annual Gallup surveys • Creating an atmosphere where employees can thrive and make significant contributions Delivering reliable service to our customers • Recognized by industry peers as Northeast Midstream Company of the Year by the Oil and Gas Awards in 2019 • Compressor availability has been at top-decile levels of ~99% across our major operations 1. Includes 2021 27

Mature environmental culture and industry leading aspirations Annual GHG emissions Goal of leading environmental stewardship in the industry (million metric tons / year) • Announced net zero emissions target by 2050; among first in sector to establish ~30% this goal – Targeting ~30% emissions reductions by 2030 • Net zero plan expects to use a combination of existing market-ready solutions along with future technologies under development Commitment to sustainable operations Net zero • Continuing to focus on processes to monitor air emissions, biodiversity and land use, habitat restoration, noise mitigation, spills and releases and waste and 2030 2030 2050 unabated target target water management 1 Methane emissions intensity • Existing portfolio comprised of modern-day assets, including electric compression • NGSI pilot study participant to establish reporting standards for methane intensity​ 0.033 • Participant in the EPA Methane Challenge to reduce methane emissions 0.015 • Practicing waste reduction through Pollution Prevention Program​ • Collaborating with Pennsylvania Environmental Council for clean-up events DTM Peers 1. 2019 actual methane emission intensity percentage for gathering & compression. Peer data is the ONE Future industry average reported for 2019 for gathering & compression 28Mature environmental culture and industry leading aspirations Annual GHG emissions Goal of leading environmental stewardship in the industry (million metric tons / year) • Announced net zero emissions target by 2050; among first in sector to establish ~30% this goal – Targeting ~30% emissions reductions by 2030 • Net zero plan expects to use a combination of existing market-ready solutions along with future technologies under development Commitment to sustainable operations Net zero • Continuing to focus on processes to monitor air emissions, biodiversity and land use, habitat restoration, noise mitigation, spills and releases and waste and 2030 2030 2050 unabated target target water management 1 Methane emissions intensity • Existing portfolio comprised of modern-day assets, including electric compression • NGSI pilot study participant to establish reporting standards for methane intensity​ 0.033 • Participant in the EPA Methane Challenge to reduce methane emissions 0.015 • Practicing waste reduction through Pollution Prevention Program​ • Collaborating with Pennsylvania Environmental Council for clean-up events DTM Peers 1. 2019 actual methane emission intensity percentage for gathering & compression. Peer data is the ONE Future industry average reported for 2019 for gathering & compression 28

Pipeline and Other segment is comprised of critical, low-risk infrastructure 1 Segment contribution composition Stable cash flows • Revenue is predominantly from MVCs / demand charges (take-or-pay) and currently flowing gas • Substantially all fee-based revenue with no commodity price exposure Contract type Customer type • Contracts are long-term, with an average remaining contract tenor of ~9 years • Unconsolidated joint ventures account for ~23% of Q1 2021 contribution Strong customer mix Long-term MVCs / demand charge LDCs & utilities Interstate pipelines (take-or-pay) • Diversified counterparties with solid credit profiles Producers Gas marketers Shorter-term demand Stable transmission and storage assets with diverse customers and firm volumes 1. Customer composition based on 2020 contribution and contract type composition based on Q1 2021 revenues. Reflects non-GAAP financial metric based on total revenue contribution of DTM’s various assets, 29 including DTM’s proportionate interest in joint venturesPipeline and Other segment is comprised of critical, low-risk infrastructure 1 Segment contribution composition Stable cash flows • Revenue is predominantly from MVCs / demand charges (take-or-pay) and currently flowing gas • Substantially all fee-based revenue with no commodity price exposure Contract type Customer type • Contracts are long-term, with an average remaining contract tenor of ~9 years • Unconsolidated joint ventures account for ~23% of Q1 2021 contribution Strong customer mix Long-term MVCs / demand charge LDCs & utilities Interstate pipelines (take-or-pay) • Diversified counterparties with solid credit profiles Producers Gas marketers Shorter-term demand Stable transmission and storage assets with diverse customers and firm volumes 1. Customer composition based on 2020 contribution and contract type composition based on Q1 2021 revenues. Reflects non-GAAP financial metric based on total revenue contribution of DTM’s various assets, 29 including DTM’s proportionate interest in joint ventures

High-quality Pipeline and Other segment backed by strong customers and fee-based demand charges Average Q1 2021 segment remaining Ownership Overview Key customers 1 contribution contract tenor • NEXUS is a 256-mile, 1.4 Bcf/d pipeline linking Appalachia supply with ~9 years Midwest and Ontario markets 28% 50% interest • Generation is a 25-mile PUCO-regulated intrastate pipeline system in northern Ohio • Diverse mix of demand pull and supply push customers ~11 years 50% interest • Long-term capacity contracts with anchor shipper customers • 263-mile, 2.0 Bcf/d pipeline connecting Northeast Marcellus supply 26.25% interest with Northeast markets ~6 years • West-to-east service fully contracted 47.50% interest • Invaluable outlet in an area in which new pipeline construction is 12% infeasible 26.25% interest • 348-mile, 2.8 Bcf/d pipeline connecting storage and Appalachia supply 40% interest with Midwest, Northeast and Ontario markets ~14 years • Utility and FERC pipeline customers comprise majority of revenue • Bi-directional capabilities increases optionality 10% 60% interest 1. Reflects non-GAAP financial metric based on total revenue contribution of DTM’s various assets, including DTM’s proportionate interest in joint ventures 30High-quality Pipeline and Other segment backed by strong customers and fee-based demand charges Average Q1 2021 segment remaining Ownership Overview Key customers 1 contribution contract tenor • NEXUS is a 256-mile, 1.4 Bcf/d pipeline linking Appalachia supply with ~9 years Midwest and Ontario markets 28% 50% interest • Generation is a 25-mile PUCO-regulated intrastate pipeline system in northern Ohio • Diverse mix of demand pull and supply push customers ~11 years 50% interest • Long-term capacity contracts with anchor shipper customers • 263-mile, 2.0 Bcf/d pipeline connecting Northeast Marcellus supply 26.25% interest with Northeast markets ~6 years • West-to-east service fully contracted 47.50% interest • Invaluable outlet in an area in which new pipeline construction is 12% infeasible 26.25% interest • 348-mile, 2.8 Bcf/d pipeline connecting storage and Appalachia supply 40% interest with Midwest, Northeast and Ontario markets ~14 years • Utility and FERC pipeline customers comprise majority of revenue • Bi-directional capabilities increases optionality 10% 60% interest 1. Reflects non-GAAP financial metric based on total revenue contribution of DTM’s various assets, including DTM’s proportionate interest in joint ventures 30

New slide High-quality Pipeline and Other segment backed by strong customers and fee-based demand charges Average Q1 2021 segment remaining Overview Key customers 1 contribution contract tenor • 155-mile, 1.0 Bcf/d pipeline connecting Haynesville supply to the Gulf Coast ~9 years LEAP • Supported by MVCs and acreage dedication from Indigo Natural Resources 12% • 65-mile, 1.2 Bcf/d pipeline connecting northeast Marcellus supply to Millennium and markets downstream ~6 years Bluestone 14% • Supported by demand charges and acreage dedication from Southwestern Energy and a long-term contract with Cabot Oil and Gas • 68-mile, 1.5 Bcf/d pipeline connecting southwest Marcellus supply to multiple interstate pipelines 13% ~9 years • JV between DT Midstream (85%) and Antero Midstream (15%) Stonewall • Supported by long-term contract with Antero Resources which includes an MVC Birdsboro Birdsboro • 14-mile pipeline supplying ~485 MW power plant in Pennsylvania ~18 years Power • Revenues are 100% backed by demand charge contract with the generation facility Lateral LLC 1% 9% • 94 Bcf of storage in southeast Michigan Washington 10 ~3 years • DT Midstream owns 91% Storage Complex • Strategically located, providing easy access to markets in the Midwest, Ontario and Northeast U.S. 1. Reflects non-GAAP financial metric based on total revenue contribution of DTM’s various assets, including DTM’s proportionate interest in joint ventures 31New slide High-quality Pipeline and Other segment backed by strong customers and fee-based demand charges Average Q1 2021 segment remaining Overview Key customers 1 contribution contract tenor • 155-mile, 1.0 Bcf/d pipeline connecting Haynesville supply to the Gulf Coast ~9 years LEAP • Supported by MVCs and acreage dedication from Indigo Natural Resources 12% • 65-mile, 1.2 Bcf/d pipeline connecting northeast Marcellus supply to Millennium and markets downstream ~6 years Bluestone 14% • Supported by demand charges and acreage dedication from Southwestern Energy and a long-term contract with Cabot Oil and Gas • 68-mile, 1.5 Bcf/d pipeline connecting southwest Marcellus supply to multiple interstate pipelines 13% ~9 years • JV between DT Midstream (85%) and Antero Midstream (15%) Stonewall • Supported by long-term contract with Antero Resources which includes an MVC Birdsboro Birdsboro • 14-mile pipeline supplying ~485 MW power plant in Pennsylvania ~18 years Power • Revenues are 100% backed by demand charge contract with the generation facility Lateral LLC 1% 9% • 94 Bcf of storage in southeast Michigan Washington 10 ~3 years • DT Midstream owns 91% Storage Complex • Strategically located, providing easy access to markets in the Midwest, Ontario and Northeast U.S. 1. Reflects non-GAAP financial metric based on total revenue contribution of DTM’s various assets, including DTM’s proportionate interest in joint ventures 31

Gathering segment features strategically-located assets serving top-tier supply 1 Q1 2021 contribution composition Premier supply basins • Gathering assets serve the Marcellus / Utica and Haynesville, which are the largest and among the most economic dry gas basins in the U.S. Contract type Supply basin Favorable contract structures • Revenue predominantly derived from MVCs or flowing gas volumes; providing visible and stable revenue generation • Large dedicated acreage footprint MVCs / demand Flowing gas Marcellus / Utica Haynesville • Credit agreements enhance customer credit profiles Non-MVC growth Antrim Gathering systems located in the core of the two most economic dry natural gas basins in the U.S. 1. Reflects non-GAAP financial metric based on total revenue contribution of DTM’s various assets, including DTM’s proportionate interest in joint ventures 32Gathering segment features strategically-located assets serving top-tier supply 1 Q1 2021 contribution composition Premier supply basins • Gathering assets serve the Marcellus / Utica and Haynesville, which are the largest and among the most economic dry gas basins in the U.S. Contract type Supply basin Favorable contract structures • Revenue predominantly derived from MVCs or flowing gas volumes; providing visible and stable revenue generation • Large dedicated acreage footprint MVCs / demand Flowing gas Marcellus / Utica Haynesville • Credit agreements enhance customer credit profiles Non-MVC growth Antrim Gathering systems located in the core of the two most economic dry natural gas basins in the U.S. 1. Reflects non-GAAP financial metric based on total revenue contribution of DTM’s various assets, including DTM’s proportionate interest in joint ventures 32

Well-positioned assets are backed by substantial MVCs, acreage dedications and strong contract enhancements Q1 2021 Average segment remaining Overview Key customers 1 contribution contract tenor • 343-mile gathering system in Haynesville basin in Louisiana and east Texas • Capacity of over 2.0 Bcf/d, delivering gas to LEAP and other pipelines with access to the Gulf Coast markets Blue Union Gathering ~13 years • Primary customer is Indigo Natural Resources, an experienced and well-capitalized producer 50% System • Gathering agreement is supported by dedicated acreage and MVCs and contains strong credit provisions • High-quality resource well-positioned on supply stack • 197-mile pipeline system (steel poly-pipeline) in Marcellus in northeast Pennsylvania Susquehanna • Gathering capacity of up to 1.4 Bcf/d; the system delivers gas to the Bluestone Lateral Life of reserves Gathering • Primary customer is Southwestern Energy, which has an MVC and credit enhancements 32% System • Revenue projections are dependent primarily upon MVCs and volumes from currently-flowing wells • 135-mile system serving dry gas production in north West Virginia and southwest Pennsylvania Appalachia 16% • Capacity of up to 0.9 Bcf/d ~5 years Gathering • Serves diverse mix of customers and is supported by acreage dedications System • Strong interconnectedness north (NEXUS, TETCO) and south (Columbia Pipeline) 2% Tioga • Tioga Gathering System is a Pennsylvania system with a capacity of 0.14 Bcf/d; supported by an acreage ~15 years dedication with Southwestern Energy Michigan • Michigan Gathering System includes 336 miles of rich and dry gas gathering and intrastate pipelines with a ~7 years capacity of up to 0.8 Bcf/d Gathering 1. Reflects non-GAAP financial metric based on total revenue contribution of DTM’s various assets, including DTM’s proportionate interest in joint ventures 33Well-positioned assets are backed by substantial MVCs, acreage dedications and strong contract enhancements Q1 2021 Average segment remaining Overview Key customers 1 contribution contract tenor • 343-mile gathering system in Haynesville basin in Louisiana and east Texas • Capacity of over 2.0 Bcf/d, delivering gas to LEAP and other pipelines with access to the Gulf Coast markets Blue Union Gathering ~13 years • Primary customer is Indigo Natural Resources, an experienced and well-capitalized producer 50% System • Gathering agreement is supported by dedicated acreage and MVCs and contains strong credit provisions • High-quality resource well-positioned on supply stack • 197-mile pipeline system (steel poly-pipeline) in Marcellus in northeast Pennsylvania Susquehanna • Gathering capacity of up to 1.4 Bcf/d; the system delivers gas to the Bluestone Lateral Life of reserves Gathering • Primary customer is Southwestern Energy, which has an MVC and credit enhancements 32% System • Revenue projections are dependent primarily upon MVCs and volumes from currently-flowing wells • 135-mile system serving dry gas production in north West Virginia and southwest Pennsylvania Appalachia 16% • Capacity of up to 0.9 Bcf/d ~5 years Gathering • Serves diverse mix of customers and is supported by acreage dedications System • Strong interconnectedness north (NEXUS, TETCO) and south (Columbia Pipeline) 2% Tioga • Tioga Gathering System is a Pennsylvania system with a capacity of 0.14 Bcf/d; supported by an acreage ~15 years dedication with Southwestern Energy Michigan • Michigan Gathering System includes 336 miles of rich and dry gas gathering and intrastate pipelines with a ~7 years capacity of up to 0.8 Bcf/d Gathering 1. Reflects non-GAAP financial metric based on total revenue contribution of DTM’s various assets, including DTM’s proportionate interest in joint ventures 33

Key demand markets feature positive long-term growth outlooks 1 Gulf Coast demand Midwest demand Northeast and Mid-Atlantic demand Eastern Canada demand (Bcf/d) (Bcf/d) (Bcf/d) (Bcf/d) 39% 13% 5% 21% 14.8 54.6 14.1 2.9 19.3 14.0 17.1 2.4 39.2 8.1 7.5 8.4 1.6 11.6 2 11.4 Other 8.4 1.5 Industrial 9.7 11.9 1.6 1.8 6.1 0.7 5.7 Power 9.6 0.6 5.0 4.9 17.1 LNG 4.8 0.6 8.5 3.0 exports 0.3 2021 2030 2021 2030 2021 2030 2021 2030 Demand growth is driven by the Demand growth is driven Demand growth is driven by Demand growth is driven electric and industrial sector and primarily by growth in gas-fired increased industrial usage and primarily by growth in gas-fired LNG exports power generation other industry fuel and transport power generation and industrial demand load 1. Northeast and Mid-Atlantic represents total demand in DC, MD, MA, NJ, NY, PA, VA and WV 2. Includes residential, commercial, Mexican exports, fuel and transport 34 Source: Wood MackenzieKey demand markets feature positive long-term growth outlooks 1 Gulf Coast demand Midwest demand Northeast and Mid-Atlantic demand Eastern Canada demand (Bcf/d) (Bcf/d) (Bcf/d) (Bcf/d) 39% 13% 5% 21% 14.8 54.6 14.1 2.9 19.3 14.0 17.1 2.4 39.2 8.1 7.5 8.4 1.6 11.6 2 11.4 Other 8.4 1.5 Industrial 9.7 11.9 1.6 1.8 6.1 0.7 5.7 Power 9.6 0.6 5.0 4.9 17.1 LNG 4.8 0.6 8.5 3.0 exports 0.3 2021 2030 2021 2030 2021 2030 2021 2030 Demand growth is driven by the Demand growth is driven Demand growth is driven by Demand growth is driven electric and industrial sector and primarily by growth in gas-fired increased industrial usage and primarily by growth in gas-fired LNG exports power generation other industry fuel and transport power generation and industrial demand load 1. Northeast and Mid-Atlantic represents total demand in DC, MD, MA, NJ, NY, PA, VA and WV 2. Includes residential, commercial, Mexican exports, fuel and transport 34 Source: Wood Mackenzie

Assets are backed by well-positioned, high-quality resources 1 2022 - 2024 drill supply curve (Bcf/d) $ / MMBtu 3.5 3.0 2.5 ~18 Bcf/d of new supply is needed to meet expected demand 2.0 1.5 Susquehanna Gathering / Bluestone Blue Union / LEAP 1.0 Appalachia Gathering System / Stonewall Gas Gathering Other 0.5 Associated Gas 0.0 2 4 6 8 10 12 14 16 18 20 22 Bcf/d High-quality resource ensures gas will continue to flow on DTM’s systems 1. Includes regional basis differential 35 Source: Wood MackenzieAssets are backed by well-positioned, high-quality resources 1 2022 - 2024 drill supply curve (Bcf/d) $ / MMBtu 3.5 3.0 2.5 ~18 Bcf/d of new supply is needed to meet expected demand 2.0 1.5 Susquehanna Gathering / Bluestone Blue Union / LEAP 1.0 Appalachia Gathering System / Stonewall Gas Gathering Other 0.5 Associated Gas 0.0 2 4 6 8 10 12 14 16 18 20 22 Bcf/d High-quality resource ensures gas will continue to flow on DTM’s systems 1. Includes regional basis differential 35 Source: Wood Mackenzie

Reconciliation of reported to operating earnings (non-GAAP) Use of Operating Earnings Information – Operating earnings exclude non-recurring items, certain mark-to-market adjustments and discontinued operations. DTE Energy management believes that operating earnings provide a more meaningful representation of the company’s earnings from ongoing operations and uses operating earnings as the primary performance measurement for external communications with analysts and investors. Internally, DTE Energy uses operating earnings to measure performance against budget and to report to the Board of Directors. In this presentation, DTE Energy provides guidance for future period operating earnings. It is likely that certain items that impact the company’s future period reported results will be excluded from operating results. A reconciliation to the comparable future period reported earnings is not provided because it is not possible to provide a reliable forecast of specific line items (i.e. future non-recurring items, certain mark-to-market adjustments and discontinued operations). These items may fluctuate significantly from period to period and may have a significant impact on reported earnings. 36Reconciliation of reported to operating earnings (non-GAAP) Use of Operating Earnings Information – Operating earnings exclude non-recurring items, certain mark-to-market adjustments and discontinued operations. DTE Energy management believes that operating earnings provide a more meaningful representation of the company’s earnings from ongoing operations and uses operating earnings as the primary performance measurement for external communications with analysts and investors. Internally, DTE Energy uses operating earnings to measure performance against budget and to report to the Board of Directors. In this presentation, DTE Energy provides guidance for future period operating earnings. It is likely that certain items that impact the company’s future period reported results will be excluded from operating results. A reconciliation to the comparable future period reported earnings is not provided because it is not possible to provide a reliable forecast of specific line items (i.e. future non-recurring items, certain mark-to-market adjustments and discontinued operations). These items may fluctuate significantly from period to period and may have a significant impact on reported earnings. 36

New slide Adjusted EBITDA and distributable cash flow (DCF) are non-GAAP measures Adjusted EBITDA is defined as GAAP net income attributable to DT Midstream before expenses for interest, taxes, depreciation and amortization, further adjusted to include our proportional share of net income from our equity method investees (excluding taxes, depreciation and amortization), and to exclude certain items we consider non-routine. We believe Adjusted EBITDA is useful to us and external users of our financial statements in understanding our operating results and the ongoing performance of our underlying business because it allows our management and investors to have a better understanding of our actual operating performance unaffected by the impact of interest, taxes, depreciation, amortization and non-routine charges noted in the table below. We believe the presentation of Adjusted EBITDA is meaningful to investors because it is frequently used by analysts, investors and other interested parties in our industry to evaluate a company’s operating performance without regard to items excluded from the calculation of such measure, which can vary substantially from company to company depending on accounting methods, book value of assets, capital structure and the method by which assets were acquired, among other factors. We use Adjusted EBITDA to assess our performance by reportable segment and as a basis for strategic planning and forecasting. Distributable Cash Flow (DCF) is calculated by deducting earnings from equity method investees, depreciation and amortization attributable to noncontrolling interests, cash interest expense, maintenance capital investment (as defined below), and cash taxes from, and adding interest expense, income tax expense, depreciation and amortization, certain items we consider non-routine and dividends and distributions from equity method investees to, Net Income Attributable to DT Midstream. Maintenance capital investment is defined as the total capital expenditures used to maintain or preserve assets or fulfill contractual obligations that do not generate incremental earnings. We believe DCF is a meaningful performance measurement because it is useful to us and external users of our financial statements in estimating the ability of our assets to generate cash earnings after servicing our debt, paying cash taxes and making maintenance capital investments, which could be used for discretionary purposes such as common stock dividends, retirement of debt or expansion capital expenditures. Adjusted EBITDA and DCF are not measures calculated in accordance with GAAP and should be viewed as a supplement to and not a substitute for the results of operations presented in accordance with GAAP. There are significant limitations to using Adjusted EBITDA and DCF as a measure of performance, including the inability to analyze the effect of certain recurring and non-recurring items that materially affect our net income or loss. Additionally, because Adjusted EBITDA and DCF exclude some, but not all, items that affect net income and are defined differently by different companies in our industry, Adjusted EBITDA and DCF do not intend to represent net income attributable to DT Midstream, the most comparable GAAP measure, as an indicator of operating performance and are not necessarily comparable to similarly titled measures reported by other companies. Reconciliation of net income attributable to DT Midstream to Adjusted EBITDA or DCF as projected for full-year 2021 is not provided. We do not forecast net income as we cannot, without unreasonable efforts, estimate or predict with certainty the components of net income. These components, net of tax, may include, but are not limited to, impairments of assets and other charges, divesture costs, acquisition costs, or changes in accounting principles. All of these components could significantly impact such financial measures. At this time, management is not able to estimate the aggregate impact, if any, of these items on future period reported earnings. Accordingly, we are not able to provide a corresponding GAAP equivalent for Adjusted EBITDA or DCF. 37New slide Adjusted EBITDA and distributable cash flow (DCF) are non-GAAP measures Adjusted EBITDA is defined as GAAP net income attributable to DT Midstream before expenses for interest, taxes, depreciation and amortization, further adjusted to include our proportional share of net income from our equity method investees (excluding taxes, depreciation and amortization), and to exclude certain items we consider non-routine. We believe Adjusted EBITDA is useful to us and external users of our financial statements in understanding our operating results and the ongoing performance of our underlying business because it allows our management and investors to have a better understanding of our actual operating performance unaffected by the impact of interest, taxes, depreciation, amortization and non-routine charges noted in the table below. We believe the presentation of Adjusted EBITDA is meaningful to investors because it is frequently used by analysts, investors and other interested parties in our industry to evaluate a company’s operating performance without regard to items excluded from the calculation of such measure, which can vary substantially from company to company depending on accounting methods, book value of assets, capital structure and the method by which assets were acquired, among other factors. We use Adjusted EBITDA to assess our performance by reportable segment and as a basis for strategic planning and forecasting. Distributable Cash Flow (DCF) is calculated by deducting earnings from equity method investees, depreciation and amortization attributable to noncontrolling interests, cash interest expense, maintenance capital investment (as defined below), and cash taxes from, and adding interest expense, income tax expense, depreciation and amortization, certain items we consider non-routine and dividends and distributions from equity method investees to, Net Income Attributable to DT Midstream. Maintenance capital investment is defined as the total capital expenditures used to maintain or preserve assets or fulfill contractual obligations that do not generate incremental earnings. We believe DCF is a meaningful performance measurement because it is useful to us and external users of our financial statements in estimating the ability of our assets to generate cash earnings after servicing our debt, paying cash taxes and making maintenance capital investments, which could be used for discretionary purposes such as common stock dividends, retirement of debt or expansion capital expenditures. Adjusted EBITDA and DCF are not measures calculated in accordance with GAAP and should be viewed as a supplement to and not a substitute for the results of operations presented in accordance with GAAP. There are significant limitations to using Adjusted EBITDA and DCF as a measure of performance, including the inability to analyze the effect of certain recurring and non-recurring items that materially affect our net income or loss. Additionally, because Adjusted EBITDA and DCF exclude some, but not all, items that affect net income and are defined differently by different companies in our industry, Adjusted EBITDA and DCF do not intend to represent net income attributable to DT Midstream, the most comparable GAAP measure, as an indicator of operating performance and are not necessarily comparable to similarly titled measures reported by other companies. Reconciliation of net income attributable to DT Midstream to Adjusted EBITDA or DCF as projected for full-year 2021 is not provided. We do not forecast net income as we cannot, without unreasonable efforts, estimate or predict with certainty the components of net income. These components, net of tax, may include, but are not limited to, impairments of assets and other charges, divesture costs, acquisition costs, or changes in accounting principles. All of these components could significantly impact such financial measures. At this time, management is not able to estimate the aggregate impact, if any, of these items on future period reported earnings. Accordingly, we are not able to provide a corresponding GAAP equivalent for Adjusted EBITDA or DCF. 37

New slide Reconciliation of net income attributable to DT Midstream to Adjusted EBITDA (millions) 2008 2020 1. Includes share of our equity method investees’ earnings before taxes, depreciation and amortization, which we refer to as “EBTDA.” A reconciliation Net income attributable to DT Midstream $ 38 $ 312 of earnings from equity method investees to EBTDA from equity method Plus: Interest expense 7 113 investees follows: 2008 2020 Plus: Income tax expense 24 116 Plus: Depreciation and amortization 5 152 Earnings from equity method investees $ 22 $ 108 Plus: Depreciation and amortization from 1 Plus: EBTDA from equity method investees 31 154 9 46 equity method investees 2 Plus: Adjustments for non-routine items - (16) EBTDA from equity method investees $ 31 $ 154 Less: Interest income (1) (9) 2. Adjusted EBITDA calculation excludes certain items we consider non-routine. Less: Earnings from equity method investees (22) (108) In 2020, adjustments for non-routine items were comprised of: (i) $20 million Less: Depreciation and amortization attributable to noncontrolling interests - (4) of proceeds from a post-acquisition settlement ($15 million post-tax) and (ii) $4 million of spin related transaction costs ($3 million post-tax). Adjusted EBITDA $ 82 $ 710 38New slide Reconciliation of net income attributable to DT Midstream to Adjusted EBITDA (millions) 2008 2020 1. Includes share of our equity method investees’ earnings before taxes, depreciation and amortization, which we refer to as “EBTDA.” A reconciliation Net income attributable to DT Midstream $ 38 $ 312 of earnings from equity method investees to EBTDA from equity method Plus: Interest expense 7 113 investees follows: 2008 2020 Plus: Income tax expense 24 116 Plus: Depreciation and amortization 5 152 Earnings from equity method investees $ 22 $ 108 Plus: Depreciation and amortization from 1 Plus: EBTDA from equity method investees 31 154 9 46 equity method investees 2 Plus: Adjustments for non-routine items - (16) EBTDA from equity method investees $ 31 $ 154 Less: Interest income (1) (9) 2. Adjusted EBITDA calculation excludes certain items we consider non-routine. Less: Earnings from equity method investees (22) (108) In 2020, adjustments for non-routine items were comprised of: (i) $20 million Less: Depreciation and amortization attributable to noncontrolling interests - (4) of proceeds from a post-acquisition settlement ($15 million post-tax) and (ii) $4 million of spin related transaction costs ($3 million post-tax). Adjusted EBITDA $ 82 $ 710 38

New slide DT Midstream Safe Harbor Statement This presentation contains statements which, to the extent they are not statements of historical or present fact, constitute “forward-looking statements” under the securities laws. These forward-looking statements are intended to provide management’s current expectations or plans for our future operating and financial performance, business prospects, outcomes of regulatory proceedings, market conditions, and other matters, based on what we believe to be reasonable assumptions and on information currently available to us. Forward-looking statements can be identified by the use of words such as “believe,” “expect,” “expectations,” “plans,” “intends,” “continues,” “forecasts,” “goals,” “strategy,” “prospects,” “estimate,” “project,” “scheduled,” “target,” “anticipate,” “could,” “may,” “might,” “will,” “should,” “see,” “guidance,” “outlook,” “confident” and other words of similar meaning. The absence of such words, expressions or statements, however, does not mean that the statements are not forward-looking. In particular, express or implied statements relating to future earnings, cash flow, results of operations, uses of cash, tax rates and other measures of financial performance, future actions, conditions or events, potential future plans, strategies or transactions of DT Midstream, the Spin-Off, including the expected timing of completion of the Spin-Off and estimated costs associated with the Spin-Off, and other statements that are not historical facts, are 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 of the factors that will determine these results are beyond our ability to control or accurately predict. Such assumptions, risks, uncertainties and other factors include, but are not limited to, the following: changes in general economic conditions; competitive conditions in our industry; changes in the long-term supply of, demand for and price of natural gas and related products; actions taken by third-party operators, processors, transporters and gatherers; changes in expected production from Indigo Natural Resources, LLC and/or its affiliates, Southwestern Energy Company and/or its affiliates, Antero Resources Corporation and/or its affiliates and other third parties in our areas of operation; demand for natural gas gathering, transmission, storage, transportation and water services; our ability to retain or replace existing customers or volumes due to declining demand or increased competition; the availability and price of natural gas to the consumer compared to the price of alternative and competing fuels; development and rate of adoption of and competition from alternative energy sources; our ability to successfully implement our business plan; our ability to complete organic growth projects on time and on budget and the ability of such assets to operate as designed; our ability to successfully identify, evaluate and timely complete acquisitions the ability of the acquired assets to operate at expected levels; the price and availability of debt and equity financing; restrictions in our existing and any future credit facilities; energy efficiency and technology trends; operating hazards and other risks incidental to gathering, storing and transporting natural gas; natural disasters, adverse weather conditions, power shortages, casualty losses, epidemics, pandemics (such as COVID-19) and other matters beyond our control; interest rates; labor relations; the ability of our customers and other counterparties to perform under their contracts with us, including as a result of financial distress or bankruptcy; constraints on our ability to perform our obligations under our contracts, whether as a result of non-performance by third parties, including our customers or counterparties, market constraints, third- party constraints, legal constraints (including governmental orders and guidance), or other factors; changes in the availability and cost of capital; changes in tax status; the effects of environmental, health and safety, and other government regulations and of current or pending legislation; changes in our tariff rates required by the Federal Energy Regulatory Commission, the Michigan Public Service Commission or any other regulatory agency; changes in insurance markets impacting costs and the level and types of coverage available; the timing and extent of changes in commodity prices; 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; information technology risks, including cybersecurity breaches and other disruptions or failures of our information systems; the effects of future litigation; the qualification of the Spin-Off as a tax-free Distribution; our ability to achieve the benefits that we expect to achieve as an independent publicly traded company; and our dependence on DTE Energy to provide us with certain services following the Spin-Off. The above list of factors is not exhaustive. Other factors described herein, as well as factors that are unknown or unpredictable, could also cause actual future results to be materially different from those contained in any forward-looking statement. For additional information on factors that may affect our forward-looking statements, including those associated with COVID-19, see the discussion under the section entitled “Risk Factors” in our registration statement on Form 10 and any other reports filed with the SEC. Given the uncertainties and risk factors that could cause our actual results to differ materially from those contained in any forward-looking statement, you should not put undue reliance on any 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, changes in assumptions or otherwise, unless required by law. 39New slide DT Midstream Safe Harbor Statement This presentation contains statements which, to the extent they are not statements of historical or present fact, constitute “forward-looking statements” under the securities laws. These forward-looking statements are intended to provide management’s current expectations or plans for our future operating and financial performance, business prospects, outcomes of regulatory proceedings, market conditions, and other matters, based on what we believe to be reasonable assumptions and on information currently available to us. Forward-looking statements can be identified by the use of words such as “believe,” “expect,” “expectations,” “plans,” “intends,” “continues,” “forecasts,” “goals,” “strategy,” “prospects,” “estimate,” “project,” “scheduled,” “target,” “anticipate,” “could,” “may,” “might,” “will,” “should,” “see,” “guidance,” “outlook,” “confident” and other words of similar meaning. The absence of such words, expressions or statements, however, does not mean that the statements are not forward-looking. In particular, express or implied statements relating to future earnings, cash flow, results of operations, uses of cash, tax rates and other measures of financial performance, future actions, conditions or events, potential future plans, strategies or transactions of DT Midstream, the Spin-Off, including the expected timing of completion of the Spin-Off and estimated costs associated with the Spin-Off, and other statements that are not historical facts, are 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 of the factors that will determine these results are beyond our ability to control or accurately predict. Such assumptions, risks, uncertainties and other factors include, but are not limited to, the following: changes in general economic conditions; competitive conditions in our industry; changes in the long-term supply of, demand for and price of natural gas and related products; actions taken by third-party operators, processors, transporters and gatherers; changes in expected production from Indigo Natural Resources, LLC and/or its affiliates, Southwestern Energy Company and/or its affiliates, Antero Resources Corporation and/or its affiliates and other third parties in our areas of operation; demand for natural gas gathering, transmission, storage, transportation and water services; our ability to retain or replace existing customers or volumes due to declining demand or increased competition; the availability and price of natural gas to the consumer compared to the price of alternative and competing fuels; development and rate of adoption of and competition from alternative energy sources; our ability to successfully implement our business plan; our ability to complete organic growth projects on time and on budget and the ability of such assets to operate as designed; our ability to successfully identify, evaluate and timely complete acquisitions the ability of the acquired assets to operate at expected levels; the price and availability of debt and equity financing; restrictions in our existing and any future credit facilities; energy efficiency and technology trends; operating hazards and other risks incidental to gathering, storing and transporting natural gas; natural disasters, adverse weather conditions, power shortages, casualty losses, epidemics, pandemics (such as COVID-19) and other matters beyond our control; interest rates; labor relations; the ability of our customers and other counterparties to perform under their contracts with us, including as a result of financial distress or bankruptcy; constraints on our ability to perform our obligations under our contracts, whether as a result of non-performance by third parties, including our customers or counterparties, market constraints, third- party constraints, legal constraints (including governmental orders and guidance), or other factors; changes in the availability and cost of capital; changes in tax status; the effects of environmental, health and safety, and other government regulations and of current or pending legislation; changes in our tariff rates required by the Federal Energy Regulatory Commission, the Michigan Public Service Commission or any other regulatory agency; changes in insurance markets impacting costs and the level and types of coverage available; the timing and extent of changes in commodity prices; 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; information technology risks, including cybersecurity breaches and other disruptions or failures of our information systems; the effects of future litigation; the qualification of the Spin-Off as a tax-free Distribution; our ability to achieve the benefits that we expect to achieve as an independent publicly traded company; and our dependence on DTE Energy to provide us with certain services following the Spin-Off. The above list of factors is not exhaustive. Other factors described herein, as well as factors that are unknown or unpredictable, could also cause actual future results to be materially different from those contained in any forward-looking statement. For additional information on factors that may affect our forward-looking statements, including those associated with COVID-19, see the discussion under the section entitled “Risk Factors” in our registration statement on Form 10 and any other reports filed with the SEC. Given the uncertainties and risk factors that could cause our actual results to differ materially from those contained in any forward-looking statement, you should not put undue reliance on any 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, changes in assumptions or otherwise, unless required by law. 39