UNITED STATES
SECURITIES AND EXCHANGE COMMISSION
 
Washington, D.C. 20549
 
FORM 10-Q
(Mark One)
  
☒QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934
  
FOR THE QUARTERLY PERIOD ENDED MARCH 31, 20212022
or
 
☐TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934
  
FOR THE TRANSITION PERIOD FROM TO
COMMISSION FILE NUMBER001-38629
EQUITRANS MIDSTREAM CORPORATION
(Exact name of registrant as specified in its charter) 
Pennsylvania 83-0516635
(State or other jurisdiction of incorporation or organization) (IRS Employer Identification No.)

2200 Energy Drive, Canonsburg, Pennsylvania     15317
(Address of principal executive offices)     (Zip code)
(724) 271-7600
(Registrant's telephone number, including area code)
 
Securities registered pursuant to Section 12(b) of the Act:
Title of each classTrading SymbolName of each exchange on which registered
Common Stock, no par valueETRNNew York Stock Exchange

Indicate by check mark whether the registrant: (1) has filed all reports required to be filed by Section 13 or 15(d) of the Securities Exchange Act of 1934 during the preceding 12 months (or for such shorter period that the registrant was required to file such reports), and (2) has been subject to such filing requirements for the past 90 days.    Yes  ☒  No  ☐
 
Indicate by check mark whether the registrant has submitted electronically every Interactive Data File required to be submitted pursuant to Rule 405 of Regulation S-T (§ 232.405 of this chapter) during the preceding 12 months (or for such shorter period that the registrant was required to submit such files).    Yes  ☒  No  ☐
 
Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer, a smaller reporting company, or an emerging growth company.  See the definitions of "large accelerated filer," "accelerated filer," "smaller reporting company" and "emerging growth company" in Rule 12b-2 of the Exchange Act.
Large Accelerated Filer☒Accelerated Filer                 ☐Emerging Growth Company☐
Non-Accelerated Filer☐Smaller Reporting Company☐

If an emerging growth company, indicate by check mark if the registrant has elected not to use the extended transition period for complying with any new or revised financial accounting standards provided pursuant to Section 13(a) of the Exchange Act.  ☐
 Indicate by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the Exchange Act).        Yes  ☐  No  ☒
The number of shares of common stock outstanding (in thousands), as of April 30, 2021: 432,4982022: 432,763


EQUITRANS MIDSTREAM CORPORATION
Index
 Page No.
  
3
  
 
   
Item 1.
 
   
 
5
   
76
87
   
 
108
   
 
119
  
Item 2.
2917
  
Item 3.
4632
  
Item 4.
4935
  
Item 1.
5036
  
Item 1A.
5540
Item 2.
5740
Item 6.
5841
 
6042
  
2
Table of Contents


EQUITRANS MIDSTREAM CORPORATION
Glossary of Commonly Used Terms, Abbreviations and Measurements
2021 Water Services Agreement – that certain mixed-use water services agreement entered into on October 22, 2021 by the Company and EQT (as defined below), as subsequently amended, which became effective on March 1, 2022 and replaced the Water Services Letter Agreement (as defined below) and certain other existing Pennsylvania water services agreements.
Allowance for Funds Used During Construction (AFUDC) – carrying costs for the construction of certain long-lived regulated assets are capitalized and amortized over the related assets' estimated useful lives. The capitalized amount for construction of regulated assets includes interest cost and a designated cost of equity for financing the construction of these regulated assets.
Amended EQM Credit Facility – that certain unsecured revolving credit facility of EQM Midstream Partners, LP, as previously amended and restated, including by an amendment entered on March 30, 2020 (such facility, as so amended in March 2020, the First Amended EQM Credit Facility) and a subsequent amendment entered into on April 16, 2021.
Amended 2019 EQM Term Loan Agreement - that certain term loan agreement entered into in August 2019 and amended on March 30, 2020 by EQM, which term loan agreement was terminated on January 8, 2021.
Annual Revenue Commitments (ARC or ARCs) - contractual term in a water services agreement that obligates the customer to pay for a fixed amount of water services annually.
Appalachian Basin – the area of the United States composed of those portions of West Virginia, Pennsylvania, Ohio, Maryland, Kentucky and Virginia that lie in the Appalachian Mountains.
associated gas – natural gas that is produced as a byproduct of principally oil production activities.
British thermal unit – a measure of the amount of energy required to raise the temperature of one pound of water one-degree Fahrenheit.
delivery point – the point where gas is delivered into a downstream gathering system or transmission pipeline.
EQM – EQM Midstream Partners, LP and its subsidiaries.
EQT – EQT Corporation (NYSE: EQT) and its subsidiaries.
EQT Global GGA – that certain Gas Gathering and Compression Agreement entered into on February 26, 2020 (the EQT Global GGA Effective Date) by the Company (through EQM) with EQT and certain affiliates of EQT for the provision of certain gas gathering services to EQT in the Marcellus and Utica Shales of Pennsylvania and West Virginia, as subsequently amended.
firm contracts – contracts for gathering, transmission, storage and water services that reserve an agreed upon amount of pipeline or storage capacity regardless of the capacity used by the customer during each month, and generally obligate the customer to pay a fixed, monthly charge.
firm reservation fee revenues – contractually obligated revenues that include fixed monthly charges under firm contracts and fixed volumetric charges under MVC (defined(as defined below) and ARC (as defined above) contracts.
gas – natural gas.
minimumliquefied natural gas (LNG) – natural gas that has been cooled to minus 161 degrees Celsius for transportation, typically by ship. The cooling process reduces the volume of natural gas by 600 times.
Minimum volume commitments (MVC or MVCs) – contracts for gathering or water services that obligate the customer to pay for a fixed amount of volumes daily, monthly, annually or over the life of the contract.
Mountain Valley Pipeline (MVP) – an estimated 300-mile, 42-inch diameter natural gas interstate pipeline with a targeted capacity of 2.0 Bcf per day that willis designed to span from the Company's existing transmission and storage system in Wetzel County, West Virginia to Pittsylvania County, Virginia, providing access to the growing Southeast demand markets.
Mountain Valley Pipeline, LLC (MVP Joint Venture) – a joint venture among the Company and, as applicable, affiliates of each of NextEra Energy, Inc., Consolidated Edison, Inc. (Con Edison), AltaGas Ltd. and RGC Resources, Inc. that is constructing the MVP and the MVP Southgate (defined(as defined below) projects.
3
Table of Contents


MVP Southgate – a proposed 75-mile interstate pipeline that willis contemplated to extend from the MVP at Pittsylvania County, Virginia to new delivery points in Rockingham and Alamance Counties, North Carolina. The project is subject to ongoing discussions between the MVP Joint Venture and the project shipper, Dominion Energy North Carolina, as discussed in Part I, "Outlook" in "Item 2. Management's Discussion and Analysis of Financial Condition and Results of Operations" of this Quarterly Report on Form 10-Q.
natural gas liquids (NGLs) – those hydrocarbons in natural gas that are separated from the gas as liquids through the process of absorption, condensation, adsorption or other methods in gas processing plants. Natural gas liquids include ethane, propane, butane and iso-butane.
play– a proven geological formation that contains commercial amounts of hydrocarbons.
Preferred Interest – the preferred interest that the Company has in EQT Energy Supply, LLC (EES), a subsidiary of EQT.
throughput – the volume of natural gas transported or passing through a pipeline, plant, terminal or other facility during a particular period.
3
Table of Contents


Water Services Letter Agreement – that certain letter agreement entered into on February 26, 2020 by the Company (through EQM) and EQT, pursuant to which EQT agreed to utilize the Company for the provision of water services in Pennsylvania under existing water services agreements and new water services agreements if negotiated between the parties.parties, which letter agreement was replaced by the 2021 Water Services Agreement on March 1, 2022.
wellhead – the equipment at the surface of a well used to control the well's pressure and the point at which the hydrocarbons and water exit the ground. 
Unless the context otherwise requires, a reference to a “Note” herein refers to the accompanying Notes to Consolidated Financial Statements contained in Part I, "Item 1. Financial Statements."
AbbreviationsMeasurements
ASC – Accounting Standards Codification
Btu = one British thermal unit
ASU – Accounting Standards Update
BBtu = billion British thermal units
EPA – U.S. Environmental Protection Agency
Bcf   = billion cubic feet
FASB – Financial Accounting Standards Board
Mcf = thousand cubic feet
FERC – U.S. Federal Energy Regulatory Commission
MMBtuMMcf  = million British thermal unitscubic feet
GAAP – United States Generally Accepted Accounting Principles
MMcfMMgal  = million cubic feetgallons
IRS – United States Internal Revenue Service
NGA – Natural Gas Act of 1938
MMgal  = million gallons
NYMEX – New York Mercantile Exchange
NYSE – New York Stock Exchange

SEC – U.S. Securities and Exchange Commission
4
Table of Contents


PART I.  FINANCIAL INFORMATION
Item 1. Financial Statements

EQUITRANS MIDSTREAM CORPORATION
Statements of Consolidated Comprehensive Income (Unaudited)
Three Months Ended March 31, Three Months Ended March 31,
20212020 20222021
(Thousands, except per share amounts) (Thousands, except per share amounts)
Operating revenues (a)
Operating revenues (a)
$379,996 $453,113 
Operating revenues (a)
$342,146 $379,996 
Operating expenses:Operating expenses:  Operating expenses:  
Operating and maintenanceOperating and maintenance34,099 38,422 Operating and maintenance32,834 34,099 
Selling, general and administrativeSelling, general and administrative35,494 29,739 Selling, general and administrative28,126 35,494 
Transaction costs0 11,360 
DepreciationDepreciation68,618 61,348 Depreciation67,043 68,618 
Amortization of intangible assetsAmortization of intangible assets16,205 14,581 Amortization of intangible assets16,205 16,205 
Impairments of long-lived assets (b)
0 55,581 
Total operating expensesTotal operating expenses154,416 211,031 Total operating expenses144,208 154,416 
Operating incomeOperating income225,580 242,082 Operating income197,938 225,580 
Equity income (c)(a)
Equity income (c)(a)
3 54,072 
Equity income (c)(a)
4 3 
Other income (d)
7,599 4,163 
Other income, netOther income, net6,348 7,599 
Loss on extinguishment of debt (e)
Loss on extinguishment of debt (e)
41,025 24,864 
Loss on extinguishment of debt (e)
— (41,025)
Net interest expense (a)
Net interest expense (a)
95,144 66,754 
Net interest expense (a)
(93,121)(95,144)
Income before income taxesIncome before income taxes97,013 208,699 Income before income taxes111,169 97,013 
Income tax expenseIncome tax expense20,416 19,139 Income tax expense6,261 20,416 
Net incomeNet income76,597 189,560 Net income104,908 76,597 
Net income attributable to noncontrolling interestsNet income attributable to noncontrolling interests3,914 119,828 Net income attributable to noncontrolling interests3,775 3,914 
Net income attributable to Equitrans MidstreamNet income attributable to Equitrans Midstream72,683 69,732 Net income attributable to Equitrans Midstream101,133 72,683 
Preferred dividends (f)
Preferred dividends (f)
14,628 0 
Preferred dividends (f)
14,628 14,628 
Net income attributable to Equitrans Midstream common shareholdersNet income attributable to Equitrans Midstream common shareholders$58,055 $69,732 Net income attributable to Equitrans Midstream common shareholders$86,505 $58,055 
Earnings per share of common stock attributable to Equitrans Midstream common shareholders - basic (g)
Earnings per share of common stock attributable to Equitrans Midstream common shareholders - basic (g)
$0.13 $0.28 
Earnings per share of common stock attributable to Equitrans Midstream common shareholders - basic (g)
$0.20 $0.13 
Earnings per share of common stock attributable to Equitrans Midstream common shareholders - diluted (g)
Earnings per share of common stock attributable to Equitrans Midstream common shareholders - diluted (g)
$0.13 $0.28 
Earnings per share of common stock attributable to Equitrans Midstream common shareholders - diluted (g)
$0.20 $0.13 
Weighted average common shares outstanding - basicWeighted average common shares outstanding - basic432,983 248,591 Weighted average common shares outstanding - basic433,318 432,983 
Weighted average common shares outstanding - dilutedWeighted average common shares outstanding - diluted433,158 248,591 Weighted average common shares outstanding - diluted433,913 433,158 
Statement of comprehensive income:Statement of comprehensive income:Statement of comprehensive income:
Net incomeNet income$76,597 $189,560 Net income$104,908 $76,597 
Other comprehensive income, net of tax:Other comprehensive income, net of tax:Other comprehensive income, net of tax:
Pension and other post-retirement benefits liability adjustment, net of tax expense of $12 and $1034 30 
Pension and other post-retirement benefits liability adjustment, net of tax expense of $12 and $12Pension and other post-retirement benefits liability adjustment, net of tax expense of $12 and $1234 34 
Other comprehensive incomeOther comprehensive income34 30 Other comprehensive income34 34 
Comprehensive incomeComprehensive income76,631 189,590 Comprehensive income104,942 76,631 
Less: Comprehensive income attributable to noncontrolling interestsLess: Comprehensive income attributable to noncontrolling interests3,914 119,828 Less: Comprehensive income attributable to noncontrolling interests3,775 3,914 
Less: Comprehensive income attributable to preferred dividends (f)
Less: Comprehensive income attributable to preferred dividends (f)
14,628 0 
Less: Comprehensive income attributable to preferred dividends (f)
14,628 14,628 
Comprehensive income attributable to Equitrans Midstream common shareholdersComprehensive income attributable to Equitrans Midstream common shareholders$58,089 $69,762 Comprehensive income attributable to Equitrans Midstream common shareholders$86,539 $58,089 
Dividends declared per common shareDividends declared per common share$0.15 $0.15 Dividends declared per common share$0.15 $0.15 

(a)Includes related party activity with EQT Corporation (EQT). See Note 6.
(b)See Note 3 for disclosure regarding impairments of long-lived assets.
(c)Represents equity income from Mountain Valley Pipeline, LLC (the MVP Joint Venture). See Note 7.5.

The accompanying notes are an integral part of these consolidated financial statements.
5
Table of Contents


(d)See Note 9 for disclosures regarding derivative instruments.EQUITRANS MIDSTREAM CORPORATION
(e)See Note 8 for disclosure regarding loss on extinguishmentStatements of debt.Consolidated Cash Flows (Unaudited)
(f)See Note 2for disclosure regarding the Equitrans Midstream Preferred Shares (as defined in Note 2).
(g)See Note 10 for disclosure regarding the Company's calculation of net income per share of common stock (basic and diluted).

 Three Months Ended March 31,
 20222021
 (Thousands)
Cash flows from operating activities:  
Net income$104,908 $76,597 
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation67,043 68,618 
Amortization of intangible assets16,205 16,205 
Deferred income taxes4,603 20,406 
Equity income(4)(3)
Other income(6,501)(7,254)
Loss on extinguishment of debt— 41,025 
Non-cash long-term compensation expense2,990 4,445 
Changes in other assets and liabilities:
Accounts receivable34,759 17,725 
Accounts payable(7,679)1,337 
Accrued interest(74,812)(46,934)
Deferred revenue86,652 72,019 
Other assets and other liabilities(42,218)(34,634)
Net cash provided by operating activities185,946 229,552 
Cash flows from investing activities:  
Capital expenditures(71,285)(61,265)
Capital contributions to the MVP Joint Venture(72,537)(10,723)
Principal payments received on the Preferred Interest1,351 1,277 
Net cash used in investing activities(142,471)(70,711)
Cash flows from financing activities:  
Proceeds from revolving credit facility borrowings55,000 77,500 
Payments on revolving credit facility borrowings(112,000)(70,000)
Proceeds from the issuance of long-term debt— 1,900,000 
Debt discounts, debt issuance costs and credit facility arrangement fees— (24,204)
Payment for retirement of long-term debt— (1,936,250)
Dividends paid to holders of Equitrans Midstream Preferred Shares(14,628)(14,628)
Dividends paid to common shareholders(64,901)(64,871)
Distributions to noncontrolling interests— (2,500)
Net cash used in financing activities(136,529)(134,953)
Net change in cash and cash equivalents(93,054)23,888 
Cash and cash equivalents at beginning of period134,661 208,023 
Cash and cash equivalents at end of period$41,607 $231,911 
Cash paid during the period for:  
Interest, net of amount capitalized$165,631 $140,199 
Cash paid for taxes$815 $— 
The accompanying notes are an integral part of these consolidated financial statements.
6
Table of Contents


EQUITRANS MIDSTREAM CORPORATION
Statements of Consolidated Cash FlowsBalance Sheets (Unaudited)
 Three Months Ended March 31,
 20212020
 (Thousands)
Cash flows from operating activities:  
Net income$76,597 $189,560 
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation68,618 61,348 
Amortization of intangible assets16,205 14,581 
Deferred income taxes20,406 18,710 
Impairments of long-lived assets0 55,581 
Equity income(3)(54,072)
Other income(7,254)(4,306)
Loss on extinguishment of debt41,025 24,864 
Non-cash long-term compensation expense4,445 4,544 
Changes in other assets and liabilities:
Accounts receivable17,725 (998)
Accounts payable1,337 6,067 
Accrued interest(46,934)(28,793)
Deferred revenue72,019 0 
Other assets and other liabilities(34,634)(37,783)
Net cash provided by operating activities229,552 249,303 
Cash flows from investing activities:  
Capital expenditures(61,265)(152,392)
Capital contributions to the MVP Joint Venture(10,723)(45,150)
Principal payments received on the Preferred Interest (defined in Note 6)1,277 1,225 
Net cash used in investing activities(70,711)(196,317)
Cash flows from financing activities:  
Proceeds from revolving credit facility borrowings77,500 1,170,000 
Payments on revolving credit facility borrowings(70,000)(350,000)
Proceeds from the issuance of long-term debt1,900,000 0 
Debt discounts, debt issuance costs and credit facility origination fees(24,204)(2,740)
Payment for retirement of long-term debt(1,936,250)(594,000)
Distributions paid to noncontrolling interest EQM unitholders0 (96,526)
Distributions paid to holders of EQM Series A Preferred Units (as defined in Note 2)0 (25,501)
Dividends paid to holders of Equitrans Midstream Preferred Shares(14,628)0 
Dividends paid to common shareholders(64,871)(114,254)
Cash Shares and Cash Amount (as defined in Note 5)0 (52,323)
Distributions to Eureka Midstream Holdings, LLC non-controlling member(2,500)0 
Net cash used in financing activities(134,953)(65,344)
Net change in cash and cash equivalents23,888 (12,358)
Cash and cash equivalents at beginning of period208,023 88,322 
Cash and cash equivalents at end of period$231,911 $75,964 
Cash paid during the period for:  
Interest, net of amount capitalized$140,199 $94,343 
Non-cash activity during the period for:
  
Contract liability0 128,314 
March 31, 2022December 31, 2021
(Thousands)
ASSETS
Current assets:  
Cash and cash equivalents$41,607 $134,661 
Accounts receivable (net of allowance for credit losses of $2,683 and $2,696 as of March 31, 2022 and December 31, 2021, respectively)231,985 252,301 
Other current assets52,306 59,867 
Total current assets325,898 446,829 
Property, plant and equipment9,061,829 9,004,602 
Less: accumulated depreciation(1,278,247)(1,217,099)
Net property, plant and equipment7,783,582 7,787,503 
Investment in unconsolidated entity1,278,992 1,239,039 
Goodwill486,698 486,698 
Net intangible assets635,567 651,771 
Other assets307,965 308,924 
Total assets$10,818,702 $10,920,764 
LIABILITIES, MEZZANINE EQUITY AND SHAREHOLDERS' EQUITY  
Current liabilities:  
Accounts payable$47,649 $59,627 
Capital contributions payable to the MVP Joint Venture39,159 72,188 
Accrued interest77,097 151,909 
Accrued liabilities43,814 83,852 
Total current liabilities207,719 367,576 
Long-term liabilities:
   Revolving credit facility borrowings448,000 505,000 
   Long-term debt6,437,703 6,434,945 
   Contract liability907,994 821,342 
   Regulatory and other long-term liabilities97,156 99,333 
Total liabilities8,098,572 8,228,196 
Mezzanine equity:
Equitrans Midstream Preferred Shares, 30,018 shares issued and outstanding as of March 31, 2022 and December 31, 2021681,842 681,842 
Shareholders' equity:  
Common stock, no par value, 432,677 and 432,522 shares issued and outstanding as of March 31, 2022 and December 31, 2021, respectively3,960,588 3,957,756 
Retained deficit(2,407,250)(2,428,171)
Accumulated other comprehensive loss(2,020)(2,054)
Total common shareholders' equity1,551,318 1,527,531 
Noncontrolling interests486,970 483,195 
Total shareholders' equity2,038,288 2,010,726 
Total liabilities, mezzanine equity and shareholders' equity$10,818,702 $10,920,764 


The accompanying notes are an integral part of these consolidated financial statements.
7
Table of Contents


EQUITRANS MIDSTREAM CORPORATION
Statements of Consolidated Balance SheetsShareholders' Equity and Mezzanine Equity (Unaudited)
March 31, 2021December 31, 2020
(Thousands)
ASSETS
Current assets:  
Cash and cash equivalents$231,911 $208,023 
Accounts receivable (net of allowance for credit losses of $4,281 and $4,699 as of March 31, 2021 and December 31, 2020, respectively) (a)
288,748 290,446 
Other current assets (a)
51,587 63,268 
Total current assets572,246 561,737 
Property, plant and equipment8,892,078 8,835,652 
Less: accumulated depreciation(1,076,120)(1,007,756)
Net property, plant and equipment7,815,958 7,827,896 
Investment in unconsolidated entity2,870,219 2,796,316 
Goodwill486,698 486,698 
Net intangible assets700,385 716,590 
Other assets (a)
343,341 336,615 
Total assets$12,788,847 $12,725,852 
LIABILITIES, MEZZANINE EQUITY AND SHAREHOLDERS' EQUITY  
Current liabilities:  
Current portion of revolving credit facility borrowings (b)
$310,000 $302,500 
Accounts payable67,663 72,098 
Capital contributions payable to the MVP Joint Venture72,995 10,723 
Accrued interest79,257 126,191 
Accrued liabilities44,909 83,366 
Total current liabilities574,824 594,878 
Long-term liabilities:
   Revolving credit facility borrowings (c)
485,000 485,000 
   Long-term debt6,426,670 6,443,312 
   Contract liability (a)(d)
470,769 398,750 
   Deferred income tax liability371,530 345,896 
   Regulatory and other long-term liabilities97,759 94,902 
Total liabilities8,426,552 8,362,738 
Mezzanine equity:
Equitrans Midstream Preferred Shares, 30,018 and 30,018 shares issued and outstanding as of March 31, 2021 and December 31, 2020, respectively (e)
681,842 681,842 
Shareholders' equity:  
Common stock, no par value, 432,498 and 432,470 shares issued and outstanding as of March 31, 2021 and December 31, 2020, respectively3,945,957 3,941,295 
Retained deficit(735,888)(728,959)
Accumulated other comprehensive loss(2,195)(2,229)
Total common shareholders' equity3,207,874 3,210,107 
Noncontrolling interests472,579 471,165 
Total shareholders' equity3,680,453 3,681,272 
Total liabilities, mezzanine equity and shareholders' equity$12,788,847 $12,725,852 
Mezzanine
Equity
AccumulatedEquitrans
Common StockOtherMidstream
 SharesNoRetainedComprehensiveNoncontrollingTotalPreferred
 OutstandingPar ValueDeficitLossInterestsEquityShares
 (Thousands, except per share amounts)
Balance at January 1, 2021432,470 $3,941,295 $(728,959)$(2,229)$471,165 $3,681,272 $681,842 
Other comprehensive income (net of tax):
Net income— — 58,055 — 3,914 61,969 14,628 
Pension and other post-retirement benefits liability adjustment, net of tax expense of $12— — — 34 — 34 — 
Dividends on common shares ($0.15 per share)— — (64,984)— — (64,984)— 
Share-based compensation plans, net28 4,662 — — — 4,662 — 
Distributions paid to noncontrolling interests— — — — (2,500)(2,500)— 
Dividends paid to holders of Equitrans Midstream Preferred Shares ($0.4873 per share)— — — — — — (14,628)
Balance at March 31, 2021432,498 $3,945,957 $(735,888)$(2,195)$472,579 $3,680,453 $681,842 

(a)Includes related party activity with EQT. See Note 6.
(b)Includes aggregate borrowings outstanding on the Eureka Credit Facility (as defined in Note 8) as of March 31, 2021 and December 31, 2020. See Note 8 for further detail.
(c)Includes aggregate borrowings outstanding on the Amended EQM Credit Facility (as defined in Note 8) as of March 31, 2021 and December 31, 2020. See Note 8 for further detail.
(d)See Note 5 for disclosure regarding the Company's contract liabilities.
(e)See Note 2 for disclosures regarding the Equitrans Midstream Preferred Shares.
8
Table of Contents



Mezzanine
Equity
AccumulatedEquitrans
Common StockOtherMidstream
SharesNoRetainedComprehensiveNoncontrollingTotalPreferred
OutstandingPar ValueDeficitLossInterestsEquityShares
(Thousands, except per share amounts)
Balance at January 1, 2022432,522 $3,957,756 $(2,428,171)$(2,054)$483,195 $2,010,726 $681,842 
Other comprehensive income (net of tax):
Net income— — 86,505 — 3,775 90,280 14,628 
Pension and other post-retirement benefits liability adjustment, net of tax expense of $12— — — 34 — 34 — 
Dividends on common shares ($0.15 per share)— — (65,584)— — (65,584)— 
Share-based compensation plans, net155 2,832 — — — 2,832 — 
Dividends paid to holders of Equitrans Midstream Preferred Shares ($0.4873 per share)— — — — — — (14,628)
Balance at March 31, 2022432,677 $3,960,588 $(2,407,250)$(2,020)$486,970 $2,038,288 $681,842 
The accompanying notes are an integral part of these consolidated financial statements.
9
Table of Contents


EQUITRANS MIDSTREAM CORPORATION
Statements of Consolidated Shareholders' Equity and Mezzanine Equity (Unaudited)
Common Stock
Accumulated
Other
 SharesNoRetainedComprehensiveNoncontrollingTotal
 OutstandingPar ValueDeficitLossInterestsEquity
 (Thousands, except per share and unit amounts)
Balance at January 1, 2020254,745 $1,292,804 $(618,062)$(2,026)$4,609,364 $5,282,080 
Other comprehensive income (net of tax):
Net income— — 69,732 — 119,828 189,560 
Pension and other post-retirement benefits liability adjustment, net of tax expense of $10— — 0 30 — 30 
Dividends on common shares ($0.45 per share)(178)— (115,400)— — (115,400)
Share-based compensation plans85 4,500 — — 285 4,785 
Distributions paid to noncontrolling interest unitholders ($1.16 per common unit for EQM)— — — — (96,526)(96,526)
Distributions paid to holders of EQM Series A Preferred Units ($1.0364 per EQM Series A Preferred Unit)— — — — (25,501)(25,501)
Share Purchase Agreements (as defined in Note 5)(25,300)— (190,992)— — (190,992)
Adoption of Topic 326— 0 (3,718)— 0 (3,718)
Balance at March 31, 2020229,352 $1,297,304 $(858,440)$(1,996)$4,607,450 $5,044,318 
Mezzanine
Equity
Common Stock
AccumulatedEquitrans
OtherMidstream
SharesNoRetainedComprehensiveNoncontrollingTotalPreferred
OutstandingPar ValueDeficitLossInterestsEquityShares
(Thousands, except per share amounts)
Balance at January 1, 2021432,470 $3,941,295 $(728,959)$(2,229)$471,165 $3,681,272 $681,842 
Other comprehensive income (net of tax):
Net income— — 58,055 — 3,914 61,969 14,628 
Pension and other post-retirement benefits liability adjustment, net of tax expense of $12— — — 34 — 34 — 
Dividends on common shares ($0.15 per share)— — (64,984)— — (64,984)— 
Share-based compensation plans, net28 4,662 — — — 4,662 — 
Distributions paid to noncontrolling interest in Eureka— — — — (2,500)(2,500)— 
Distributions paid to holders of Equitrans Midstream Preferred Shares ($0.4873 per share)— — — — — — (14,628)
Balance at March 31, 2021432,498 $3,945,957 $(735,888)$(2,195)$472,579 $3,680,453 $681,842 
The accompanying notes are an integral part of these consolidated financial statements.
108
Table of Contents


EQUITRANS MIDSTREAM CORPORATION
Notes to Consolidated Financial Statements (Unaudited)
1.    Financial Statements
Nature of Business. The Company provides midstream services to its customers in Pennsylvania, West Virginia and Ohio through its three primary assets: the gathering system, which includes predominantly dry gas gathering systems of high-pressure gathering lines; the transmission system, which includes FERC-regulated interstate pipelines and storage systems; and the water service system,network, which primarily consists of water pipelines impoundment facilities, pumping stations, take point facilities and measurementother facilities that support well completion activities and collect flowback and produced water for recycling or disposal.handling activities.
Basis of Presentation. References in these financial statements to Equitrans Midstream or the Company refer collectively to Equitrans Midstream Corporation and its consolidated subsidiaries for all periods presented, unless otherwise indicated.
The accompanying unaudited consolidated financial statements have been prepared in accordance with generally accepted accounting principles in the United States (GAAP) for interim financial information and with the requirements of Form 10-Q and Article 10 of Regulation S-X. Accordingly, they do not include all of the information and footnotes required by GAAP for complete financial statements. In the opinion of management, these unaudited consolidated financial statements include all adjustments (consisting of only normal, recurring adjustments, unless otherwise disclosed in this Quarterly Report on Form 10-Q) necessary for a fair presentation of the financial position of the Company as of March 31, 2021,2022, the results of its operations, cash flows and equity for the three months ended March 31, 20212022 and 2020 and its cash flows for the three months ended March 31, 2021 and 2020.2021. The consolidated balance sheet at December 31, 20202021 has been derived from the audited financial statements at that date but does not include all of the information and notes required by GAAP for complete financial statements. This Quarterly Report on Form 10-Q should be read in conjunction with the Company's Annual Report on Form 10-K for the year ended December 31, 2020,2021, which includes all disclosures required by GAAP.

Due to, among other things, the seasonal nature of the Company's utility customer contracts, as well as producers’ well completion activities and varying needs for fresh and produced water (which are partiallyprimarily driven by horizontal lateral lengths and the number of completion stages per well), the interim statements for the three months ended March 31, 20212022 are not necessarily indicative of the results that may be expected for the year ending December 31, 2021.2022.

For further information, refer to the Company's annual consolidated financial statements and related notes in the Company's Annual Report on Form 10-K for the year ended December 31, 2020,2021, as well as Part I, "Item 2. Management's Discussion and Analysis of Financial Condition and Results of Operations" contained herein.

The consolidated financial statements as of and for the three months ended March 31, 2021, and the consolidated balance sheet at December 31, 2020, reflect the closing of the EQM Merger and the Restructuring (each as defined in Note 2). See Note 2 for further information.
Recently Issued Accounting StandardsStandards.

In March 2020, the FASB issued ASU 2020-04, Reference Rate Reform (Topic 848), which provides practical expedients for contract modifications and certain hedging relationships associated with the transition from reference rates that are expected to be discontinued. This guidance is applicable for the Amended EQM Credit Facility and the 2021 Eureka Credit Facility (each as(as defined in Note 8)6), as well as for each dividend following March 31, 2024 for the Equitrans Midstream Preferred Shares, which each use the London Inter-Bank Offered Rate (LIBOR) as a reference rate. The ASU was effective immediately but is only available through December 31, 2022. The Company is currently evaluating the potential impact of this standard on its financial statements.statements and related disclosures.
In August 2020, the FASB issued ASU 2020-06, Accounting for Convertible Instruments and Contracts in an Entity’s Own Equity, which simplifies the accounting for convertible debt and convertible preferred stock by removing the requirements to separately present certain conversion features in equity. In addition, the amendments in the ASU 2020-06 also simplify the guidance in ASC Subtopic 815-40, Derivatives and Hedging: Contracts in Entity’s Own Equity, by removing certain criteria that must be satisfied in order to classify a contract as equity. Finally, the amendments revise the guidance on calculating earnings per share, requiring use of the if-converted method for all convertible instruments and rescinding an entity’s ability to rebut the presumption of share settlement for instruments that may be settled in cash or other assets. The amendments will bewere effective for fiscal years beginning after December 15, 2021. Early adoption is permitted for fiscal years beginning after December 15, 2020. Adoption of the guidance must commence at the beginning of the annual fiscal year. The Company is currently evaluating the potential impact ofadopted this standard on itsJanuary 1, 2022 with no significant effect on the Company's financial statements.statements or related disclosures.
119

2.    Investments in Consolidated, Non-Wholly Owned Entities
EQM Merger. On June 17, 2020, pursuant to that certain Agreement and PlanTable of Merger, dated as of February 26, 2020, by and among the Company, EQM LP Corporation, a wholly owned subsidiary of the Company (EQM LP), LS Merger Sub, LLC, a wholly owned subsidiary of EQM LP (Merger Sub), EQM and EQGP Services, LLC, the general partner of EQM (the EQM General Partner), Merger Sub merged with and into EQM (the EQM Merger), with EQM continuing and surviving as an indirect, wholly owned subsidiary of the Company. Upon consummation of the EQM Merger, the Company acquired all of the outstanding EQM common units representing limited partner interests in EQM (EQM common units) that the Company and its subsidiaries did not already own. Following the closing of the EQM Merger, EQM was no longer a publicly traded entity.
At the effective time of the EQM Merger (the Effective Time), subject to applicable tax withholding, (i) each outstanding EQM common unit, other than EQM common units owned by the Company and its subsidiaries, was converted into the right to receive 2.44 shares of Equitrans Midstream common stock (the Merger Consideration); (ii) (x) $600.0 million aggregate principal amount of the Series A Perpetual Convertible Preferred Units representing limited partner interests in EQM (such units, EQM Series A Preferred Units) issued and outstanding immediately prior to the Effective Time were redeemed by EQM for cash at 101% of the EQM Series A Preferred Unit purchase price of $48.77 per such unit (the EQM Series A Preferred Unit Purchase Price) plus any accrued and unpaid distribution amounts and partial period distribution amounts, and (y) immediately following such redemption, each remaining issued and outstanding EQM Series A Preferred Unit was exchanged for 2.44 shares of a newly authorized and created series of preferred stock, without par value, of Equitrans Midstream, convertible into Equitrans Midstream common stock (the Equitrans Midstream Preferred Shares) on a one for one basis, in each case, in connection with the occurrence of the "Series A Change of Control" (as defined in the Fourth Amended and Restated Agreement of Limited Partnership of EQM (as amended, the Former EQM Partnership Agreement)) that occurred upon the closing of the EQM Merger; and (iii) each outstanding phantom unit relating to an EQM common unit issued pursuant to the Amended and Restated EQGP Services, LLC 2012 Long-Term Incentive Plan, dated as of February 22, 2019 (the EQM LTIP), and any other award issued pursuant to the EQM LTIP, whether vested or unvested, was converted into the right to receive, with respect to each EQM common unit subject thereto, the Merger Consideration (plus any accrued but unpaid amounts in relation to distribution equivalent rights). The limited partner interests in EQM owned by the Company and its subsidiaries remained outstanding as limited partner interests in the surviving entity. The EQM General Partner continued to own the non-economic general partner interest in the surviving entity.
No fractional shares of Equitrans Midstream common stock were issued in the EQM Merger; instead, all fractions of Equitrans Midstream common stock to which an EQM common unitholder otherwise would have been entitled were aggregated and the resulting fraction was rounded up to the nearest whole share of Equitrans Midstream common stock.
In connection with the EQM Merger at the Effective Time, the Company's omnibus and secondment agreements with EQM and certain other subsidiaries of the Company terminated, subject to the survival of certain license rights and indemnification obligations.
Because the Company controlled EQM both before and after the EQM Merger, the increase in the Company’s ownership interest in EQM resulting from the EQM Merger was accounted for as an equity transaction and reflected as a reduction of the noncontrolling interest associated with public ownership of EQM common units, offset by an increase in common stock, no par value, during the second quarter of 2020. No gain or loss was recognized in the Company’s statements of consolidated comprehensive income as a result of the EQM Merger. In addition, the tax effects of the EQM Merger were reported as adjustments to deferred income taxes and Equitrans Midstream common stock, consistent with ASC 740, Income Taxes.
Immediately prior to the completion of the EQM Merger, the public limited partners collectively owned a 40.1% interest in EQM, excluding the impact of the EQM Series A Preferred Units. The publicly-owned EQM common units, prior to completion of the EQM Merger, were reflected within noncontrolling interest in the Company's consolidated balance sheets as of March 31, 2020. The portion of EQM earnings attributable to publicly held EQM common units prior to completion of the EQM Merger was reflected in net income attributable to noncontrolling interests in the Company's statements of consolidated comprehensive income.
Additionally, for the periods prior to the EQM Merger, the Company determined that EQM was a variable interest entity. Through the Company's ownership and control of the general partner of EQM during those periods, the Company had the power to direct the activities that most significantly affected EQM's economic performance. As a result of the EQM Merger, EQM is no longer a variable interest entity.
The Company recorded $11.4 million in expenses related to the EQM Merger and the EQT Global GGA (defined in Note 3) during the three months ended March 31, 2020. The expenses primarily included advisor, legal and accounting fees related to the transactions and are included in transaction costs in the statements of consolidated comprehensive income.
12

Preferred Restructuring Agreement. On February 26, 2020, the Company and EQM entered into a Preferred Restructuring Agreement (the Restructuring Agreement) with all of the holders of the EQM Series A Preferred Units (such investors, collectively, the Investors), pursuant to which, at the Effective Time: (i) EQM redeemed $600 million aggregate principal amount of the Investors' EQM Series A Preferred Units issued and outstanding immediately prior to the Restructuring Closing (defined below), which occurred substantially concurrent with the closing of the EQM Merger, for cash at 101% of the EQM Series A Preferred Unit Purchase Price plus any accrued and unpaid distribution amounts and partial period distribution amounts, and (ii) immediately following such redemption, each remaining issued and outstanding EQM Series A Preferred Unit was exchanged for 2.44 Equitrans Midstream Preferred Shares, in each case, in connection with the occurrence of the “Series A Change of Control” (as defined in the Former EQM Partnership Agreement) that occurred upon the closing of the EQM Merger (collectively, the Restructuring and, the closing of the Restructuring, the Restructuring Closing). The Equitrans Midstream Preferred Shares issued were not registered under the Securities Act of 1933, as amended (the Securities Act), in reliance upon the exemption provided in Section 4(a)(2) of the Securities Act and/or Regulation D promulgated thereunder.
The Company's Second Amended and Restated Articles of Incorporation (the Restated Articles) set forth the designations, rights and preferences of the Equitrans Midstream Preferred Shares.
The Equitrans Midstream Preferred Shares were a new class of securities as of June 2020. They rank pari passu with any other outstanding class or series of preferred stock of the Company and senior to Equitrans Midstream common stock with respect to dividend rights and rights upon liquidation. The Equitrans Midstream Preferred Shares vote on an as-converted basis with Equitrans Midstream common stock and have certain other class voting rights with respect to any amendment to the Restated Articles that would be adverse (other than in a de minimis manner) to any of the rights, preferences or privileges of the Equitrans Midstream Preferred Shares.Contents

The holders of the Equitrans Midstream Preferred Shares receive cumulative quarterly dividends at a rate per annum of 9.75% for each quarter ending on or before March 31, 2024, and thereafter quarterly dividends at a rate per annum equal to the sum of (i) three-month LIBOR as of the LIBOR Determination Date (as defined in the Restated Articles) in respect of the applicable quarter and (ii) 8.15%; provided that such rate per annum in respect of periods after March 31, 2024 will not be less than 10.50%. The Company is not permitted to pay any dividends on any junior securities, including on Equitrans Midstream common stock, prior to paying the quarterly dividends payable to the Equitrans Midstream Preferred Shares, including any previously accrued and unpaid dividends.

Each holder of the Equitrans Midstream Preferred Shares may elect to convert all or any portion of the Equitrans Midstream Preferred Shares owned by it into Equitrans Midstream common stock initially on a one-for-one basis, subject to certain anti-dilution adjustments and an adjustment for any dividends that have accrued but not been paid when due and partial period dividends (referred to as the conversion rate), at any time (but not more often than once per fiscal quarter) after April 10, 2021 (or immediately prior to a liquidation, dissolution or winding up of the Company), provided that any conversion involves an aggregate number of Equitrans Midstream Preferred Shares of at least $20.0 million (calculated based on the closing price of Equitrans Midstream common stock on the trading day preceding notice of the conversion) or such lesser amount if such conversion relates to all of a holder’s remaining Equitrans Midstream Preferred Shares or if such conversion is approved by the Company's Board of Directors (Board).
So long as the holders of the Equitrans Midstream Preferred Shares have not elected to convert all of their Equitrans Midstream Preferred Shares into Equitrans Midstream common stock, the Company may elect to convert all of the Equitrans Midstream Preferred Shares into Equitrans Midstream common stock, at the then-applicable conversion rate, at any time after April 10, 2021, if (i) the shares of Equitrans Midstream common stock are listed for, or admitted to, trading on a national securities exchange, (ii) the closing price per share of Equitrans Midstream common stock on the national securities exchange on which the shares of Equitrans Midstream common stock are listed for, or admitted to, trading exceeds $27.99 for the 20 consecutive trading days immediately preceding notice of the conversion, (iii) the average daily trading volume of the Equitrans Midstream common stock on the national securities exchange on which the shares of Equitrans Midstream common stock are listed for, or admitted to, trading exceeds 1,000,000 shares (subject to certain adjustments) of Equitrans Midstream common stock for the 20 consecutive trading days immediately preceding notice of the conversion, (iv) the Company has an effective registration statement on file with the SEC covering resales of the shares of Equitrans Midstream common stock to be received by such holders upon any such conversion and (v) the Company has paid all prior accumulated and unpaid dividends in cash in full to the holders.

Upon certain events involving a Change of Control (as defined in the Restated Articles) in which more than 90% of the consideration payable to the Company, or to the holders of Equitrans Midstream common stock, is payable in cash, the Equitrans Midstream Preferred Shares will automatically convert into Equitrans Midstream common stock at a conversion ratio equal to the greater of (i) the quotient of (a) the sum of (x) $19.99 (such price, the Equitrans Midstream Preferred Share Issue
13

Price) plus (y) any accrued and unpaid dividends as of such date, including any partial period dividends, with respect to the Equitrans Midstream Preferred Shares, divided by (b) the Equitrans Midstream Preferred Share Issue Price and (ii) the quotient of (a) the sum of (x)(1) the Equitrans Midstream Preferred Share Issue Price multiplied by (2) 110% plus (y) any accrued and unpaid dividends on such date, including any partial period dividends with respect to the Equitrans Midstream Preferred Shares, divided by (b) the volume weighted average price of the shares of Equitrans Midstream common stock for the 30-day period ending immediately prior to the execution of definitive documentation relating to the Change of Control.

In connection with other Change of Control events that do not satisfy the 90% cash consideration threshold described above, in addition to certain other conditions, each holder of Equitrans Midstream Preferred Shares may elect to (i) convert all, but not less than all, of its Equitrans Midstream Preferred Shares into Equitrans Midstream common stock at the then-applicable conversion rate, (ii) if the Company is not the surviving entity (or if the Company is the surviving entity, but Equitrans Midstream common stock will cease to be listed), require the Company to use commercially reasonable efforts to cause the surviving entity in any such transaction to deliver, in exchange for such holder's Equitrans Midstream Preferred Shares, a substantially equivalent security that has rights, preferences and privileges substantially equivalent to the Equitrans Midstream Preferred Shares (or if the Company is unable to cause such substantially equivalent securities to be issued, to exercise the option described in clause (i) or (iv) hereof or elect to convert such Equitrans Midstream Preferred Shares at a conversion ratio reflecting a multiple of invested capital), (iii) if the Company is the surviving entity, continue to hold the Equitrans Midstream Preferred Shares or (iv) require the Company to redeem the Equitrans Midstream Preferred Shares at a price per share equal to 101% of the Equitrans Midstream Preferred Share Issue Price, plus accrued and unpaid dividends, including any partial period dividends, on the applicable Equitrans Midstream Preferred Shares as of such date, which redemption price may be payable in cash, Equitrans Midstream common stock or a combination thereof at the election of the Board (and, if payable in Equitrans Midstream common stock, such Equitrans Midstream common stock will be issued at 95% of the volume-weighted average price of Equitrans Midstream common stock for the 20-day period ending on the fifth trading day immediately preceding the consummation of the Change of Control). Any holder of Equitrans Midstream Preferred Shares that requires the Company to redeem its Equitrans Midstream Preferred Shares pursuant to clause (iv) above will have the right to withdraw such election with respect to all, but not less than all, of its Equitrans Midstream Preferred Shares at any time prior to the fifth trading day immediately preceding the consummation of the Change of Control and instead elect to be treated in accordance with any of clauses (i), (ii) or (iii) above.
At any time on or after January 1, 2024, the Company will have the right, subject to applicable law, to redeem the Equitrans Midstream Preferred Shares, in whole or in part, by paying cash for each Equitrans Midstream Preferred Share to be redeemed in an amount equal to the greater of (a) the sum of (i)(1) the Equitrans Midstream Preferred Share Issue Price multiplied by (2) 110%, plus (ii) any accrued and unpaid dividends, including partial period dividends, with respect to the Equitrans Midstream Preferred Shares as of such date and (b) the amount the holder of such Equitrans Midstream Preferred Share would receive if such holder had converted such Equitrans Midstream Preferred Share into shares of Equitrans Midstream common stock at the then-applicable conversion ratio and the Company liquidated immediately thereafter.
Pursuant to the terms of the Restructuring Agreement, in connection with the Restructuring Closing, the Company entered into a registration rights agreement with the Investors (the Registration Rights Agreement) pursuant to which, among other things, the Company gave the Investors certain rights to require the Company to file and maintain one or more registration statements with respect to the resale of the Equitrans Midstream Preferred Shares and the shares of Equitrans Midstream common stock that are issuable upon conversion of the Equitrans Midstream Preferred Shares, and certain Investors have the right to require the Company to initiate underwritten offerings for the Equitrans Midstream Preferred Shares and the shares of Equitrans Midstream common stock that are issuable upon conversion of the Equitrans Midstream Preferred Shares.
The Equitrans Midstream Preferred Shares are considered redeemable securities under GAAP due to the possibility of redemption outside the Company’s control. They are therefore presented as temporary equity in the mezzanine equity section of the Company’s consolidated balance sheets and are not considered to be a component of shareholders’ equity on the consolidated balance sheets. The Equitrans Midstream Preferred Shares were recorded at fair value as of the date of issuance, and income allocations increase the carrying value and declared dividends decrease the carrying value of the Equitrans Midstream Preferred Shares. As the Equitrans Midstream Preferred Shares are not currently redeemable and not probable of becoming redeemable, adjustment to the initial carrying amount is not necessary and would only be required if it becomes probable that the Equitrans Midstream Preferred Shares would become redeemable.
3.     Impairments of Long-Lived Assets
Goodwill. On February 26, 2020 (the EQT Global GGA Effective Date), the Company (through EQM) entered into a Gas Gathering and Compression Agreement (as amended, the EQT Global GGA) with EQT for the provision of certain gas gathering services to EQT in the Marcellus and Utica Shales of Pennsylvania and West Virginia (as further discussed in Note 5). Prior to the EQT Global GGA Effective Date, the Company operated 3 reportable operating segments and 7
14

reporting units, which are one level below the operating segment level and are generally based on how segment management reviews the Company's operating results. Commencing with the EQT Global GGA Effective Date, the Company reduced its reporting units from 7 to 6 and maintained its 3 reportable operating segments. As of the EQT Global GGA Effective Date, the only reporting unit to which the Company had goodwill recorded related to the Pennsylvania gathering assets acquired in connection with EQM's acquisition of Rice Midstream Partners LP and its general partner in July 2018 (RMP PA Gas Gathering reporting unit). As a result of the EQT Global GGA, the assets under, and operations associated with, the RMP PA Gas Gathering reporting unit and the reporting unit associated with the gas gathering and compression activities of EQM Gathering Opco, LLC, an indirect wholly owned subsidiary of the Company (EQM Opco reporting unit), were combined to service a collective minimum volume commitment (MVC) under the agreement. Therefore, effective on the EQT Global GGA Effective Date, the RMP PA Gas Gathering reporting unit was merged with and into the EQM Opco reporting unit, with the EQM Opco reporting unit surviving.
During the first quarter of 2020, the Company identified impairment indicators in the form of significant declines in the unit price of EQM common units and corresponding market capitalization. Management considered these declines as indicators that the fair value of the RMP PA Gas Gathering reporting unit may have been below its carrying amount, and the performance of an interim quantitative goodwill impairment assessment was required. Additionally, as a result of the combination of the RMP PA Gas Gathering reporting unit and the EQM Opco reporting unit, the Company tested both the RMP PA Gas Gathering and the merged EQM Opco reporting units for goodwill impairment. In estimating the fair value of the RMP PA Gas Gathering and the merged EQM Opco reporting units, the Company used a combination of the income approach and the market approach. The Company used the income approach’s discounted cash flow method, which applies significant inputs not observable in the public market (Level 3), including estimates and assumptions related to the use of an appropriate discount rate, future throughput volumes, operating costs, capital spending and changes in working capital. The Company used the market approach’s comparable company and reference transaction methods. The comparable company method evaluates the value of a company using metrics of other businesses of similar size and industry. The reference transaction method evaluates the value of a company based on pricing multiples derived from similar transactions entered into by similar companies.
As a result of the interim assessment, the Company determined that the fair values of the RMP PA Gas Gathering reporting unit and the merged EQM Opco reporting unit were greater than their respective carrying values. No impairment to goodwill was recorded during the three months ended March 31, 2020. The Company believes the estimates and assumptions used in estimating its reporting units’ fair values are reasonable and appropriate; however, different assumptions and estimates could materially affect the calculated fair values of the RMP PA Gas Gathering reporting unit and the merged EQM Opco reporting unit and the resulting conclusions on impairment of goodwill, which could materially affect the Company’s results of operations and financial position. Additionally, actual results could differ from these estimates and assumptions may not be realized.
As of March 31, 2021, the Company's goodwill balance was associated entirely with the EQM Opco reporting unit. During the three months ended March 31, 2021, no impairment indicators were identified that would indicate, in management's judgment, it is more likely than not that the fair value of the EQM Opco reporting unit was less than its carrying value. However, the EQM Opco reporting unit is susceptible to impairment risk from future adverse market or economic conditions and company-specific qualitative factors or other adverse factors such as unexpected future production curtailments by the Company's customers that have contracts with volumetric-based fees. Any such adverse changes in the future could reduce the underlying cash flows used to estimate fair value and could result in a decline in fair value that could trigger future impairment charges relating to the EQM Opco reporting unit.
Long-lived Assets. As of March 31, 2020, the Company performed a recoverability test of the Hornet Midstream Holdings, LLC (Hornet Midstream) long-lived assets due to decreased producer activity. As a result of the recoverability test, management determined that the carrying value of the Hornet Midstream long-lived assets (which consisted of gathering assets and customer-related intangible assets) was not recoverable under ASC 360, Impairment Testing: Long-Lived Assets Classified as Held and Used. During the first quarter of 2020, the Company estimated the fair value of the Hornet Midstream asset group and determined that the fair value was not in excess of the assets’ carrying value, which resulted in impairment charges of approximately $37.9 million to the gathering assets and approximately $17.7 million to the customer-related intangible assets both within the Company’s Gathering segment. The non-cash impairment charges were recognized during the first quarter of 2020 and are included in the impairments of long-lived assets line on the statements of consolidated comprehensive income.
During the three months ended March 31, 2021, there were no events or changes in circumstance identified that would indicate, in management's judgment, that the carrying value of the Company's long-lived assets may not be recoverable.
Equity Method Investment. During 2020, the MVP Joint Venture received certain adverse court rulings in the U.S. Fourth Circuit Court of Appeals as described in “Item 1. Legal Proceedings” of Part II of this Quarterly Report on Form 10-Q. As a result, the Company evaluated its equity method investment in the MVP Joint Venture for impairment during the fourth quarter
15

of 2020 and determined that the fair value of the investment continued to exceed the carrying value and, therefore, no impairment was necessary. The Company estimated the fair value of its investment in the MVP Joint Venture using an income approach that primarily considered probability-weighted scenarios of discounted future net cash flows based on the most recent estimate of total project costs and revenues as of December 31, 2020. These scenarios reflected assumptions and judgments regarding various future court decisions and regulatory authorizations and the impact that those decisions and authorizations may have on the timing and extent of the Company’s investment, including scenarios assuming the full resolution of permitting issues. The Company’s analysis took into account, among other things, growth expectations from additional compression expansion opportunities. The Company generally used an after-tax discount rate of 5.5% in the analysis derived based on a market participant approach. Based on the Company’s expectations for the MVP Joint Venture's projects, and taking into account, among other things, regulatory considerations, public support for the MVP project by the Chairman of the U.S. Senate Committee on Energy and Natural Resources, and other publicly available information, the Company assigned higher probabilities for scenarios under which the Company received all required legal and regulatory approvals and authorizations and certain compression expansion opportunities are realized. A low probability was assigned to the scenario under which the project is cancelled.
The Company evaluated its equity method investment in the MVP Joint Venture as of March 31, 2021, including the impact of recent legal and regulatory events, and determined that there was not an other-than-temporary decline in value. There is risk that the carrying value of the Company's investment in the MVP Joint Venture may be impaired in the future. There are ongoing legal and regulatory matters that must be resolved before each of the MVP and MVP Southgate projects can be completed. Assumptions and estimates utilized in assessing the Company’s investment in the MVP Joint Venture for impairment, including as of March 31, 2021, may change depending on the nature or timing of resolutions to these legal or regulatory matters or based on other relevant developments. Adverse changes in circumstances relevant to the likelihood of project completion could prompt the Company, in future assessments, to apply a lower probability of project completion. Such changes in assumptions or estimates (including probability) could have a material adverse effect on the fair value of the Company's investment in the MVP Joint Venture and potentially result in an impairment.
4.2.    Financial Information by Business Segment
The Company reports its operations in 3 segments that reflect its 3 lines of business of Gathering, Transmission and Water, which reflects the manner in which management evaluates the business for making operating decisions and assessing performance.
 Three Months Ended March 31,
 20212020
 (Thousands)
Revenues from customers:  
Gathering$250,076 $310,047 
Transmission111,419 106,615 
Water18,501 36,451 
Total operating revenues$379,996 $453,113 
Operating income:  
Gathering (a)
$139,854 $155,228 
Transmission81,488 78,434 
Water4,477 17,752 
Headquarters (b)
(239)(9,332)
Total operating income$225,580 $242,082 
Reconciliation of operating income to net income: 
Equity income (c)
$3 $54,072 
Other income (d)
7,599 4,163 
Loss on extinguishment of debt41,025 24,864 
Net interest expense95,144 66,754 
Income tax expense20,416 19,139 
Net income$76,597 $189,560 
16
Table of Contents


 Three Months Ended March 31,
 20222021
 (Thousands)
Revenues from customers:  
Gathering$219,790 $250,076 
Transmission110,795 111,419 
Water11,561 18,501 
Total operating revenues$342,146 $379,996 
Operating income (loss):  
Gathering$115,621 $139,854 
Transmission84,562 81,488 
Water(1,856)4,477 
Headquarters (a)
(389)(239)
Total operating income$197,938 $225,580 
Reconciliation of operating income to net income: 
Equity income (b)
$4 $3 
Other income, net (c)
6,348 7,599 
Loss on extinguishment of debt— (41,025)
Net interest expense(93,121)(95,144)
Income tax expense6,261 20,416 
Net income$104,908 $76,597 
(a)Impairments of long-lived assets of $55.6 million for the three months ended March 31, 2020 were included in Gathering operating income. See Note 3 for further information.
(b)Includes transaction costs and othercertain unallocated corporate expenses.
(c)(b)Equity income is included in the Transmission segment.
(d)(c)Includes unrealized gains on derivative instruments recorded in the Gathering segment.
March 31, 2021December 31, 2020March 31, 2022December 31, 2021
(Thousands) (Thousands)
Segment assets:Segment assets:  Segment assets:  
GatheringGathering$7,729,872 $7,739,836 Gathering$7,610,869 $7,638,877 
Transmission (a)
Transmission (a)
4,422,347 4,357,382 
Transmission (a)
2,798,661 2,769,097 
WaterWater174,803 185,802 Water148,875 151,151 
Total operating segmentsTotal operating segments12,327,022 12,283,020 Total operating segments10,558,405 10,559,125 
Headquarters, including cashHeadquarters, including cash461,825 442,832 Headquarters, including cash260,297 361,639 
Total assetsTotal assets$12,788,847 $12,725,852 Total assets$10,818,702 $10,920,764 
(a)The equity investment in the MVP Joint Venture is included in the Transmission segment.
 Three Months Ended March 31,
 20212020
 (Thousands)
Depreciation:  
Gathering$46,547 $40,440 
Transmission13,800 13,558 
Water8,175 7,116 
Headquarters96 234 
Total$68,618 $61,348 
Expenditures for segment assets:
Gathering (a)
$48,113 $111,454 
Transmission (b)
3,505 10,798 
Water4,807 3,476 
Headquarters1,157 1,876 
Total (c)
$57,582 $127,604 
10
Table of Contents


 Three Months Ended March 31,
 20222021
 (Thousands)
Depreciation:  
Gathering$48,255 $46,547 
Transmission13,894 13,800 
Water4,517 8,175 
Headquarters377 96 
Total$67,043 $68,618 
Capital expenditures:
Gathering (a)
$53,147 $48,113 
Transmission (b)
4,226 3,505 
Water9,565 4,807 
Headquarters12 1,157 
Total (c)
$66,950 $57,582 
(a)Includes approximately $1.7 million and $12.5 million of capital expenditures related to the noncontrolling interest in Eureka Midstream Holdings, LLC (Eureka Midstream) of approximately $3.0 million and $1.7 million for the three months ended March 31, 20212022 and 2020,2021, respectively.
(b)Transmission capital expenditures do not include aggregate capital contributions made to the MVP Joint Venture for the MVP and MVP Southgate projects of $10.7approximately $72.5 million and $45.2$10.7 million for the three months ended March 31, 20212022 and 2020,2021, respectively.
(c)The Company accrues capital expenditures when the work has been completed but the associated bills have not yet been paid. Accrued capital expenditures are excluded from the statements of consolidated cash flows until they are paid. The net impact of non-cash capital expenditures, including the effect of accrued capital expenditures, transfers to/from inventory as assets are completed/assigned to a project and capitalized share-based compensation costs, was $3.7$4.3 million and $24.8$3.7 million for the three months ended March 31, 20212022 and 2020,2021, respectively.
5.3.    Revenue from Contracts with Customers
For the three months ended March 31, 20212022 and 2020,2021, all revenues recognized on the Company's statements of consolidated comprehensive income are from contracts with customers. As of March 31, 20212022 and December 31, 2020,2021, all receivables recorded on the Company's consolidated balance sheets represented performance obligations that have been satisfied and for which an unconditional right to consideration exists.

Summary of disaggregated revenues. The tables below provide disaggregated revenue information by business segment.
Three Months Ended March 31, 2021Three Months Ended March 31, 2022
GatheringTransmissionWaterTotalGatheringTransmissionWaterTotal
(Thousands)(Thousands)
Firm reservation fee revenues (a)
Firm reservation fee revenues (a)
$148,192 $101,389 $1,844 $251,425 
Firm reservation fee revenues (a)
$132,597 $102,870 $5,752 $241,219 
Volumetric-based fee revenues (b)
Volumetric-based fee revenues (b)
101,884 10,030 16,657 128,571 
Volumetric-based fee revenues (b)
87,193 7,925 5,809 100,927 
Total operating revenuesTotal operating revenues$250,076 $111,419 $18,501 $379,996 Total operating revenues$219,790 $110,795 $11,561 $342,146 
Three Months Ended March 31, 2020Three Months Ended March 31, 2021
GatheringTransmissionWaterTotalGatheringTransmissionWaterTotal
(Thousands)(Thousands)
Firm reservation fee revenues (a)
Firm reservation fee revenues (a)
$152,079 $99,597 $12,776 $264,452 
Firm reservation fee revenues (a)
$148,192 $101,389 $1,844 $251,425 
Volumetric-based fee revenues(b)Volumetric-based fee revenues(b)157,968 7,018 23,675 188,661 Volumetric-based fee revenues(b)101,884 10,030 16,657 128,571 
Total operating revenuesTotal operating revenues$310,047 $106,615 $36,451 $453,113 Total operating revenues$250,076 $111,419 $18,501 $379,996 

(a) For the three months ended March 31, 2022, firm reservation fee revenues associated with Gathering included approximately $2.7 million of MVC unbilled revenues. For the three months ended March 31, 2021, firm reservation fee revenues associated with Gathering and Water included approximately $3.2 million and $0.5 million respectively, of MVC unbilled revenues. For the three months ended March 31, 2020, firm reservation fee revenues associated with Gathering and Water included approximately $6.3 million and $5.0 million, respectively, of MVC unbilled revenues.revenue, respectively.
(b) For the three months ended March 31, 2021, volumetric-based fee revenues associated with Gathering included approximately $6.2 million of unbilled revenues.
Contract assets. The Company recognizes contract assets primarily in instances where billing occurs subsequent to revenue recognition and the Company's right to invoice the customer is conditioned on something other than the passage of time. The Company's contract assets primarily consist of revenue recognized under contracts containing MVCs (whereby management has concluded (i) it is probable there will be a MVC deficiency payment at the end of the then-current MVC period, which is typically the period beginning at the inception of such contracts through the successive twelve month periods after that date, and (ii) that a significant reversal of revenue recognized currently for the future MVC deficiency payment will not occur), as well as certain other contractual commitments. As a result, the Company's contract assets related to the Company's future MVC deficiency payments are generally expected to be collected within the next twelve months and are primarily included in other current assets in the Company's consolidated balance sheets until such time as the MVC deficiency payments are invoiced to the customer.

The following table presents changes in the Company's unbilled revenue balance during the three months ended March 31, 20212022 and 2020:
Unbilled Revenue
20212020
(Thousands)
Balance as of beginning of period$18,618 $0 
  Revenue recognized in excess of amounts invoiced (a)
10,188 11,305 
  Minimum volume commitments invoiced (b)
(16,931)0 
Balance as of end of period$11,875 $11,305 
2021:
Unbilled Revenue
20222021
(Thousands)
Balance as of beginning of period$16,772 $18,618 
  Revenue recognized in excess of amounts invoiced (a)
4,692 10,188 
  Minimum volume commitments invoiced (b)
(14,884)(16,931)
  Amortization (c)
(110)— 
Balance as of end of period$6,470 $11,875 
(a)Primarily includes revenues associated with unbilled MVCs that are generally included in firm reservation fee revenues within the Gathering and Water segments, as described insegments. During the Summary of Disaggregated Revenues table above, andthree months ended March 31, 2021, also includes other contractual commitments of approximately $6.2 million.
(b)Unbilled revenues are transferred to accounts receivable once the Company has an unconditional right to consideration from the customer.
(c)Amortization of capitalized contract costs paid to customers over the expected life of the agreement.
Contract liabilities. As of March 31, 2021 and December 31, 2020, theThe Company's contract liabilities consisted of deferred revenue primarily associated with the EQT Global GGA, including advance payments from EQT associated with the Rate Relief Shares (as defined below) acquired by the Company as consideration for certain commercial terms and the initial fair value of the Henry Hub cash bonus payment provision (as defined below). The contractGGA. Contract liabilities are classified as current or non-current according to when such amounts are expected to be recognized. As of March 31, 2021 and December 31, 2020, the2022, total contract liabilities were $909.1 million, of which $1.1 million was classified as current and recorded in accrued liabilities and $908.0 million was classified as non-current as noneand recorded in contract liability on the Company's consolidated balance sheet. As of the deferred revenue is expected to be recognized in revenue during the next five years.
Contracts requiring advance payments and the recognition ofDecember 31, 2021, total contract liabilities are evaluated to determine whether the advance payments provide the Company with a significant financing benefit. This determination requires significant judgmentwere $822.4 million, of which $1.1 million was classified as current and is basedrecorded in accrued liabilities and $821.3 million was classified as non-current and recorded in contract liability on the combined effect of the expected length of time between when the Company transfers the promised good or service to the customer and when the customer pays for those goods or services and the prevailing interest rates.Company's consolidated balance sheet.
The following table presents changes in the Company's contract liability balances during the three months ended March 31, 20212022 and 2020:2021:
Contract LiabilityContract Liability
2021202020222021
(Thousands)(Thousands)
Balance as of beginning of periodBalance as of beginning of period$398,750 $0 Balance as of beginning of period$822,416 $398,750 
Amounts recorded during the period (a)
Amounts recorded during the period (a)
72,019 173,005 
Amounts recorded during the period (a)
86,920 72,019 
Amounts transferred during the period (b)
Amounts transferred during the period (b)
0 0 
Amounts transferred during the period (b)
(268)$— 
Balance as of end of periodBalance as of end of period$470,769 $173,005 Balance as of end of period$909,068 $470,769 
(a)Includes deferred billed revenue during the three months ended March 31, 2022 and 2021 primarily associated with the EQT Global GGA.
(b)Deferred revenues are recognized as revenue upon satisfaction of the Company's performance obligation to the customer.

Summary of remaining performance obligations. The following table summarizes the estimated transaction price allocated to the Company's remaining performance obligations under all contracts with firm reservation fees, and MVCs and/or ARCs as of March 31, 20212022 that the Company will invoice or transfer from contract liabilities and recognize in future periods.
2021(a)
2022202320242025ThereafterTotal
2022(a)
2023202420252026ThereafterTotal
(Thousands) (Thousands)
Gathering firm reservation feesGathering firm reservation fees$119,725 $158,728 $158,635 $157,133 $149,626 $1,193,074 $1,936,921 Gathering firm reservation fees$65,980 $105,804 $157,621 $150,060 $141,227 $1,277,907 $1,898,599 
Gathering revenues supported by MVCsGathering revenues supported by MVCs381,065 562,069 601,269 561,891 563,413 4,811,434 7,481,141 Gathering revenues supported by MVCs334,378 457,843 429,233 448,262 459,424 3,477,205 5,606,345 
Transmission firm reservation feesTransmission firm reservation fees261,713 386,931 346,599 284,527 248,850 2,391,273 3,919,893 Transmission firm reservation fees260,613 359,260 376,572 363,629 358,800 3,228,443 4,947,317 
Water revenues supported by MVCs1,500 35,000 60,000 60,000 60,000 85,000 301,500 
Water revenues supported by ARCsWater revenues supported by ARCs28,125 37,500 37,500 37,500 37,500 193,750 371,875 
Total (b)
Total (b)
$764,003 $1,142,728 $1,166,503 $1,063,551 $1,021,889 $8,480,781 $13,639,455 
Total (b)
$689,096 $960,407 $1,000,926 $999,451 $996,951 $8,177,305 $12,824,136 
(a)    April 1, 20212022 through December 31, 2021.2022.
(b)    Includes assumptions regarding timing for placing certain projects in-service, including the MVP in summer 2022. Delaysprojects in-service. Such assumptions may not be realized and delays in the in-service dates for projects have substantially altered, and additional delays may further substantially alter, the remaining performance obligations for certain contracts with firm reservation fees, MVCs and/or MVCs. See Note 12 toARCs. The MVP Joint Venture is accounted for as an equity investment and those amounts are not included in the consolidated financial statements for a discussion of the targeted timing of the in-service date of the MVP.table above.
Based on total projected contractual revenues, including projected contractual revenues from future capacity expected from expansion projects that are not yet fully constructed for which the Company has executed firm contracts, the Company's firm gathering contracts and firm transmission and storage contracts had weighted average remaining terms of approximately 1514 years and 1413 years, respectively, as of March 31, 2021.
EQT Global GGA. On the EQT Global GGA Effective Date, the Company entered into the EQT Global GGA with EQT for the provision by the Company of certain gas gathering services to EQT in the Marcellus and Utica Shales of Pennsylvania and West Virginia. Pursuant to the EQT Global GGA, EQT is subject to an initial annual MVC of 3.0 Bcf per day that gradually steps up to 4.0 Bcf per day for several years following the in-service date of the MVP. The EQT Global GGA runs from the EQT Global GGA Effective Date through December 31, 2035, and will renew annually thereafter unless terminated by EQT or the Company pursuant to its terms. Pursuant to the EQT Global GGA, the Company has certain obligations to build connections to connect EQT wells to the Company's gathering system, which are subject to geographical limitations in relation to the dedicated area in Pennsylvania and West Virginia, as well as the distance of such connections to the Company's then-existing gathering system. Management has estimated the total consideration expected to be received over the life of the EQT Global GGA, including gathering MVC revenue with a declining rate structure, the fair value of the Rate Relief Shares (as defined below) and the initial fair value of the Henry Hub cash bonus payment provision. The total consideration is allocated proportionally to the performance obligation under the contract, which is to provide daily MVC capacity over the life of the contract, in order to recognize revenue in accordance with ASC 606, Revenue from Contracts with Customers. The performance
obligations will be satisfied during the life of the contract based on a units of production methodology for the daily MVC capacity provided to EQT. Due to the declining rate structure, there will be periods during which the billable gathering MVC revenue will exceed the allocated consideration to the performance obligation, which will result in billable gathering MVC revenue being deferred to the contract liability. The deferred consideration amounts are deferred until recognized in revenue when the associated performance obligation has been satisfied and are classified as current or non-current according to when such amounts are expected to be recognized. In addition to the estimated total consideration allocated to the daily MVC, the EQT Global GGA includes other fees based on variable or volumetric-based services that will be recognized in the period the services are provided. The Company applied judgment in determining the balance sheet classification of the elements of the EQT Global GGA and Share Purchase Agreements (defined below) under the applicable accounting guidance.
The EQT Global GGA provides for potential cash bonus payments payable by EQT to the Company during the period beginning on the first day of the calendar quarter in which the MVP in-service date occurs through the earlier of the twelfth calendar quarter from that point or the calendar quarter ending December 31, 2024 (the Henry Hub cash bonus payment provision). The potential cash bonus payments are conditioned upon the quarterly average of certain Henry Hub natural gas prices exceeding certain price thresholds. The Henry Hub cash bonus payment provision meets the definition of an embedded derivative that was required to be bifurcated from the host contract and accounted for separately in accordance with ASC 815, Derivatives and Hedging. The embedded derivative was recorded as a derivative asset at its estimated fair value at inception of approximately $51.5 million and as part of the contract liability to be included in the total consideration to be allocated to the performance obligation under ASC 606. Subsequent changes to the fair value of the derivative instrument through the end of the contract are recognized in other income on the Company's statements of consolidated comprehensive income.

The gathering MVC fees payable by EQT to the Company set forth in the EQT Global GGA are subject to potential reductions for certain contract years as set forth in the EQT Global GGA, conditioned upon the in-service date of the MVP, which provide for estimated aggregate fee relief of approximately $270 million in the first year after the in-service date of the MVP, approximately $230 million in the second year after the in-service date of the MVP and approximately $35 million in the third year after the in-service date of the MVP. In addition, commencing on January 1, 2022 and continuing until the earlier of (i) the in-service of the MVP and (ii) December 31, 2022, EQT will have an option to forgo approximately $145 million of the gathering fee relief in the first year after the MVP in-service date and approximately $90 million of the gathering fee relief in the second year after the MVP in-service date in exchange for a cash payment from the Company to EQT in the amount of approximately $196 million (the EQT Cash Option). As consideration for the additional rate relief subject to the EQT Cash Option, the Company purchased shares of its common stock (see Rate Relief Shares discussed and defined below) from EQT. The consideration received for future contractual rate relief associated with the Rate Relief Shares was recorded at a fair value of approximately $121.5 million as a contract liability in accordance with ASC 606 and will be recognized as revenue over the life of the contract.

Water Services Letter Agreement. On February 26, 2020, the Company entered into a letter agreement with EQT, pursuant to which EQT agreed to utilize the Company for the provision of water services in Pennsylvania under existing water services agreements and new water services agreements if negotiated between the parties (such letter agreement, the Water Services Letter Agreement). The Water Services Letter Agreement is effective as of the first day of the first month following the MVP in-service date and will expire on the fifth anniversary of such date. During each year of the Water Services Letter Agreement, EQT agreed that fixed MVC fees payable to the Company for water services incurred on a volumetric basis, provided in accordance with existing agreements and new agreements entered into between the parties pursuant to the Water Services Letter Agreement (or the related agreements), will be equal to or greater than $60 million per year.
Share Purchase Agreements. On February 26, 2020, the Company entered into 2 share purchase agreements (the Share Purchase Agreements) with EQT, pursuant to which the Company agreed to (i) purchase 4,769,496 shares of Equitrans Midstream common stock (the Cash Shares) from EQT in exchange for approximately $46 million in cash, (ii) purchase 20,530,256 shares of Equitrans Midstream common stock (the Rate Relief Shares and, together with the Cash Shares, the Share Purchases) from EQT in exchange for a promissory note in the aggregate principal amount of approximately $196 million (which EQT subsequently assigned to EQM as consideration for certain commercial terms under the EQT Global GGA), and (iii) pay EQT cash in the amount of approximately $7 million (the Cash Amount). On March 5, 2020, the Company completed the Share Purchases and paid the Cash Amount. The Company used proceeds from the EQM Credit Facility (defined in Note 8) to fund the purchase of the Cash Shares and to pay the Cash Amount in addition to other uses of proceeds. After the closing of the Share Purchases, the Company retired the Cash Shares and the Rate Relief Shares. Additionally, the Company recorded a $17.2 million deferred tax liability in conjunction with the Rate Relief Shares. On September 29, 2020, the Company made a prepayment to EQM of all principal, interest, fees and other obligations outstanding under the promissory note EQT assigned to EQM and the promissory note was terminated.2022.
6.4.    Related Party Transactions
17

As of March 31, 2021,2022, EQT remainedwas a related party of the Company due to its ownership of 25,296,02622,796,026 shares of Equitrans Midstream common stock, which represented an approximately 5.8%5.3% ownership interest in the Company, excluding the impact of the Equitrans Midstream Preferred Shares. In the ordinary course of business, the Company engaged, and continues to engage, as applicable, in transactions with EQT and its affiliates, including, but not limited to, entering into new or amending existing gathering agreements, transportation service and precedent agreements, storage agreements and water services agreements. As of May 3, 2022, EQT is no longer a related party of the Company.
The following table summarizes the Company's related party transactions.
Three Months Ended March 31,
20212020
(Thousands)
Operating revenues$224,957 $303,800 
Equity income3 54,072 
Interest income from the preferred interest in EQT Energy Supply, LLC (the Preferred Interest)1,469 1,539 
Capital contributions to the MVP Joint Venture(10,723)(45,150)
Principal payments received on the Preferred Interest1,277 1,225 

Three Months Ended March 31,
20222021
(Thousands)
Operating revenues$198,386 $224,957 
Equity income4 3 
Interest income from the Preferred Interest1,395 1,469 
Capital contributions to the MVP Joint Venture(72,537)(10,723)
Principal payments received on the Preferred Interest1,351 1,277 
The following table summarizes the Company's related party receivables and payables.
March 31, 2021December 31, 2020March 31, 2022December 31, 2021
(Thousands)(Thousands)
Accounts receivableAccounts receivable$181,051 $199,674 Accounts receivable$168,114 $190,410 
Contract assetContract asset500 2,207 Contract asset— 2,246 
Investment in unconsolidated entityInvestment in unconsolidated entity2,870,219 2,796,316 Investment in unconsolidated entity1,278,992 1,239,039 
Preferred InterestPreferred Interest103,778 105,056 Preferred Interest98,487 99,838 
Capital contributions payable to the MVP Joint VentureCapital contributions payable to the MVP Joint Venture72,995 10,723 Capital contributions payable to the MVP Joint Venture39,159 72,188 
Contract liabilityContract liability905,578 818,658 
Credit Letter Agreement. On February 26, 2020, in connection with the execution of the EQT Global GGA, the Company and EQT entered into a letter agreement (the Credit Letter Agreement) pursuant to which, among other things, (a) the Company agreed to relieve certain credit posting requirements for EQT, in an amount up to approximately $250 million, under its commercial agreements with EQT, subject to EQT maintaining a minimum credit rating from two of three rating agencies of (i) Ba3 with Moody’s Investors Service (Moody's), (ii) BB- with S&P Global Ratings (S&P) and (iii) BB- with Fitch Investor Services (Fitch) and (b) the Company agreed to use commercially reasonable good faith efforts to negotiate similar credit support arrangements for EQT in respect of its commitments to the MVP Joint Venture.
EQT Global GGA.
11
See Note 5 for further detail.Table of Contents
Water Services Letter Agreement. See Note 5 for further detail.
Share Purchase Agreements. See Note 5 for further detail.
7.5.    Investment in Unconsolidated Entity
The MVP Joint Venture is constructing the Mountain Valley Pipeline (MVP), an estimated 300-mile natural gas interstate pipeline that willis designed to span from northern West Virginia to southern Virginia. The Company will operate the MVP and owned a 46.2%47.0% interest in the MVP project as of March 31, 2021.2022. On November 4, 2019, Consolidated Edison, Inc. (Con Edison) exercised an option to cap its investment in the construction of the MVP project at approximately $530 million (excluding AFUDC). The Company and NextEra Energy, Inc. are obligated to, and RGC Resources, Inc., another member of the MVP Joint Venture owning an interest in the MVP project, has opted to, fund the shortfall in Con Edison's capital contributions, on a pro rata basis. Such funding by the Company and funding by other members has and will correspondingly increase the Company's and such other funding members' respective interests in the MVP project and decrease Con Edison's interest in the MVP project. As a result, based on the project'sCompany's targeted cost for the project of approximately $6.2$6.6 billion (excluding AFUDC), the Company's equity ownership in the
18
Table of Contents

MVP project will progressively increase from approximately 46.2%47.0% to approximately 47.8%48.1%. The MVP Joint Venture is a variable interest entity because it has insufficient equity to finance its activities during the construction stage of the project. The Company is not the primary beneficiary of the MVP Joint Venture because the Company does not have the power to direct the activities that most significantly affect the MVP Joint Venture's economic performance. Certain business decisions, such as decisions to make distributions of cash, require a greater than 66 2/3% ownership interest approval, and no one member owns more than a 66 2/3% interest.
In April 2018, the MVP Joint Venture announced the MVP Southgate project, which is a proposed 75-mile interstate pipeline that willis contemplated to extend from the MVP at Pittsylvania County, Virginia to new delivery points in Rockingham and Alamance Counties, North Carolina. The Company willis expected to operate the MVP Southgate pipeline and owned a 47.2% interest in the MVP Southgate project as of March 31, 2022. The MVP Joint Venture continues to evaluate the MVP Southgate project, including engaging in discussions with the project shipper, Dominion Energy North Carolina, regarding options with respect to the project, including potentially refining the project’s design and timing in lieu of pursuing the project as originally contemplated. Dominion Energy North Carolina’s obligations under the precedent agreement in support of the original project are subject to certain conditions, including that the MVP Joint Venture complete construction of the project facilities by June 1, 2022, which deadline is subject to extension by virtue of previously declared events of force majeure. The Company is unable to predict the results of the discussions between the MVP Joint Venture and Dominion Energy North Carolina, including any potential modifications to the project, or ultimate undertaking or completion of the project.
In the fourth quarter of 2021, the Company incurred an other-than-temporary decline in value in its equity investment in the MVP Joint Venture, primarily due to unfavorable decisions by the U.S. Fourth Circuit Court of Appeals that vacated and remanded key authorizations, that resulted in a pre-tax impairment charge of $1.9 billion. As a result of the impairment, the carrying value of the Company's equity investment in the MVP Joint Venture was reduced to $1.2 billion as of December 31, 2021. There is risk that the Company's equity investment in the MVP Joint Venture may be further impaired in the future due to ongoing (and potentially future) legal and regulatory matters, as well as potential macroeconomic factors, including market fluctuations, changes in interest rates, cost increases and other unanticipated events.
In March 2021,2022, the MVP Joint Venture issued a capital call notice for the funding of the MVP project to MVP Holdco, LLC (MVP Holdco), a wholly owned subsidiary of the Company, for $72.9$39.1 million, of which $14.6 million and $25.8$18.2 million was paid in April 2021May 2022, and May 2021, respectively, and $32.5$20.9 million is expected to be paid in June 2021.2022. The capital contributions payable and the corresponding increase to the investment balance are reflected on the consolidated balance sheet as of March 31, 2021.2022.
Pursuant to the MVP Joint Venture's limited liability company agreement, MVP Holdco is obligated to provide performance assurances, which may take the form of a guarantee from EQM (provided that EQM's debt is rated as investment grade in accordance with the requirements of the MVP Joint Venture's limited liability company agreement), a letter of credit or cash collateral, in favor of the MVP Joint Venture to provide assurance as to the funding of MVP Holdco's proportionate share of the construction budget for the MVP project.
In addition, pursuant to the MVP Joint Venture's limited liability company agreement, MVP Holdco is obligated to provide performance assurances in respect of MVP Southgate, which performance assurances may take the form of a guarantee from EQM (provided that EQM's debt is rated as investment grade in accordance with the requirements of the MVP Joint Venture's limited liability company agreement), a letter of credit or cash collateral.
As a result ofBased on EQM’s credit rating downgrades in the first quarter of 2020,levels, EQM has delivered replacement credit support to the MVP Joint Venture in the form of letters of credit, which, in the amountscase of approximately $220.2 million and $14.2 million with respect to the MVP project and MVP Southgate project, respectively. In connection with delivering such letters of credit as replacement performance assurances, EQM's prior performance guarantees associated with the MVP and MVP Southgate projects were terminated. As of March 31, 2021, the letters of credit with respect to the MVP project and MVP Southgate project were in the amounts of approximately $231.2 million and $14.2 million, respectively. As of May 4, 2021, based on the targeted project cost, MVP Holdco's obligation to deliver a replacement letter of credit with respect to the MVP project wasis in the amount of approximately $273.1 million.$219.7 million and, in the case of the MVP Southgate, is in the amount of approximately $14.2 million, in each case, as of March 31, 2022. The amount of each of the letters of credit is subject to adjustment based upon the applicable project's construction budget. Upon the FERC’s initial release to begin construction of the MVP Southgate project, the Company’s currentCompany's then-current letter of credit to support MVP Southgate will be terminated, and the Company will be obligated to deliver a new letter of credit (or provide another allowable
12
Table of Contents

form of performance assurance) in an amount equal to 33% of MVP Holdco’s proportionate share of the remaining capital obligations for the MVP Southgate project under the applicable construction budget.
As of March 31, 2021, the Company's maximum financial statement exposure related to the MVP Joint Venture was approximately $3,043 million, which consisted of the investment in unconsolidated entity balance on the consolidated balance sheet as of March 31, 2021, net of capital contributions payable, and the letters of credit outstanding under the Amended EQM Credit Facility. As of May 4, 2021, in conjunction with MVP Holdco's obligation to deliver a replacement letter of credit with respect to the MVP project, the Company's maximum financial statement exposure related to the MVP Joint Venture was approximately $3,125 million.
The following tables summarize the unaudited condensed consolidated financial statements of the MVP Joint Venture in relation to the MVP project.
19
Table of Contents

Condensed Consolidated Balance Sheets
March 31, 2021December 31, 2020March 31, 2022December 31, 2021
(Thousands)(Thousands)
Current assetsCurrent assets$108,467 $146,054 Current assets$82,570 $148,820 
Non-current assetsNon-current assets5,938,196 5,848,298 Non-current assets6,515,268 6,432,288 
Total assetsTotal assets$6,046,663 $5,994,352 Total assets$6,597,838 $6,581,108 
Current liabilitiesCurrent liabilities$185,003 $217,086 Current liabilities$146,148 $160,331 
EquityEquity5,861,660 5,777,266 Equity6,451,690 6,420,777 
Total liabilities and equityTotal liabilities and equity$6,046,663 $5,994,352 Total liabilities and equity$6,597,838 $6,581,108 
Condensed Statements of Consolidated Operations
 Three Months Ended March 31,
 20212020
(Thousands)
Environmental remediation reserve$0 $(265)
Other income6 231 
Net interest income0 35,326 
AFUDC — equity0 82,428 
Net income$6 $117,720 
 Three Months Ended March 31,
 20222021
(Thousands)
Operating expenses$(1)$— 
Other income10 6 
Net income$9 $6 
8.6.    Debt
Equitrans Midstream Term Loan Facility. In December 2018, Equitrans Midstream entered into a term loan credit agreement (as amended in May 2019, the ETRN Term Loan Credit Agreement) that provided for a senior secured term loan facility in an aggregate principal amount of $600 million (the ETRN Term Loans). On March 3, 2020, EQM drew $650.0 million under the EQM Credit Facility and transferred such funds to the Company, pursuant to a senior unsecured term loan agreement with the Company. The Company utilized a portion of such funds to pay off all of the amounts outstanding under the ETRN Term Loans and the ETRN Term Loan Credit Agreement was terminated. As a result, the Company wrote off $24.4 million of unamortized discount and financing costs related to the ETRN Term Loan Credit Agreement. The write off charge is included in the loss on extinguishment of debt line on the statements of consolidated comprehensive income. On September 29, 2020, the Company made a prepayment to EQM of all principal, interest, fees and other obligations outstanding under the senior unsecured term loan agreement and terminated the agreement. During the period from January 1, 2020 to March 3, 2020, the weighted average annual interest rate was approximately 6.2%.
Equitrans Midstream Credit Facility. In October 2018, Equitrans Midstream entered into a senior secured revolving credit facility agreement that provided for $100 million in borrowing capacity (the Equitrans Midstream Credit Facility). Equitrans Midstream amended the Equitrans Midstream Credit Facility on December 31, 2018 to, among other things, permit the incurrence of the borrowings under the ETRN Term Loan Credit Agreement. The Equitrans Midstream Credit Facility, which was available for general corporate purposes and to fund ongoing working capital requirements, was terminated on March 3, 2020 in conjunction with the Company's termination of the ETRN Term Loan Credit Agreement (see above). As a result, the Company wrote off $0.5 million of unamortized financing costs related to the Equitrans Midstream Credit Facility. The write off charge is included in the loss on extinguishment of debt line on the statements of consolidated comprehensive income. The Company had 0 borrowings and 0 letters of credit outstanding under the Equitrans Midstream Credit Facility during the period from January 1, 2020 to March 3, 2020. Commitment fees paid to maintain credit availability under the Equitrans Midstream Credit Facility were approximately $0.1 million for the period from January 1, 2020 to March 3, 2020.
Amended EQM Revolving Credit Facility. On OctoberAs of March 31, 2018, EQM amended and restated its unsecured revolving credit facility to increase2022, the borrowing capacity from $1Company had aggregate commitments available of $2.25 billion to $3 billion and extend the term to October 2023 (the EQM Credit Facility). On March 30, 2020, EQM entered into an amendment to the EQM Credit Facility (as amended, the Amended EQM Credit Facility) which, among other things, amended certain defined terms and negative covenants in the EQM Credit Facility.
The Amended EQM Credit Facility is available for general partnership purposes, including to purchase assets, to make investments, to fund working capital requirements and capital expenditures and to pay distributions. Subject to satisfaction of
20
Table of Contents

certain conditions, the Amended EQM Credit Facility has an accordion feature that allows EQM to increase the available borrowings under the facility by up to an additional $750 million. The Amended EQM Credit Facility has a sublimit of up to $250 million for same-day swing line advances and a sublimit of up to $400 million for letters of credit. In addition, EQM has the ability to request that one or more lenders make available term loans under the Amended EQM Credit Facility, subjectwhich is set to the satisfaction of certain conditions. The Company’s obligationsmature in respect of the revolving borrowings made under the Amended EQM Credit Facility are unsecured.October 2023. As of March 31, 2021, 0 term loans were2022, EQM had approximately $180 million of borrowings and $234.9 million of letters of credit outstanding under the Amended EQM Credit Facility. Such term loans would be secured by cash, qualifying investment grade securities or a combination thereof.
As of each of MarchDecember 31, 2021, and December 31, 2020, EQM had approximately $485$225 million of borrowings and $246$234.9 million of letters of credit outstanding under the Amended EQM Credit Facility. During the three months ended March 31, 2022, the maximum outstanding borrowings at any time was approximately $280 million and the average daily balance was approximately $260 million. EQM incurred interest at a weighted average annual interest rate of approximately 2.8% for the three months ended March 31, 2022. During the three months ended March 31, 2021, the maximum outstanding borrowingborrowings at any time was approximately $525 million and the average daily balance was approximately $489 million. EQM incurred interest at a weighted average annual interest rate of approximately 2.5% for the three months ended March 31, 2021. During the three months ended March 31, 2020, the maximum outstanding borrowing at any time was approximately $1,560 million, the average daily balance was approximately $1,027 million, and the weighted average annual interest rate was approximately 3.2%. For the three months ended March 31, 2021 and 2020,2022, commitment fees of $2.3$1.8 million and $1.2 million, respectively, were paid to maintain credit availability under the Amended EQM Credit Facility. For the three months ended March 31, 2021, commitment fees of $2.3 million were paid to maintain credit availability under the First Amended EQM Credit Facility. As of March 31, 2022, no term loans were outstanding under the Amended EQM Credit Facility.
See Note 1210 for discussion of the SecondThird Amendment (as defined in Note 12)10) to the Amended EQM Credit Facility.
Amended 2019 EQM Term Loan Agreement. In August 2019, EQM entered into a term loan agreement (the 2019 EQM Term Loan Agreement) that provided for unsecured term loans (the EQM Term Loans) in an aggregate principal amount of $1.4 billion. On March 30, 2020, EQM entered into an amendment to the 2019 EQM Term Loan Agreement (as amended, the Amended 2019 EQM Term Loan Agreement) which, among other things, amended certain defined terms and negative covenants in the 2019 EQM Term Loan Agreement.
On January 8, 2021, EQM (i) applied a portion of the proceeds from the issuance of the 2021 Senior Notes (defined(as defined below) to prepay all principal, interest, fees and other obligations outstanding under the Amended 2019 EQM Term Loan Agreement and (ii) terminated the Amended 2019 EQM Term Loan Agreement and the loan documents associated therewith. EQM repaid outstanding term loans (the EQM Term Loans) with a principal amount of $1.4 billion in connection with the termination of the Amended 2019 EQM Term Loan Agreement. Prior to its termination in January 2021, the Amended 2019 EQM Term Loan Agreement would have matured in August 2022. During the period from January 1, 2021 through January 7, 2021, and during the three months ended March 31, 2020, the weighted average annual interest rates wererate was approximately 2.4% and 3.2%, respectively..
Eureka Credit Facility.Facilities. On May 13, 2021, Eureka Midstream, LLC (Eureka), a wholly owned subsidiary of Eureka Midstream, hasrepaid all outstanding principal borrowings plus accrued and unpaid interest under and terminated its credit facility
13
Table of Contents

with ABN AMRO Capital USA LLC, as administrative agent, the lenders party thereto from time to time and any other persons party thereto from time to time (the Former Eureka Credit Facility). In conjunction with the termination of, and to fund the repayment of all outstanding amounts under the Former Eureka Credit Facility, on May 13, 2021, Eureka entered into a $400 million senior secured revolving credit facility that is available for general business purposes, including financing maintenancewith Sumitomo Mitsui Banking Corporation, as administrative agent, the lenders party thereto from time to time and expansion capital expenditures relatedany other persons party thereto from time to the Eureka system and providing working capital for Eureka’s operations (as amended, thetime (the 2021 Eureka Credit Facility). The Eureka Credit Facility matures on August 25, 2021. Subject to satisfaction of certain conditions, the Eureka Credit Facility has an accordion feature that allows Eureka to increase the available borrowings under the facility to an amount no greater than $500 million of total commitments.
As of March 31, 20212022, and December 31, 2020,2021, Eureka had approximately $310$268 million and $303$280 million, respectively, of borrowings outstanding under the 2021 Eureka Credit Facility. For the three months ended March 31, 2022, the maximum amount of outstanding borrowings under the 2021 Eureka Credit Facility at any time was approximately $280 million and the average daily balance was approximately $277 million and Eureka incurred interest at a weighted average annual interest rate of approximately 2.9%. For the three months ended March 31, 2022, commitment fees of $0.1 million were paid to maintain credit availability under the 2021 Eureka Credit Facility. For the three months ended March 31, 2021, the maximum amount of outstanding borrowings under the Former Eureka Credit Facility at any time was approximately $310 million, the average daily balance was approximately $305 million and Eureka incurred interest at a weighted average annual interest rate of approximately 2.4%. For the three months ended March 31, 2020, the maximum amount of outstanding borrowings under the Eureka Credit Facility at any time was approximately $293 million, the average daily balance was approximately $293 million and Eureka incurred interest at a weighted average annual interest rate of approximately 3.9%. For the three months ended March 31, 2021, and 2020, commitment fees of $0.1 million and $0.2 million, respectively, were paid to maintain credit availability under the Former Eureka Credit Facility.
2021 Senior Notes. During the first quarter of 2021, EQM issued, in a private offering, $800 million aggregate principal amount of new 4.50% senior notes due 2029 (the 2029 Notes) and $1,100 million aggregate principal amount of new 4.75% senior notes due 2031 (the 2031 Notes and, together with the 2029 Notes, the 2021 Senior Notes) and received net proceeds from the offering of approximately $1,876.5 million (excluding costs related to the Tender Offers discussed below), inclusive of a discount of $19 million and debt issuance costs of $4.5 million. EQM used the net proceeds from the offering of the 2021 Senior Notes and cash on hand to repay all outstanding borrowings under the Amended 2019 EQM Term Loan Agreement, to purchase an aggregate principal amount of $500 million of its outstanding 4.75% notes due 2023 (2023 Notes) pursuant to tender offers for certain of EQM's outstanding indebtedness (such tender offers, the Tender Offers), and for general partnership purposes.
21
Table of Contents

The 2021 Senior Notes were issued under and are governed by an indenture, dated January 8, 2021 (the 2021 Indenture), between EQM and The Bank of New York Mellon Trust Company, N.A., as trustee. The 2021 Indenture contains covenants that limit EQM’s ability to, among other things, incur certain liens securing indebtedness, engage in certain sale and leaseback transactions, and enter into certain consolidations, mergers, conveyances, transfers or leases of all or substantially all of EQM’s assets. The 2029 Notes will mature on January 15, 2029 and interest on the 2029 Notes is payable semi-annually on January 15 and July 15 of each year, commencing July 15, 2021. The 2031 Notes will mature on January 15, 2031 and interest on the 2031 Notes is payable semi-annually on January 15 and July 15 of each year, commencing July 15, 2021.
The 2021 Senior Notes are unsecured and rank equally with all of EQM’s existing and future senior obligations. The 2021 Senior Notes are senior in right of payment to any of EQM’s future obligations that are, by their terms, expressly subordinated in right of payment to the 2021 Senior Notes. The 2021 Senior Notes are effectively subordinated to EQM’s secured obligations, if any, to the extent of the value of the collateral securing such obligations, and structurally subordinated to all indebtedness and obligations, including trade payables, of EQM’s subsidiaries, other than any subsidiaries that may guarantee the 2021 Senior Notes in the future.
EQM may, at its option, redeem some or all of the 2029 Notes and the 2031 Notes, in whole or in part, at any time prior to their maturity at the applicable redemption price as set forth in the 2021 Indenture.
Upon the occurrence of a Change of Control Triggering Event (as defined in the 2021 Indenture), EQM may be required to offer to purchase the 2021 Senior Notes at a purchase price equal to 101% of the aggregate principal amount of the 2021 Senior Notes repurchased, plus accrued and unpaid interest, if any, to, but excluding, the repurchase date.
The 2021 Indenture contains certain events of default, including the following: (1) default in the payment of interest on such 2021 Senior Notes when due that continues for 30 days; (2) default in the payment of principal of or premium, if any, on any such 2021 Senior Notes when due, whether at its stated maturity, upon redemption or otherwise; (3) failure by EQM or any subsidiary guarantor, if any, to comply for 90 days with the other agreements with respect to such 2021 Senior Notes contained in the 2021 Indenture after written notice by the trustee or by the holders of at least 25% in principal amount of the outstanding 2021 Senior Notes of such series; (4) certain events of bankruptcy, insolvency or reorganization of EQM or any subsidiary guarantor, if any, that is one of EQM’s Significant Subsidiaries (as defined in the 2021 Indenture); and (5) if such 2021 Senior Notes are guaranteed by a subsidiary guarantor that is one of EQM’s Significant Subsidiaries, (a) the guarantee of that subsidiary guarantor ceases to be in full force and effect, except as otherwise provided in the 2021 Indenture; (b) the guarantee of that subsidiary guarantor is declared null and void in a judicial proceeding; or (c) that subsidiary guarantor denies or disaffirms its obligations under the 2021 Indenture or its guarantee.
If an event of default occurs and is continuing with respect to any of the 2021 Senior Notes, the trustee or the holders of at least 25% in aggregate principal amount of the then outstanding 2021 Senior Notes of such series may declare the 2021 Senior Notes of such series to be due and payable. Upon such a declaration, such principal, premium, if any, and accrued and unpaid interest on such 2021 Senior Notes will be due and payable immediately. If an event of default relating to certain events of bankruptcy, insolvency or reorganization occurs, all outstanding 2021 Senior Notes will become due and payable immediately without further action or notice on the part of the trustee or any holders of the 2021 Senior Notes.
Tender Offers. On January 15, 2021 (the early tender deadline), the maximum principal amount for the Tender Offers was fully subscribed by the 2023 Notes tendered as of the early tender deadline and on January 20, 2021, EQM purchased an aggregate principal amount of $500 million of 2023 Notes at an aggregate cost of approximately $537 million (inclusive of the applicable early tender premium for the 2023 Notes described in that certain Offer to Purchase of EQM dated January 4, 2021, as amended, plus accrued interest).
The Company incurred a loss on the extinguishment of debt of $41.0 million during the three months ended March 31, 2021 related to the payment of the Tender Offer premium and write off of unamortized discounts and financing costs related to the prepayment of the EQM Term Loans under, and termination of, the Amended 2019 EQM Term Loan Agreement and purchase of 2023 Notes in the Tender Offers. This amount is included in the loss on extinguishment of debt line on the statements of consolidated comprehensive income.
As of March 31, 2021,2022, EQM and Eureka were in compliance with all debt provisions and covenants.
9.7.    Fair Value Measurements
Assets Measured at Fair Value on a Recurring Basis. The Company records derivative instruments at fair value on a gross basis in its consolidated balance sheets. The EQT Global GGA provides for potential cash bonus payments payable by EQT to the Company during the period beginning on the first day of the calendar quarter in which the MVP full in-service date occurs through the calendar quarter ending December 31, 2024 (the Henry Hub cash bonus payment provision). The potential cash bonus payments are conditioned upon the quarterly average of certain Henry Hub natural gas prices exceeding certain price thresholds. The Henry Hub cash bonus payment provision is accounted for as described in Note 5, isa derivative instrument and recorded at its estimated fair value using a Monte Carlo simulation model. Significant inputs used in the fair value measurement include NYMEX Henry Hub natural gas futures prices as of the date of valuation, the targeted in-service date offor the MVP, risk-free
22

interest rates based on U.S. Treasury rates, expected volatility of NYMEX Henry Hub natural gas futures prices and an estimated credit spread of EQT. The expected volatility of NYMEX Henry Hub natural gas futures prices used in the valuation methodology represents a significant unobservable input causing the Henry Hub cash bonus payment provision to be designated as a Level 3 fair value measurement. An expected average volatility of approximately 31%50% was utilized in the valuation model, which is based on market-quoted volatilities of relevant NYMEX Henry Hub natural gas forward prices. As of March 31, 20212022 and December 31, 2020,2021, the fair valuevalues of the Henry Hub cash bonus payment provision was $75.1were $58.1 million and $68.0$51.6 million, respectively, which waswere recorded in other assets on the Company's consolidated balance sheets. During the three months ended March 31, 20212022 and 2020,2021, the Company recognized gains of $7.1$6.4 million and $4.2$7.1 million, respectively, representing the
14

change in estimated fair value of the derivative instrument during the respective periods.period. The gains are reflected in other income, net in the Company's statements of consolidated comprehensive income.
Other Financial Instruments. The carrying values of cash and cash equivalents, accounts receivable, amounts due to/from related parties and accounts payable approximate fair value due to the short maturity of the instruments; as such, their fair values are Level 1 fair value measurements. The carrying values of borrowings under the Amended EQM Credit Facility, the Former Eureka Credit Facility (prior to its termination), the 2021 Eureka Credit Facility and the Amended 2019 EQM Term Loan Agreement (before(prior to its termination) approximate fair value as the interest rates are based on prevailing market rates; these are considered Level 1 fair value measurements. As EQM's borrowings under its senior notes are not actively traded, their fair values are estimated using an income approach model that applies a discount rate based on prevailing market rates for debt with similar remaining time-to-maturity and credit risk; as such, their fair values are Level 2 fair value measurements. As of March 31, 20212022, and December 31, 2020,2021, the estimated fair values of EQM's senior notes were approximately $6,681$6,425.6 million and $5,495 million, respectively, and the carrying values of EQM's senior notes were approximately $6,427 million and $5,046$7,060.5 million, respectively. The fair value of the Preferred Interest is a Level 3 fair value measurement and is estimated using an income approach model that applies a market-based discount rate. As of March 31, 20212022, and December 31, 2020,2021, the estimated fair values of the Preferred Interest were approximately $120$107.6 million and $127$117.0 million, respectively, and the carrying values of the Preferred Interest were approximately $104$98.5 million and $105$100.0 million, respectively.
10.8.    Earnings Per Share
The following table sets forth the computation of the basic and diluted earnings per share attributable to Equitrans Midstream common shareholders for the three months ended March 31, 2021 and 2020:
Three Months Ended March 31,
20212020
BasicDilutedBasicDiluted
(In thousands, except per share data)
Net income$76,597 $76,597 $189,560 $189,560 
Less: Net income attributable to noncontrolling interests (excluding EQM Series A Preferred Units)3,914 3,914 94,327 94,327 
Less: EQM Series A Preferred Units interest in net income0 0 25,501 25,501 
Less: Preferred dividends14,628 14,628 0 0 
Net income attributable to Equitrans Midstream common shareholders$58,055 $58,055 $69,732 $69,732 
Basic weighted average common shares outstanding432,983 432,983 248,591 248,591 
Dilutive securities (a)
— 175 — 0 
Diluted weighted average common shares outstanding432,983 433,158 248,591 248,591 
Earnings per share of common stock attributable to Equitrans Midstream common shareholders$0.13 $0.13 $0.28 $0.28 
(a)For the three months ended March 31, 2021, the Company excluded 30,137 and 30,076 (in thousands) of weighted average anti-dilutive securities related to the Equitrans Midstream Preferred Shares and stock-based compensation awards. Forawards from the computation of diluted weighted average common shares outstanding for the three months ended March 31, 2020, the Company excluded EQM’s anti-dilutive securities related to the EQM Series A Preferred Units2022 and 522 (in thousands) of weighted average anti-dilutive securities related to stock-based compensation awards.2021, respectively.
The Company grants Equitrans Midstream phantom units to certain non-employee directors that will be paid in Equitrans Midstream common stock upon the director's termination of service on the Board. As there are no remaining service, performance or market conditions related to these awards, 486642 and 248486 (in thousands) Equitrans Midstream phantom units were included in the computation of basic and diluted weighted average common shares outstanding for the three months ended March 31, 20212022 and 2020,2021, respectively.
23
Table of Contents


11.9.     Income Taxes

The Company's effective tax rate was 5.6% for the three months ended March 31, 2022, compared to 21.0% for the three months ended March 31, 2021, compared to 9.2% for the three months ended March 31, 2020.2021. For the three months ended March 31, 20212022 and 2020,2021, the Company calculated the provision for income taxes for interim periods by applying an estimate of the annual effective tax rate for the full fiscal year to "ordinary" income or loss (pre-tax income or loss excluding unusual or infrequently occurring items) for the periods. The effective tax rate was higherlower for the three months ended March 31, 20212022 compared to the three months ended March 31, 20202021 primarily due to a reduction in the decrease in net income attributable to noncontrolling interests as a result ofvaluation allowances that limit tax benefits for the EQM MergerCompany’s federal and related effect onstate deferred tax assets, which valuation allowances were recorded by the Company's estimated annualCompany at December 31, 2021. The effective tax rate for the three months ended March 31, 2021.2022 was lower than the statutory rate primarily due to the reduction in the valuation allowances that limit tax benefits for the Company’s federal and state deferred tax assets. The effective tax rate for the three months ended March 31, 2021 was lower than the statutory rate primarily due to the impact of AFUDC - equity on the MVP project and because the Company does not record income tax expense on the portion of its income attributable to the noncontrolling member of Eureka Midstream. The effective tax rate forproject.
For the three months ended March 31, 2020 was lower than the statutory rate because2022, the Company didbelieves that it is more likely than not recordthat the benefit from a portion of its federal and state net operating loss (NOL) carryforwards and deferred tax assets related to interest disallowance under Internal Revenue Code Section 163(j), net of offsetting deferred tax liabilities, will not be realized. For the three months ended March 31, 2022, the Company recorded a $23.1 million income tax benefit related to changes in valuation allowances because of decreases in federal and state deferred tax assets. As of March 31, 2022, the valuation allowances related to federal and state deferred tax assets that are not more likely than not to be realized were $74.5 million compared to the year ended December 31, 2021, of $97.6 million.
Valuation allowances are recorded to reduce deferred tax assets when it is more likely than not (greater than 50%) that a tax benefit will not be realized. In evaluating the need for a valuation allowance, management considers available evidence, both positive and negative, including potential sources of taxable income, income available in carry-back periods, future reversals of taxable temporary differences, projections of taxable income and income from tax planning strategies. Positive evidence includes reversing temporary differences and projection of future profitability within the carry-forward period, including from tax planning strategies. Negative evidence includes historical pre-tax book losses and Pennsylvania NOL expirations. A review of positive and negative evidence regarding these tax benefits resulted in the conclusion that valuation allowances on the Company’s federal and state NOL carryforwards and deferred tax assets related to interest disallowance under Internal Revenue Code Section 163(j), net of offsetting deferred tax liabilities, were warranted as it was more likely than not that these assets will not be realized. Any determination to change the valuation allowance would impact the Company's income tax expense onin the portionperiod in which such a determination is made.
15
Table of its income attributable to the noncontrolling limited partners of EQM for the periods prior to the closing of the EQM Merger, did not record income tax expense on the portion of its income attributable to the noncontrolling member of Eureka Midstream and due to the impact of AFUDC - equity on the MVP project.Contents

12.10.     Subsequent Events
EQM Credit Facility.On April 16, 202122, 2022 (the Amendment Date), EQM entered into an amendment (the SecondThird Amendment) to the Amended EQM Credit Facility. The SecondThird Amendment, amended, among other things:
•Replaced LIBOR with SOFR as the benchmark rate for borrowings, including a credit spread adjustment of 0.10% for all applicable interest periods as well as for daily swing line borrowings.
•certain defined terms, including:Extended the stated maturity date, with such extension only applicable for the lenders approving the Third Amendment, from October 31, 2023 (the Earlier Maturity Date) to April 30, 2025 (the Later Maturity Date).
•Reduced the aggregate commitments available under the Amended EQM Credit Facility, as amended by the Third Amendment, on a non-pro rata basis to approximately $2.16 billion, with approximately $1.55 billion in aggregate commitments available under the Amended EQM Credit Facility, as amended by the Third Amendment, on and after the Earlier Maturity Date and prior to the Later Maturity Date.
•Amended the definition of “Applicable Rate” to change the applicable percentages per annum set forth in the Amended EQM Credit Facility such that:“Pricing Grid” for certain pricing levels, which continue to be determined on the basis of EQM’s then current credit ratings. As of the Amendment Date, (i) Base Rate Loans (as defined in the Amended EQM Credit Facility, as amended by the SecondThird Amendment) bear interest at a base rate plus a margin of 0.125% to 2.000% determined on the basis of EQM’s then-current credit ratings and1.750% per annum, (ii) Eurodollar RateSOFR Loans (as defined in the Amended EQM Credit Facility, as amended by the SecondThird Amendment) bear interest at a Eurodollar RateAdjusted Term SOFR (as defined in the Amended EQM Credit Facility, as amended by the SecondThird Amendment) plus a margin of 1.125% to 3.000% also determined on the basis of EQM’s then-current credit ratings; and
•the definition of “Qualified Project” in the Amended EQM Credit Facility and certain related definitions, which, collectively, have the effect of removing the designation of the MVP project and the Hammerhead project as Qualified Projects on a go-forward basis after March 31, 2021 under the Amended EQM Credit Facility, as amended by the Second Amendment, and eliminating certain addbacks to Consolidated EBITDA2.750% per annum, (iii) Daily Simple Swing Line Loans (as defined in the Amended EQM Credit Facility, as amended by the SecondThird Amendment) that previously were availablebear interest at Adjusted Daily Simple SOFR (as defined in connection with the MVP project and the Hammerhead project; and

•the financial covenant under the Amended EQM Credit Facility, pursuant to which, exceptas amended by the Third Amendment) plus a margin of 2.750% per annum, (iv) the letter of credit fee payable on the daily maximum amount available under each letter of credit is 2.750% per annum and (v) the commitment fee payable for certain measurement periods followingunused commitments is 0.500% per annum.
•Amended the consummation of certain acquisitions during whichfinancial covenant, such that the Consolidated Leverage Ratio (as defined in the Amended EQM Credit Facility, as amended by the SecondThird Amendment) as at the end of each fiscal quarter of EQM ending on or after the Amendment Date cannot exceed the greater of 5.50 to 1.00 or1.00; provided that, effective as of the MVP Mobilization Effective Date (as defined in the Amended EQM Credit Facility, as amended by the Third Amendment), the maximum ratio otherwiseConsolidated Leverage Ratio permitted with respect to the end of the fiscal quarter in which the MVP Mobilization Effective Date occurs and the end of each of the three consecutive fiscal quarters of EQM thereafter shall be 5.85 to 1.00.
•Reduced each of the general lien and general subsidiary debt baskets based on Consolidated Net Tangible Assets (as defined in the Amended EQM Credit Facility, as amended by the Third Amendment) from 5.0% to 2.5% of Consolidated Net Tangible Assets.
•Added a borrowing condition requiring that, solely to the extent a credit extension is used to repay, redeem or refinance EQM’s senior notes, total outstanding amounts under the Amended EQM Credit Facility, as amended by the SecondThird Amendment, for the applicable period, the Consolidated Leverage Ratio cannotmust not exceed (i) for each fiscal quarter ending on and after June 30, 2021 and on or prior to September 30, 2022, 5.95 to 1.00, (ii) for the fiscal quarter ending on December 31, 2022, 5.25 to 1.00, and (iii) for each fiscal quarter ending after December 31, 2022, 5.00 to 1.00.

The Second Amendment also reduced85% of the aggregate commitments available under the Amended EQM Credit Facility, as amended by the Second Amendment, to $2.25 billion, and the commitment of each lender thereunder was reduced accordingly on a pro rata basis.

Mountain Valley Pipeline. Relatedafter giving effect to the MVP Joint Venture’s pursuituse of authorizations to effect stream and wetland crossings on the MVP project route, on March 29, 2021 and April 26, 2021, the Virginia Department of Environmental Quality (the VADEQ) and the West Virginia Department of Environmental Protection (the WVDEP), respectively, requested additional time from the U.S. Army Corps of Engineers (the Army Corps) to address pending MVP Joint Venture applications for Section 401 water quality certification approvals or waivers. Based on the Company’s understanding of continuing discussions, including those held on May 3, 2021, involving the Army Corps, the VADEQ and the WVDEP that indicate a longer review period than the Company anticipated at March 31, 2021, the Company modified its targeted in-service date for the MVP project in the second quarter of 2021 to summer 2022 at a total project cost of approximately $6.2 billion (excluding AFUDC). As a result, the Company is currently evaluating the impact of the modified targeted in-service date to the EQT Global GGA and theproceeds.
24
Table of Contents


Company’s investment in the MVP to its future results of operations and financial position. See Note 5 to the consolidated financial statements for a discussion of the EQT Global GGA.
2516
Table of Contents


EQUITRANS MIDSTREAM CORPORATION
Item 2.  Management's Discussion and Analysis of Financial Condition and Results of Operations
You should read the following discussion and analysis of financial condition and results of operations in conjunction with the consolidated financial statements, and the notes thereto, included elsewhere in this report.
Cautionary Statements
Disclosures in this Quarterly Report on Form 10-Q contain certain forward-looking statements within the meaning of Section 21E of the Securities Exchange Act of 1934, as amended (the Exchange Act), and Section 27A of the Securities Act of 1933, as amended (the Securities Act). Statements that do not relate strictly to historical or current facts are forward-looking and usually identified by the use of words such as "anticipate," "estimate," "could," "would," "will," "may," "forecast," "approximate," "expect," "project," "intend," "plan," "believe," "target" and other words of similar meaning in connection with any discussion of future operating or financial matters. Without limiting the generality of the foregoing, forward-looking statements contained in this Quarterly Report on Form 10-Q include the matters discussed in the section captioned "Outlook" in Part 1,I, "Item 2. Management's Discussion and Analysis of Financial Condition and Results of Operations," and the expectations of plans, strategies, objectives, and growth and anticipated financial and operational performance of Equitrans Midstream andCorporation (together with its affiliates,subsidiaries, Equitrans Midstream or the Company), including:
•guidance and any changes in such guidance regarding the Company’s gathering, transmission and storage and water services revenue and volume, growth, including the anticipated effects associated with the EQT Global GGA and related documents entered into with EQT;
•projected revenue (including from firm reservation fees) and volumes, deferred revenues, expenses and contract liabilities, and the effects on liquidity, leverage, projected revenue, deferred revenue and contract liabilities associated with the EQT Global GGA and the MVP project (including changes in the targeted full in-service date for such project);
•the ultimate gathering fee relief, and timing thereof, provided to EQT under the EQT Global GGA and related agreements, including the exercise by EQT of any cash-out option as an alternative to receiving a portion of such relief;
•the Company's ability to de-lever;
•the weighted average contract life of gathering, transmission and storage contracts;
•infrastructure programs (including the timing, cost, capacity and sources of funding with respect to gathering, transmission and storage and water projects);
•the cost to construct or restore right-of-way for, capacity, shippers for, timing and durability of regulatory approvals and concluding litigation, final design (including expansions, extensions or extensionsrefinements and capital related thereto), ability to contract additional capacity on, mitigate emissions from and complete, and targeted in-service dates of current or in-service projects or assets, in each case as applicable;
•the ultimate terms, partner relationships and structure of the MVP Joint Venture and ownership interests therein;
•the impact of changes in the targeted full in-service date of the MVP project on, among other things, the fair value of the Henry Hub cash bonus payment provision of the EQT Global GGA;GGA and the estimated transaction price allocated to the Company's remaining performance obligations under certain contracts with firm reservation fees and MVCs;
•expansion projects in the Company's operating areas and in areas that would provide access to new markets;
•the Company's ability to provide produced and mixed water handling services and realize expansion opportunities and related capital avoidance;opportunities;
•the Company's ability to identify and complete acquisitions and other strategic transactions, including joint ventures, effectively integrate transactions into the Company’sCompany's operations, and achieve synergies, system optionality, accretion and accretionother benefits associated with transactions, including through increased scale;
•the Company's ability to access commercial opportunities and new customers for its water services business, and the timing and final terms of any definitive water services agreement or agreements between EQT and the Company entered into pursuant to the terms of the Water Services Letter Agreement;
•any credit rating impacts associated with the MVP project, customer credit ratings changes, including EQT's, and defaults, acquisitions, dispositions and financings and any changes in EQM's credit ratings;
2617
Table of Contents


•the impact of the dispute with EQT (or resolution thereof) regarding the Hammerhead gathering agreement and/or ownership of the Hammerhead pipeline on the Company's business and results of operations;
•the impact of such dispute (or resolution thereof) on investors' perceptions of the Company's commercial relationship with EQT;
•the effect and outcome of future contractual disputes, litigation and other proceedings, including regulatory proceedings;
•the effects of any consolidation of or effected by upstream gas producers, whether in or outside of the Appalachian Basin;
•the ability of the Company's contracts to survive a customer bankruptcy or restructuring, the outcome of any attempt to reject such contracts in such contexts (or related negotiations) and the impact on the Company’s results of operations and liquidity of a customer bankruptcy or restructuring;
•the timing and amount of future issuances or repurchases of the Company's securities;
•the effects of conversion, if at all, of the Equitrans Midstream Preferred Shares;Shares (as defined herein);
•the effects of seasonality;
•expected cash flows and MVCs, including those associated with the EQT Global GGA, and any definitive agreement or agreements between EQT and the Company related to the Water Services Letter Agreement, and the potential impacts thereon of the commission timing and cost of the MVP project;
•the ability to achieve, and time for achieving, Hammerhead pipeline full commercial in-service;
•projected capital contributions and capital and operating expenditures, including the amount and timing of reimbursable capital expenditures, capital budget and sources of funds for capital expenditures;
•the Company's potential seeking recoupment of, and ability to recoup, replacement and related costs;
•dividend amounts, timing and rates;
•changes in commodity prices and the effect of commodity prices on the Company's business;
•future decisions of customers in respect of curtailing natural gas production, choke management, timing of turning wells in line, rig and completion activity and related impacts on the Company's business;
•liquidity and financing requirements, including sources and availability;
•interest rates;
•the ability of the Company's subsidiaries (some of which are not wholly owned) to service debt under, and comply with the covenants contained in, their respective credit agreements;
•expectations regarding production, gatherednatural gas and water volumes in the Company's areas of operations;
•the Company's ability to achieve anticipated benefits associated with the execution of the EQT Global GGA the Water Services Letter Agreement and relatedother commercial agreements;
•the impact on the Company and its subsidiaries of the coronavirus disease 2019 (COVID-19) pandemic, including, among other things, effects on demand for natural gas and the Company's services, levels of production of associated gas from basins such as the Permian Basin, commodity prices and access to capital;pandemic;
•the Company's ability to achieve, and create value from, its environmental, social and governance (ESG) and sustainability goalstargets (including goalstargets set forth in its climate policy); and the Company's ability to respond, and impacts of responding, to increasing stakeholder scrutiny in these areas;
•the effectiveness of the Company's information technology systems and practices to defend against evolving cyberattacks on United States critical infrastructure;
•the effects of government regulation;regulation including any quantification of potential impacts of regulatory matters related to climate change on the Company; and
•tax status and position.
The forward-looking statements included in this Quarterly Report on Form 10-Q involve risks and uncertainties that could cause actual results to differ materially from projected results. Accordingly, investors should not place undue reliance on forward-looking statements as a prediction of actual results. The Company has based these forward-looking statements on management's current expectations and assumptions about future events. While the Company considers these expectations and assumptions to be reasonable, they are inherently subject to significant business, economic, competitive, regulatory, judicial and other risks and uncertainties, many of which are difficult to predict and are beyond the Company's control. The risks and
27
Table of Contents


uncertainties that may affect the operations, performance and results of the Company's business and forward-looking statements include, but are not limited to, those set forth under "Item 1A. Risk Factors" in the Company's Annual Report on Form 10-K for the year ended December 31, 2020,2021, as are updated by this Quarterly Report on Form 10-Q.
18
Table of Contents

Any forward-looking statement speaks only as of the date on which such statement is made and the Company does not intend to correct or update any forward-looking statement, unless required by securities law, whether as a result of new information, future events or otherwise.
2819
Table of Contents


Executive Overview

Net income attributable to Equitrans Midstream common shareholders was $58.1$86.5 million ($0.20 per diluted share) for the three months ended March 31, 20212022 compared to $69.7$58.1 million ($0.13 per diluted share) for the three months ended March 31, 2020.2021. The decreaseincrease resulted primarily from the loss on debt extinguishment in the first quarter of 2021, lower income tax expense and lower operating revenues on Gathering (primarily due to impacts of the EQT Global GGA) and Water, lower equity income from the Company's investmentexpenses in the MVP Joint Venture, higher net interest expense and additional loss on extinguishmentfirst quarter of debt charges,2022, partially offset by lower net income attributable to noncontrolling interests, and impairment charges associated with long-lived assets on Gathering and transaction costs duringoperating revenues in the first quarter of 2020. See Note 5 to the consolidated financial statements for a discussion of deferred revenues under the EQT Global GGA.2022.

COVID-19 Update

The COVID-19 outbreak,Effective April 4, 2022, given, among other things, modifications in guidelines from the U.S. Centers for Disease Control and Prevention, the Company terminated its mandatory work-from-home protocol, commenced its return-to-office plan for its office-based employees and made adjustments to certain of its other companywide working protocols which has resulted in a severe global economic downturn and has caused increased volatility in and intermittent disruptionshad been responsive to the global financial and credit markets, remainsCOVID-19 outbreak. However, the Company acknowledges that the COVID-19 pandemic is still ongoing. While COVID-19 has significantly impacted the manner in which the Company’s employees and contractors perform their job functions,Although the outbreak has had, and continues to have, a minimal direct impact on the Company’s overall operations. However, the situation surrounding COVID-19 remains fluid and the Company continues to actively manage its response to the COVID-19 pandemic in collaboration with relevant parties and to take steps intended to protect the safety and health of its employees, customers and communities, and to support the continued delivery of safe and reliable service to its customers and the communities it serves.
In response to COVID-19, the Company has proactively undertaken and continued a number of companywide measures intended to promote the safety and health of field and office-based employees and contractors and the Company's operations have been able to maintain a consistent level of effectiveness through the measures taken. These measures include, among other things, implementing a mandatory work-from-home protocol for a substantial majority of the Company’s employees that remains ongoing as of the filing date of this Quarterly Report on Form 10-Q, instituting enhanced self-protection and office sanitation measures (including face covering protocols and practicing social distancing where possible), eliminating non-essential business travel, providing certain medical benefit enhancements, and timely communicating updates to employees and other relevant parties. Further, additional mitigation efforts have been implemented in connection with the Company’s field operations and the Company has provided support to local communities through corporate giving and the Equitrans Midstream Foundation. The Company believes that it is following best practices under COVID-19 guidance and intends to continue to refine its practices as additional guidance is released and assess potential impacts from COVID-19 to its financial position and operating results, as well as any regulatory and legislative activities relating to COVID-19 that could impact its business.

Notwithstanding the outbreak’s minimal impact to date on the Company’s overall operations, the Company is unable tocannot predict that the pandemic, or further developments regarding variants of COVID-19 or related governmental action, will not have any impact in light of the ongoing and dynamic nature of the circumstances related to COVID-19 and infection levels, any future impact the outbreak may have on the Company’sCompany's business, results of operations andor financial condition. The extent of COVID-19’s impact on the Company will depend on future developments, which are highly uncertain and cannot be predicted with any reasonable degree of certainty, including new information which may emerge concerning the severity of COVID-19 (or variants of the disease), the duration of the outbreak, spikes in infection rates and related economic effects and after effects (including on the natural gas industry), the pace and scale of economic recovery, and actions taken to contain COVID-19 or its impact, including vaccine acceptance, distribution and effectiveness, among others.position. For further information regarding the potential impact of COVID-19 on the Company, see "The ongoing outbreak of COVID-19 and its variant strains (or any future pandemic), and related declines in economic output and demand for natural gas, could harm our business, results of operations and financial condition."under "Item 1A. Risk Factors" in the Company'sCompany’s Annual Report on Form 10-K for the year ended December 31, 2020.2021.

Business Segment Results
Operating segments are revenue-producing components of an enterprise for which separate financial information is produced internally and is subject to evaluation by the chief operating decision maker in deciding how to allocate resources. Headquarters costs consist primarily of certain unallocated corporate expenses and transaction costs, and other unallocated corporate expenses.as applicable. Net interest expense, components of other income and income tax expense (benefit) are managed on a consolidated basis. The Company has presented each segment's operating income other(loss), unrealized gain on derivative instruments, equity income, impairment of equity incomemethod investment and various operational measures, as applicable, in the following sections. Management believes that the presentation of this information is useful to management and investors regarding the financial condition, results of operations and trends and uncertainties of its segments. The Company has reconciled each segment's operating income (loss) to the Company's consolidated operating income and net income (loss) in Note 42 to the consolidated financial statements.
















29
20
Table of Contents


Gathering Results of Operations
Three Months Ended March 31, Three Months Ended March 31,
20212020%
Change		20222021%
Change
(Thousands, except per day amounts)(Thousands, except per day amounts)
FINANCIAL DATAFINANCIAL DATAFINANCIAL DATA
Firm reservation fee revenues (a)
Firm reservation fee revenues (a)
$148,192 $152,079 (2.6)
Firm reservation fee revenues (a)
$132,597 $148,192 (10.5)
Volumetric-based fee revenues (b)
Volumetric-based fee revenues (b)
101,884 157,968 (35.5)
Volumetric-based fee revenues (b)
87,193 101,884 (14.4)
Total operating revenuesTotal operating revenues250,076 310,047 (19.3)Total operating revenues219,790 250,076 (12.1)
Operating expenses:Operating expenses:Operating expenses:
Operating and maintenanceOperating and maintenance22,666 18,878 20.1 Operating and maintenance22,175 22,666 (2.2)
Selling, general and administrativeSelling, general and administrative24,804 21,235 16.8 Selling, general and administrative17,534 24,804 (29.3)
Transaction costs— 4,104 (100.0)
DepreciationDepreciation46,547 40,440 15.1 Depreciation48,255 46,547 3.7 
Amortization of intangible assetsAmortization of intangible assets16,205 14,581 11.1 Amortization of intangible assets16,205 16,205 — 
Impairments of long-lived assets— 55,581 (100.0)
Total operating expensesTotal operating expenses110,222 154,819 (28.8)Total operating expenses104,169 110,222 (5.5)
Operating incomeOperating income$139,854 $155,228 (9.9)Operating income$115,621 $139,854 (17.3)
Other income (c)
$7,135 $4,170 71.1 
Other income, net (c)
Other income, net (c)
$6,442 $7,135 (9.7)
OPERATIONAL DATAOPERATIONAL DATA   OPERATIONAL DATA
Gathered volumes (BBtu per day)Gathered volumes (BBtu per day)Gathered volumes (BBtu per day)
Firm capacity (d)
Firm capacity (d)
5,244 3,282 59.8 
Firm capacity (d)
5,256 5,244 0.2 
Volumetric-based servicesVolumetric-based services3,345 5,014 (33.3)Volumetric-based services2,737 3,345 (18.2)
Total gathered volumesTotal gathered volumes8,589 8,296 3.5 Total gathered volumes7,993 8,589 (6.9)
Capital expenditures (e)
Capital expenditures (e)
$48,113 $111,454 (56.8)
Capital expenditures (e)
$53,147 $48,113 10.5 
(a)For the three months ended March 31, 20212022 and 2020,2021, firm reservation fee revenues included approximately $3.2$2.7 million and $6.3$3.2 million, respectively, of MVC unbilled revenues.
(b)For the three months ended March 31, 2021,, volumetric-based fee revenues included approximately $6.2 million of unbilled revenues.
(c)Other income, net includes the unrealized gains on derivative instruments associated with the Henry Hub cash bonus payment provision. See "Other Income Statement Items" belowNote 7 to the consolidated financial statements for further information.
(d)Includes volumes up to the contractual MVC under agreements structured with MVCs. Volumes in excess of the contractual MVC are reported under Volumetric-based services.
(e)Includes approximately $1.7$3.0 million and $12.5$1.7 million of capital expenditures related to the noncontrolling interest in Eureka Midstream for the three months ended March 31, 20212022 and 2020,2021, respectively.
Three Months Ended March 31, 20212022 Compared to Three Months Ended March 31, 20202021
Gathering operating revenues decreased by $60.0$30.3 million for the three months ended March 31, 20212022 compared to the three months ended March 31, 2020.2021. Firm reservation fee revenues decreased by $3.9$15.6 million primarily due to $72.0 million ofhigher deferred revenue primarily resulting from assumption changes in the fourth quarter of 2021 associated with certain potential contract extensions impacting the estimated total consideration under the EQT Global GGA, partly offset by $61.0 million of increased MVC revenues resulting from the EQT Global GGA and increased firm capacity by other producers.GGA. Volumetric-based fee revenues decreased by $56.1$14.7 million primarily due to increased MVC revenues attributable tolower gathered volumes that previously were subject to volumetric-based fees prior to the EQT Global GGA. See Note 5 to the consolidated financial statements for a discussion of deferred revenues under the EQT Global GGA.resulting from normal well declines and reduced producer activity.
Gathering operating expenses decreased by $44.6$6.1 million for the three months ended March 31, 20212022 compared to the three months ended March 31, 20202021. Selling, general and administrative expenses decreased by $7.3 million primarily as a result of the impairments of long-lived assets (which consisted of gathering assetsdue to lower professional fees and customer-related intangible assets totaling $55.6 million, as described in Note 3 to the consolidated financial statements) and transactionpersonnel costs, associated with the EQM Merger and related transactions, in each case during the first quarter of 2020, partially offset by a $3.8 million increase in operating and maintenance expense in the first quarter of 2021 primarily associated with an increase in repairs and maintenance expense. In addition, selling, general and administrative expense increased by $3.6
30
Table of Contents


million in the first quarter of 2021 primarily due to higher professional services fees and depreciation expense increased by $6.1of $1.7 million in the first quarter of 2021 as a result of additional assets placed in-service.
See "Outlook" and Note 3 to the consolidated financial statements for further discussion of the impairments of long-lived assets. See also “Outlook” for discussions of certain customer production curtailments during 2020 and Note 5 to the consolidated financial statements for discussions of the EQT Global GGA and the transactions related thereto, including the gathering fee relief to EQT thereunder. As was the case for the Gathering operating revenues during the first quarter of 2021, theThe Company expects that the revenues resulting from the MVCs under the EQT Global GGA will increase the proportion of the Company's total operating revenues that are firm reservation fee revenues, and correspondingly decrease the portion of the Company's total operating revenues that are volumetric-based fee revenues, in future periods. Firm reservation fee revenues under the Company’s Hammerhead gathering agreement with EQT (which is subject to a pending dispute with EQT)also are also expected to contribute to an increase in the Company’s firm reservation fee revenues. See also “Outlook” for discussions of the Hammerhead dispute with EQT and the Gulfport Energy Corporation (Gulfport) bankruptcy.


3121
Table of Contents


an increase in the Company’s firm reservation fee revenues following achievement of the Hammerhead pipeline full commercial in-service. See also "Outlook" for discussions of the expected timing of the Hammerhead pipeline in service.
Transmission Results of Operations
Three Months Ended March 31, Three Months Ended March 31,
20212020%
Change		 20222021%
Change
(Thousands, except per day amounts)(Thousands, except per day amounts)
FINANCIAL DATAFINANCIAL DATAFINANCIAL DATA
Firm reservation fee revenuesFirm reservation fee revenues$101,389 $99,597 1.8 Firm reservation fee revenues$102,870 $101,389 1.5 
Volumetric-based fee revenuesVolumetric-based fee revenues10,030 7,018 42.9 Volumetric-based fee revenues7,925 10,030 (21.0)
Total operating revenuesTotal operating revenues111,419 106,615 4.5 Total operating revenues110,795 111,419 (0.6)
Operating expenses:Operating expenses:Operating expenses:
Operating and maintenanceOperating and maintenance7,282 9,441 (22.9)Operating and maintenance3,933 7,282 (46.0)
Selling, general and administrativeSelling, general and administrative8,849 5,182 70.8 Selling, general and administrative8,406 8,849 (5.0)
DepreciationDepreciation13,800 13,558 1.8 Depreciation13,894 13,800 0.7 
Total operating expensesTotal operating expenses29,931 28,181 6.2 Total operating expenses26,233 29,931 (12.4)
Operating incomeOperating income$81,488 $78,434 3.9 Operating income$84,562 $81,488 3.8 
Equity incomeEquity income$3 $54,072 (100.0)Equity income$4 $3 33.3 
OPERATIONAL DATAOPERATIONAL DATA   OPERATIONAL DATA
Transmission pipeline throughput (BBtu per day)Transmission pipeline throughput (BBtu per day)Transmission pipeline throughput (BBtu per day)
Firm capacity reservationFirm capacity reservation2,937 3,000 (2.1)Firm capacity reservation3,151 2,937 7.3 
Volumetric-based servicesVolumetric-based services9 15 (40.0)Volumetric-based services41 9 355.6 
Total transmission pipeline throughputTotal transmission pipeline throughput2,946 3,015 (2.3)Total transmission pipeline throughput3,192 2,946 8.4 
Average contracted firm transmission reservation commitments (BBtu per day)Average contracted firm transmission reservation commitments (BBtu per day)4,424 4,453 (0.7)Average contracted firm transmission reservation commitments (BBtu per day)4,487 4,424 1.4 
Capital expenditures (a)
Capital expenditures (a)
$3,505 $10,798 (67.5)
Capital expenditures (a)
$4,226 $3,505 20.6 
(a)Transmission capital expenditures do not include aggregate capital contributions made to the MVP Joint Venture for the MVP and MVP Southgate projects of approximately $10.7$72.5 million and $45.2$10.7 million for the three months ended March 31, 20212022 and 2020,2021, respectively.
Three Months Ended March 31, 20212022 Compared to Three Months Ended March 31, 20202021
Transmission operating revenues increaseddecreased by $4.8$0.6 million for the three months ended March 31, 20212022 compared to the three months ended March 31, 2020. Firm2021 primarily as a result of decreased volumetric-based fee revenues due to lower storage activities, partially offset by an increase in firm reservation fee revenues increased by $1.8 million primarily due to customers contracting for additional firm transmission capacity. Volumetric-based fee revenues increased by $3.0 million primarily due to higher parkcontracted firm transmission capacity and loan activity and increased usage fees.rates.
Operating expenses increaseddecreased by $1.8$3.7 million for the three months ended March 31, 20212022 compared to the three months ended March 31, 20202021 primarily as a result of higher selling, general and administrative expense resulting from increased professional service fees and personnel costs, partly offset by lower operating and maintenance expense primarily due to operational efficiencies.
Equity income decreased by $54.1 millionwas relatively flat for the three months ended March 31, 20212022 compared to the three months ended March 31, 2020 due to2021.
The Company's equity income in future periods will be affected by the decrease intiming of the MVP Joint Venture's AFUDC onresumption of the remaining MVP project for the three months ended March 31, 2021. Effective January 2021, the MVP Joint Venture temporarily suspended AFUDC on the MVP project until growth construction activities resume. Depending onand associated AFUDC, and the timing for when growth construction activities may resume,of the Company’s equity income could be negatively impacted in future periods,completion of the MVP project, and such impact could continue to be substantial.


3222
Table of Contents



Water Results of Operations
Three Months Ended March 31,Three Months Ended March 31,
20212020%
Change		20222021%
Change
(Thousands)(Thousands, except MMgal amounts)
FINANCIAL DATAFINANCIAL DATAFINANCIAL DATA
Firm reservation fee revenues (a)
Firm reservation fee revenues (a)
$1,844 $12,776 (85.6)
Firm reservation fee revenues (a)
$5,752 $1,844 211.9 
Volumetric-based fee revenuesVolumetric-based fee revenues16,657 23,675 (29.6)Volumetric-based fee revenues5,809 16,657 (65.1)
Total operating revenuesTotal operating revenues18,501 36,451 (49.2)Total operating revenues11,561 18,501 (37.5)
Operating expenses:Operating expenses:Operating expenses:
Operating and maintenanceOperating and maintenance4,135 10,103 (59.1)Operating and maintenance6,709 4,135 62.2 
Selling, general and administrativeSelling, general and administrative1,714 1,480 15.8 Selling, general and administrative2,191 1,714 27.8 
DepreciationDepreciation8,175 7,116 14.9 Depreciation4,517 8,175 (44.7)
Total operating expensesTotal operating expenses14,024 18,699 (25.0)Total operating expenses13,417 14,024 (4.3)
Operating income$4,477 $17,752 (74.8)
Operating (loss) incomeOperating (loss) income$(1,856)$4,477 (141.5)
OPERATIONAL DATAOPERATIONAL DATAOPERATIONAL DATA
Water services volumes (MMgal)Water services volumes (MMgal)Water services volumes (MMgal)
Firm capacity reservation (b)
Firm capacity reservation (b)
36 210 (82.9)
Firm capacity reservation (b)
110 36 205.6 
Volumetric-based servicesVolumetric-based services380 383 (0.8)Volumetric-based services208 380 (45.3)
Total water volumesTotal water volumes416 593 (29.8)Total water volumes318 416 (23.6)
Capital expendituresCapital expenditures$4,807 $3,476 38.3 Capital expenditures$9,565 $4,807 99.0 
(a)    For the three months ended March 31, 2021, and 2020, firm reservation fee revenues included approximately $0.5 million and $5.0 million, respectively, of MVC unbilled revenues.
(b)    Includes volumes up to the contractual MVC under agreements structured with MVCs.MVCs or ARCs, as applicable. Volumes in excess of the contractual MVC are reported under Volumetric-based services.
Three Months Ended March 31, 20212022 Compared to Three Months Ended March 31, 20202021
Water operating revenues decreased by $18.0$6.9 million for the three months ended March 31, 20212022 compared to the three months ended March 31, 2020.2021. Firm reservation fee revenues decreasedincreased by $10.9$3.9 million primarily as a result of decreasedincreased revenues associated with contractually lower MVCs, including decreased unbilled revenue associated with the contractually lower MVCs.ARCs. Volumetric-based fee revenues decreased $7.0$10.8 million primarily due to decreased realized rates on a per gallon basis. A majority of the fresh water delivery fees the Company charges per gallon of water are tieredlower volumes and thus are lower on a per gallon basis once certain volumetric thresholds are met.rates.
Water operating expenses decreased by $4.7$0.6 million for the three months ended March 31, 20212022 compared to the three months ended March 31, 2020 as a result2021. Depreciation expense decreased due to the impairments of lowercertain long-lived assets during the second quarter of 2021, which was partly offset by higher operating and maintenance expense primarily due to overall lower customer activity resulting in lower freshhigher water transfer and produced water costs, partly offset by an increase in depreciation expense as a result of additional assets placed in-service.line expense.
The Company’s water services are directly associated with producers’ well completion activities and fresh and produced water needs (which are partiallyprimarily driven by horizontal lateral lengths and the number of completion stages per well). Therefore, the Water operating results traditionally fluctuate from year-to-year in response to producers’ well completion activities and wateractivities. The
Company expects Water operating resultsrevenues to be higher for interim periods are not necessarily indicative of the results for any year, including the year ending December 31, 2021.2022 as compared to the year ended
December 31, 2021 primarily due to the 2021 Water Services Agreement that became effective on March 1, 2022.
The Company also expects that the contractual revenues resulting from the ARC under the 2021 Water Services Agreement will increase the proportion of the Company's total water operating revenues that are firm reservation fee revenues, and correspondingly decrease the portion of the Company's total water operating revenues that are volumetric-based fee revenues, in future periods. See "Outlook" for further discussion of the 2021 Water Services Agreement.
Other Income Statement Items
Other Income, Net
Other income, net decreased $1.3 million for the three months ended March 31, 2022 compared to the three months ended March 31, 2021. The decrease was primarily due to a $0.7 million decrease in unrealized gain on derivative instruments
3323
Table of Contents


Other income increased by $3.4 million for the three months ended March 31, 2021 compared to the three months ended March 31, 2020. The increase was primarily due to a $3.0 million increase in unrealized gain on derivative instruments associated with the Henry Hub cash bonus payment provision relateddue to the impact of changes in the targeted in-service date for the MVP project, partially offset by an increase in NYMEX Henry Hub natural gas futures prices.
See also "Outlook" for a discussion of factors affecting the estimated fair value of the derivative asset attributable to the Henry Hub cash bonus payment provision that is recognized in other income, net on the Company's statements of consolidated comprehensive income.
Loss on Extinguishment of Debt
Loss on extinguishment of debt increased $16.2decreased $41.0 million for the three months ended March 31, 20212022 compared to the three months ended March 31, 2020. The2021. During the three months ended March 31, 2021, the Company incurred a loss on the extinguishment of debt of $41.0 million during the three months ended March 31, 2021 related to the payment of the Tender Offer premium and write off of unamortized discounts and financing costs related to the prepayment of the EQM Term Loans under, and termination of, the Amended 2019 EQM Term Loan Agreement and purchase of 2023 Notes in the Tender Offers. During the three months ended March 31, 2020, the Company incurred a loss on the extinguishment of debt of $24.9 million related to the write off of unamortized discounts and financing costs related to the prepayment and termination of the ETRN Term Loan Credit Agreement and the Equitrans Midstream Credit Facility. See Note 86 to the consolidated financial statements for additional discussion.

Net Interest Expense

Net interest expense increased $28.4decreased $2.0 million for the three months ended March 31, 20212022 compared to the three months ended March 31, 20202021 primarily due to higher interest expense of $26.0 million associated with the $700 million aggregate principal amount of 6.00% senior unsecured notes due 2025 and $900 million aggregate principal amount of 6.50% senior unsecured notes due 2027 issued by EQM in June 2020 and $20.9 million associated with the 2021 Senior Notes and decreased capitalized interest and AFUDC - debt of $8.1 million, partially offset by lower interest expense of $26.9$1.9 million primarily associated with the termination of the Amended 2019 EQM Term Loan Agreementlower borrowings and the ETRN Term Loan Credit Agreement, decreased borrowings undercommitment fees on the Amended EQM Credit Facility and lower interest on the 2023 Notes as a result of the Tender Offers. As a result of the issuance of the 2021 Senior Notes and use of those proceeds to pay off other outstanding debt, the Company expects interest expense to increase in future periods.Facility.

See also Note 86 and Note 10 to the consolidated financial statements for a discussion of certain of the Company's outstanding debt.

See Note 12 for discussion of the Second Amendment (as defined in Note 12) to the Amended EQM Credit Facility.
Income Taxes
See Note 119 to the consolidated financial statements for an explanation of the increasechanges in income taxes for the three months ended March 31, 20212022 compared to the three months ended March 31, 2020.2021.
The Company files a consolidated income tax returnManagement continues to evaluate the need for federal income taxes and uses the asset and liability method to account for income taxes. EQM is a limited partnership for U.S. federal and state income tax purposes. Eureka Midstream is a limited liability company for such purposes. EQM and Eureka Midstream are not subject to U.S. federal or state income taxes.
All of Eureka Midstream's income is, and for the period prior to the closing of the EQM Merger all of EQM's income was, included invaluation allowances on the Company's pre-tax income; however,deferred tax assets. Management expects the Company does not record incomereduction of valuation allowances to continue during the year ended December 31, 2022 based on its estimated annual effective tax expense on the portions of its income attributable to the noncontrolling member of Eureka Midstream and did not record income tax expense on the portions of its income attributable to the noncontrolling limited partners of EQM for the periods prior to the closing of the EQM Merger. This reduces therate. The Company's estimated annual effective tax rate in periods whenis susceptible to change, including the Company has consolidated pre-tax income. The Company's effective tax rate for periods following the EQM Merger has been,amount of valuation allowances realized, and the Company expects its effective tax rate for future periods willsuch impact may be generally higher than the pre-EQM Merger periods due to the decrease in net income attributable to noncontrolling interests as a result of the EQM Merger and related Restructuring.substantial.
Net Income Attributable to Noncontrolling Interests
Net income attributable to noncontrolling interests decreased $115.9 millionwas relatively flat for the three months ended March 31, 20212022 compared to the three months ended March 31, 2020 primarily as a result of the reduction in noncontrolling interest in connection with the EQM Merger and the Restructuring.
The Company recorded net income attributable to noncontrolling interest for the third-party ownership interests in EQM (including the EQM Series A Preferred Units) through the closing of the EQM Merger. Upon the closing of the EQM Merger on June 17, 2020, the Company's remaining noncontrolling interest consists solely of the third-party ownership interest in Eureka Midstream.2021.
Capital Expenditures
34
Table of Contents


See "Investing Activities" and "Capital Requirements" under "Capital Resources and Liquidity" for discussion of capital expenditures and capital contributions.
Outlook
The Company's strategically-located assets overlay core acreage in the Appalachian Basin. The location of the Company's assets allows its producer customers to access major demand markets in the U.S. The Company is one of the largest natural gas gatherers in the U.S., and its largest customer, EQT, was one of the largest natural gas producerproducers in the U.S. based on average daily sales volumes as of DecemberMarch 31, 2020.2022 and EQT's public senior debt had investment grade credit ratings from Standard & Poor's Global Ratings and Fitch Ratings as of that date. The Company maintains a stable cash flow profile, with approximately 66%71% of its revenue for the three months ended March 31, 20212022 generated by firm reservation fees. Further, the percentage of the Company's operating revenues that are generated by firm reservation fees is expected to increase in future years as a result of the 15-year term EQT Global GGA, which includes an MVC of 3.0 Bcf per day that became effective on April 1, 2020 of 3.0 Bcf per day and gradually steps up to 4.0 Bcf per day for several yearsthrough December 2031 following the full in-service date of the MVP project.MVP. This contract structure enhances the stability of the Company's cash flows and limits its direct exposure to commodity price risk.customer volume variability.
The Company's principal strategy is to achieve greater scale and scope, and enhance the durability of its financial strength and to continue to work to position itself for a lower carbon economy, which the Company expects will drive future growth and investment. The Company is implementing its strategy by leveraging its existing assets, executing on its growth projects (including through potential expansion and extension opportunities), periodically evaluating strategically-aligned inorganic
24
Table of Contents

growth opportunities (whether within its existing footprint or to extend the Company's reach into the southeast United States and to become closer to key demand markets, such as the Gulf of Mexico LNG export market), and focusing on ESG and sustainability initiatives, and, where appropriate, seeking and executingsustainability-oriented initiatives. Additionally, the Company is also continuing to focus on strategically-aligned acquisition and joint venture opportunities and other strategic transactions, while strengthening its balance sheet through:
•highly predictable cash flows backed by firm reservation fees;
•actions to de-lever its balance sheet;
•disciplined capital spending;
•operating cost control; and
•an appropriate dividend policy.
As part of its approach to organic growth, the Company is focused on its projects and assets outlined below, many of which are supported by contracts with firm capacity, MVC or MVCARC commitments. The Company believes that this approach will enable the Company to achieve its strategic goals.
The Company expects that the MVP project (should it be placed in-service), together with the Hammerhead pipeline and Equitrans, L.P. Expansion Project (EEP), will primarily drive the Company's organic growth, and that its future growth also will be supported by the MVP Southgate project and the water services business, as discussed in further detail below.

•Mountain Valley Pipeline. The MVP is being constructed by a joint venture among the Company and affiliates of each of NextEra Energy, Inc., ConConsolidated Edison, Inc. (Con Edison), AltaGas Ltd. and RGC Resources, Inc. As of March 31, 2021,2022, the Company owned an approximate 46.2%47.0% interest in the MVP project and will operate the MVP. The MVP is an estimated 300-mile, 42-inch diameter natural gas interstate pipeline with a targeted capacity of 2.0 Bcf per day that willis designed to span from the Company's existing transmission and storage system in Wetzel County, West Virginia to Pittsylvania County, Virginia, providing access to the growing Southeastsoutheast demand markets. The MVP Joint Venture has secured a total of 2.0 Bcf per day of firm capacity commitments at 20-year terms. Additional shippers have expressed interest in the MVP project and the MVP Joint Venture is evaluating an expansion opportunity that could add approximately 0.5 Bcf per day of capacity through the installation of incremental compression. The MVP Joint Venture is also evaluating other future pipeline extension projects.

In October 2017, the FERC issued the Certificate of Public Convenience and Necessity (the Certificate) for the MVP. In the first quarter of 2018, the MVP Joint Venture received limited notice to proceed with certain construction activities from the FERC and commenced construction. Following a comprehensive review of all outstanding stream and wetland crossings across the approximately 300-mile MVP project route, on February 19, 2021, the MVP Joint Venture submitted (i) a joint application package to each of the Huntington, Pittsburgh and Norfolk Districts of the U.S. Army Corps of Engineers (Army Corps) that requestsrequested an Individual Permit from the Army Corps to cross certain streams and wetlandseffect approximately 300 water crossings utilizing open cut techniques (the Army Corps Individual Permit) and (ii) an application to amend the Certificate that seekssought FERC authority to cross certain streams and wetlands utilizingutilize alternative trenchless construction methods.methods to effect approximately 120 water crossings. On April 8, 2022, the FERC authorized the amended Certificate. Related to seeking the Army Corps Individual Permit, on March 4, 2021, the MVP Joint Venture submitted applications to each of the West Virginia Department of Environmental Protection (WVDEP) and the Virginia Department of Environmental Quality (VADEQ) seeking Section 401 water quality certification approvals or waivers (such approvals or waivers, the State 401 Approvals).
35
Table, which State 401 Approvals were each received in December 2021. As discussed in Part II, "Item 1. Legal Proceedings" of Contents


Whilethis Quarterly Report on Form 10-Q, on January 25, 2022, the MVP Joint Venture's authorizations related to the Jefferson National Forest (JNF) received from the Bureau of Land Management (BLM) and the U.S. Forest Service (USFS) were vacated and remanded on specific issues by the U.S. Court of Appeals for the Fourth Circuit (Fourth Circuit). As also discussed in Part II, "Item 1. Legal Proceedings" of this Quarterly Report on Form 10-Q, on February 2, 2022, the Fourth Circuit vacated and remanded on specific issues the Biological Opinion and Incidental Take Statement issued by the United States Department of the Interior's Fish and Wildlife Service (FWS) for the MVP project. After evaluating legal options and consulting with the relevant federal agencies, the MVP Joint Venture anticipated that the applications would be acted upon within approximately six months and the agencies are continuingplans to process the applications, both the VADEQ and WVDEP submitted requestspursue new authorizations relating to the Army Corps for additional time to address the applications. Based on the Company’s understanding of discussions occurring in April (which discussions continue, including as recently as May 3, 2021), involving the Army CorpsJNF and the VADEQa new Biological Opinion and WVDEP regarding the requested extensions, the Company expects that the Army Corps will grant the VADEQ and WVDEP additional review time and, in light of the agencies' rationales for seeking extensions, is supportive of that action. Taking into account that discussions regarding the extensions remain ongoing and the likelihood of a longer review period than originally anticipatedIncidental Take Statement and as a result, the potential for certain time of year restrictions (unless waived or alternative crossing authority is obtained) and seasonal challenges to affect construction, as well as seasonal carrying costs, the Company is targeting a full in-service date for the MVP project in summer 2022during the second half of 2023 at a targeted total project cost of approximately $6.2$6.6 billion (excluding AFUDC).

In addition to timely receiving, and subsequently maintaining, new authorizations in respect of the JNF, and a Biological Opinion and Incidental Take Statement, the MVP Joint Venture must, in order to complete the project, in accordance with the targeted full in-service date and cost, the MVP Joint Venture must, among other things, timely receive the Army Corps Individual Permit (as well as timely receive, the State 401 Approvals and, asif necessary,
25
Table of Contents

certain other state-level approvals), and timely receive authorizationas well as any necessary extensions from the FERC to amendcomplete the Certificate to utilize alternative trenchless construction methods for certain stream and wetland crossings.MVP project. The MVP Joint Venture also must (i) maintain and, as applicable, timely receive required authorizations, including authorization to proceed with construction, related to the Jefferson National Forest (JNF) from the Bureau of Land Management (BLM), the U.S. Forest Service (USFS) and the FERC; (ii) continue to have available the orders previously issued by the FERC, which are the subject of ongoing litigation, modifying its prior stop work orders and extending the MVP Joint Venture’s prescribed time to complete the MVP project; (iii)and (ii) timely receive authorization from the FERC to complete construction work in the portion of the project route currently remaining subject to the FERC’s previous stop work order;order and (iv) continue to be authorized to work underin the Biological Opinion and Incidental Take Statement issued by the United States Department of the Interior’s Fish and Wildlife Service (FWS) for the MVP project.JNF. In each case, any such foregoing or other authorizations, including the FERC's April 2022 order authorizing the amended Certificate, must remain in effect notwithstanding any pending or future challenge thereto. For further information regarding litigation and regulatory related delays affecting the completion of the MVP project, see Part II, "Item 1. Legal Proceedings" in Part II of this Quarterly Report on Form 10-Q. See also "The regulatory approval process for the construction of new midstream assets is very challenging, has significantly increased costs and delayed targeted in-service dates, and decisions by regulatory and judicial authorities in pending or potential proceedings couldare likely to impact our or the MVP Joint Venture's ability to obtain or maintain in effect all approvals and authorizations necessary to complete certain projects on the targeted time frame or at all or our ability to achieve the expected investment returns on the projects." included in "Item 1A. Risk Factors" in the Company's Annual Report on Form 10-K for the year ended December 31, 2020 for additional discussion of risks in respect of the targeted in-service date and cost discussed above.

2021.
On November 4, 2019, Con Edison exercised an option to cap its investment in the construction of the MVP project at approximately $530 million (excluding AFUDC). The Company and NextEra Energy, Inc. are obligated, and RGC Resources, Inc., another member of the MVP Joint Venture owning an interest in the MVP project, has opted, to fund the shortfall in Con Edison's capital contributions on a pro rata basis. Such funding by the Company and funding by other members has and will correspondingly increase the Company's and such other members' respective interests in the MVP project and decrease Con Edison's interest in the MVP project. As a result, based on the MVP project's approximate $6.2Company's total targeted cost for the project of approximately $6.6 billion (excluding AFUDC) targeted cost,, the Company's equity ownership interest in the MVP project will progressively increase from approximately 46.2%47.0% to approximately 47.8%48.1%.

Through March 31, 2021,2022, based on the MVP project's total targeted cost, the Company had funded approximately $2.3$2.6 billion of its estimated total capital contributions of approximately $3.1$3.4 billion (inclusive of additional contributions required due to the Con Edison cap described above), includingwhich estimated total capital contributions include approximately $160$180 million in excess of the Company's ownership interest. For 2021,2022, the Company expects to make total capital contributions of $265approximately $175 million to $315$225 million primarily related to the MVP Joint Venture for purposes of the MVP project, depending on the timing of construction of the project,work completed in late 2021 and ongoing right-of-way maintenance, of which approximately $9.1$72.0 million had been contributed to the MVP Joint Venture as of March 31, 2021.

2022.
•Wellhead Gathering Expansion Projects and Hammerhead Pipeline. During the three months ended March 31, 2021,2022, the Company invested approximately $48.1$53.1 million in gathering projects (inclusive of capital expenditures related to the noncontrolling interest in Eureka Midstream). For 2021,2022, the Company expects to invest approximately $285$270 million to $315$320 million in gathering projects (inclusive of expected capital expenditures of approximately $20 million related to the noncontrolling interest in Eureka Midstream). The primary projects include infrastructure expansion of core development areas in the Marcellus and Utica Shales in southwestern Pennsylvania, southeastern Ohio and northern West Virginia for EQT, Range Resources Corporation (Range Resources) and other producers.
36
Table of Contents



The Hammerhead pipeline is a 1.6 Bcf per day gathering header pipeline that is primarily designed to connect natural gas produced in Pennsylvania and West Virginia to the MVP, Texas Eastern Transmission and Dominion Transmission, is supported by a 20-year term, 1.2 Bcf per day, firm capacity commitment from EQT and cost approximately $540 million. The Company believes theexpects Hammerhead pipeline was placedfull commercial in-service effective August 1, 2020. For more information, see "Hammerhead Pipeline" below.to commence in conjunction with full MVP in-service.
•Transmission Projects and Equitrans Expansion Project. During the three months ended March 31, 2021,2022, the Company invested approximately $3.5$4.2 million in transmission projects. For 2021,projects, including the Company expects to invest approximately $30 million to $50 million in transmission projects.

EEP. The EEP is designed to provide north-to-south capacity on the mainline Equitrans, L.P. system, including primarily for deliveries to the MVP. A portion of the EEP commenced operations with interruptible service in the third quarter of 2019. The EEP provides capacity of approximately 600 MMcf per day and offers access to several markets through interconnects with Texas Eastern Transmission, Dominion Transmission and Columbia Gas Transmission. Once the MVP is fully placed in service, firm transportation agreements for 550 MMcf per day of capacity will commence under 20-year terms.
For 2022, the Company expects to invest approximately $45 million in transmission projects, inclusive of capital expenditures expected for 2022 associated with the Company's Ohio Valley Connector expansion project
26
Table of Contents

(OVCX). OVCX will increase deliverability on the Company's existing Ohio Valley Connector pipeline (OVC) by approximately 350 MMcf per day, create new receipt and delivery transportation paths, and enhance long-term reliability. The project is supported by new long-term firm capacity commitments of 330 MMcf per day, as well as an extension of approximately 1.0 Bcf per day of existing contracted mainline capacity for EQT. OVCX is designed to meet growing demand in key markets in the mid-continent and gulf coast through existing interconnects with long-haul pipelines in Clarington, Ohio. The targeted in-service date for the incremental OVC capacity is the third quarter of 2023. The Company expects to invest approximately $160 million, which includes approximately $130 million for new compression. The project is consistent with the Company's ongoing efforts to optimize existing assets and achieve capital efficiency.
•MVP Southgate Project. In April 2018, the MVP Joint Venture announced the MVP Southgate project, which is a proposed 75-mile interstate pipeline that willis contemplated to extend from the MVP at Pittsylvania County, Virginia to new delivery points in Rockingham and Alamance Counties, North Carolina. The MVP Southgate project is backed by a 300 MMcf per day firm capacity commitment from Dominion Energy North Carolina. AsCarolina, and, as currently designed, the MVP Southgate project hasreflects potential expansion capabilities that could provide up to 900 MMcf per day of total capacity. The MVP Southgate project is estimated to cost a total of approximately $450 million to $500 million, whichCompany is expected to be spent primarily in 2022. The Company expects to fund approximately $225 million of the overall project cost. During the three months ended March 31, 2021, the Company made approximately $1.6 million of capital contributions to the MVP Joint Venture for the MVP Southgate project. For 2021, the Company expects to make capital contributions of approximately $10 million to the MVP Joint Venture for the MVP Southgate project. The Company will operate the MVP Southgate project and as of March 31, 2021, owned a 47.2% interest in the MVP Southgate project. project as of March 31, 2022.
The MVP Joint Venture submitted the MVP Southgate certificate application to the FERC in November 2018. The Final Environmental Impact Statement for the MVP Southgate project was issued on February 14, 2020. In June 2020, the FERC issued the Certificate of Public Convenience and Necessity for the MVP Southgate; however, the FERC, while authorizing the project, directed the Office of Energy Projects not to issue a notice to proceed with construction until necessary federal permits are received for the MVP project and the Director of the Office of Energy Projects lifts the stop work order and authorizes the MVP Joint Venture to continue constructing the MVP project. On August 11, 2020, the North Carolina Department of Environmental Quality (NCDEQ) denied the MVP Southgate project's application for a Clean Water Act Section 401 Individual Water Quality Certification and Jordan Lake Riparian Buffer Authorization due to uncertainty surrounding the completion of the MVP project. On March 11, 2021, the Fourth Circuit, Court of Appeals, pursuant to an appeal filed by the MVP Joint Venture, vacated the NCDEQ's denial and remanded the matter to the NCDEQ for additional review. On April 29, 2021, the NCDEQ reissued its denial of the MVP Southgate project's application for a Clean Water Act Section 401 Individual Water Quality Certification and Jordan Lake Riparian Buffer Authorization. Based onOn December 3, 2021, the updated targeted full in-service dateVirginia State Air Pollution Control Board denied the permit for the MVP and expectations regarding MVP Southgate permit approval timing, the Company is targeting commencing construction onproject’s Lambert compressor station, which decision the MVP Southgate in 2022 and placingJoint Venture initially appealed before withdrawing its request to review the MVP Southgate in-service during the spring of 2023.denial. See the discussion of litigation and regulatory related delays affecting the completion of the MVP Southgate project set forth in Part II, "Item 1. Legal Proceedings" in Part II of this Quarterly Report on Form 10-Q.
Given the continually evolving regulatory and legal environment for greenfield pipeline construction projects, as well as factors specific to the MVP and MVP Southgate projects, including the December 2021 compressor station state air permit denial, the MVP Joint Venture continues to evaluate the MVP Southgate project, including engaging in discussions with Dominion Energy North Carolina regarding options with respect to the MVP Southgate project, including potentially refining the project’s design and timing in lieu of pursuing the project as originally contemplated. Dominion Energy North Carolina’s obligations under the precedent agreement in support of the original project are subject to certain conditions, including that the MVP Joint Venture complete construction of the project facilities by June 1, 2022, which deadline is subject to extension by virtue of previously declared events of force majeure. The Company is unable to predict the results of the discussions between the MVP Joint Venture and Dominion Energy North Carolina, including any potential modifications to the project, or ultimate undertaking or completion of the project.
The MVP Southgate project, as originally designed, was estimated to cost a total of approximately $450 million to $500 million, a portion of which the Company expected to fund. For 2022, the Company expects to make capital contributions of approximately $5 million to the MVP Joint Venture for the MVP Southgate project, of which approximately $0.5 million had been contributed as of March 31, 2022.
•Water Operations. During the three months ended March 31, 2021,2022, the Company invested approximately $4.8$9.6 million in its fresh water delivery infrastructure. For 2021,In 2022, the Company expects to invest approximately $75 million to complete the initial mixed-use water system buildout. This includes approximately $20 million into replace certain previously installed water lines that the operationsCompany believes do not meet their prescribed quality standards. The Company intends to seek recoupment of its fresh water delivery infrastructure in Pennsylvaniasuch replacement and Ohio.related costs.
27
Table of Contents

See further discussion of capital expenditures in the "Capital Requirements" section below.
EQT Global GGA. On February 27, 2020, the Company announced the EQT Global GGA, which is a 15-year contract that includes, among other things, a 3.0 Bcf per day MVC (which gradually steps up to 4.0 Bcf per day for several yearsthrough December 2031 following the full in-service date of the MVP project)MVP) and the dedication of a substantial majority of EQT’s core acreage in southwestern Pennsylvania and West Virginia to the Company. Under the EQT Global GGA, EQT will receive certain gathering fee relief over a period of
37
Table of Contents


three years, following the in-service date of the MVP, subject to any exercise of the EQT Cash Option (as further described in Note 5 to the consolidated financial statements)below). The EQT Global GGA replaced 14 previous gathering agreements between EQT and the Company.
Under the EQT Global GGA, the performance obligation is to provide daily MVC capacity and as such the total consideration is allocated proportionally to the daily MVC over the life of the contract. In periods that the gathering MVC revenue billed will exceed the allocated consideration, the excess will be deferred to the contract liability and recognized in revenue when the performance obligation has been satisfied. Assuming a full in-service date in summer 2022 for the MVP, the deferral to the contract liability is expected to increase by approximately $296 million for 2021 and by approximately $67 million during 2022. While the 3.0 Bcf per day MVC capacity became effective on April 1, 2020, additional daily MVC capacity and the associated gathering MVC fees payable by EQT to the Company as set forth in the EQT Global GGA are conditioned upon the full in-service date of the MVP. There are ongoing legal and regulatory matters that must be resolved beforeaffect the MVP project can be completed which have had and/or could have (as applicable) a material effect on the performance obligation, the allocation of the total consideration over the life of the contract and the gathering MVC fees payable by EQT under the contract.
The gathering MVC fees payable by EQT to the Company are subject to potential reductions for certain contract years as set forth in the EQT Global GGA, conditioned to begin the first day of the quarter in which the full in-service date of the MVP occurs, which provide for estimated aggregate fee relief of approximately $270 million in the first twelve-month period, approximately $230 million in the second twelve-month period and approximately $35 million in the third twelve-month period. Further, the EQT Global GGA provides for a fee credit to the gathering rate for certain gathered volumes that also receive separate transmission services under certain transmission contracts. In addition, given that the MVP full in-service date did not occur by January 1, 2022, EQT has an option until December 31, 2022, to forgo approximately $145 million of the gathering fee relief in such first twelve-month period and approximately $90 million of the gathering fee relief in such second twelve-month period in exchange for a cash payment from the Company to EQT in the amount of approximately $196 million (the EQT Cash Option).
Based on the Henry Hub natural gas forward strip prices as of April 30, 202129, 2022 and the terms of the Henry Hub cash bonus payment provision, any further delays in the full in-service date for the MVP project, including beyond the most recent targeted full in-service date of summer 2022,the second half of 2023, would decrease the estimated fair value of the derivative asset attributable to the Henry Hub cash bonus payment provision, and such decrease may be substantial. SuchFor a discussion of the potential effect of hypothetical changes to the NYMEX Henry Hub natural gas future prices on the estimated fair value of the derivative asset attributable to the Henry Hub cash bonus payment provision, see "Commodity Prices" in Part I, "Item 3. Quantitative and Qualitative Disclosures About Market Risk" of this Quarterly Report on Form 10-Q. Changes in estimated fair value if any, would beare recognized in other income, net, on the Company’s statements of consolidated comprehensive income.
2021 Water Services Agreement. On October 22, 2021, the Company and EQT entered into a new 10-year, mixed-use water services agreement covering operations within a dedicated area in southwestern Pennsylvania. The 2021 Water Services Agreement became effective on March 1, 2022 and replaced the Water Services Letter Agreement and certain other existing Pennsylvania water services agreements. Pursuant to the 2021 Water Services Agreement, EQT has agreed to pay the Company a minimum ARC for water services equal to $40 million in each of the first five years of the 10-year contract term and equal to $35 million per year for the remaining five years of the contract term.
For afurther discussion of the Company's commercial relationship with EQT and related considerations, including risk factors, see "Item 1A. Risk Factors." in the Company's Annual Report on Form 10-K for the year ended December 31, 2020, as updated by this Quarterly Report on Form 10-Q. See also Note 5 to the consolidated financial statements for additional information regarding the EQT Global GGA, and the transactions related thereto.2021. For further discussion on litigation and regulatory challenges affecting the completion of the MVP project, see "Outlook" above and Part II, "Item 1. Legal Proceedings" in Part II of this Quarterly Report on Form 10-Q.
Hammerhead Pipeline. On September 23, 2020, EQT and certain affiliates of EQT instituted arbitration proceedings against the Company by filing a Demand for Arbitration with the American Arbitration Association. The arbitration arises out of the Hammerhead gathering agreement, pursuant to which the Company agreed to construct the Hammerhead pipeline and gather gas for EQT. EQT sought a declaratory judgment that it may exercise an early termination right and purchase the Hammerhead pipeline and related facilities under the terms of the Hammerhead gathering agreement. With its Demand for Arbitration, EQT also sought emergency relief, asking that an emergency arbitrator: (i) resolve the parties’ dispute on the merits by October 1, 2020; or (ii) alternatively, toll the contractual deadline for EQT’s exercise of its termination right, which was set to expire on October 11, 2020, until after the parties’ dispute was resolved. On October 6, 2020, the emergency arbitrator issued an order denying EQT’s request for emergency resolution on the merits but tolling the early termination deadline until the arbitration has been resolved. The Company’s answer to the Notice of Arbitration was filed on October 8, 2020, and the parties are currently engaged in arbitration with a hearing currently scheduled for June 28, 2021. The Company will vigorously defend against EQT’s claims and litigate the Company’s rights, including the assertion of appropriate counterclaims.
Gulfport Bankruptcy. On November 13, 2020, Gulfport commenced bankruptcy proceedings. On November 24, 2020, Gulfport moved to reject its gas gathering agreements with the Company and made certain related court filings, which motions the Company opposed. On April 21, 2021, Gulfport acted to assume the gas gathering agreements with the Company, which assumption was confirmed by the bankruptcy court in a subsequent hearing.

Commodity Prices. The Company’s business is dependent on continued natural gas production and the availability and development of reserves in its areas of operation. Low prices for natural gas and NGLs adversely affect development of additional reserves and production that is accessible by the Company’s pipeline and storage assets, which also negatively affects the Company’s water services business.

The outbreak of COVID-19 directly resulted in a significant decrease in demand for oil and NGLs and, together with events affecting the level of oil supplies, negatively impacted the prices of those commodities. The revised outlook for oil and other liquids prices caused a significant reduction in the number of operating drilling rigs in the United States from January 2020 levels (according to average rig count data from Baker Hughes) and oil and associated natural gas and NGL production to be curtailed during portions of 2020. Although commodity prices have stabilized and improved from 2020 lows, the number of operating drilling rigs has not returned to pre-COVID-19 levels as exploration and production companies remain focused on capital discipline and free cash flow generation rather than growth. Accordingly, the natural gas forward price strip has been positively impacted based on the continued market expectation that reduced production of associated gas from basins such as the Permian Basin will result in higher natural gas prices relative to 2020 lows at least in the near- and medium-term.

38
Table of Contents


Although Henry Hub natural gas prices generally have improved from the 2020 lows (and temporarily spiked during the first quarter of 2021), Henry Hub spot and local spot natural gas prices were under pressure prior to the COVID-19 outbreak and market prices for natural gas in the Appalachian Basin continue to be lower than Henry Hub natural gas prices and were significantly lower during portions of 2020. While the natural gas forward price strip as of April 30, 2021 indicated higher prices during 2021 and potentially into 2022 relative to 2020 lows, the length and extent of that price recovery (if any), including in the Company’s local markets, and its effect on the development plans of the Company’s customers, which impact both the Company’s ability to execute new commercial agreements with its customers as well as the volumetric-based fee revenues the Company earns under existing contracts, will be impacted by, among other things, global demand for natural gas (which will likely continue to be impacted by, among other things, increasing focus on climate change, energy transition from fossil fuels, and demand for alternative forms of energy), rates of natural gas production (including in the Appalachian Basin, as well as amounts of associated gas from the Permian Basin, which certain analysts have projected will increase in 2021 and later years), producers’ focus on capital discipline and free cash flow generation rather than growth, storage levels, and the length and severity of the COVID-19 outbreak. There is no assurance that any elevated natural gas prices indicated by the natural gas forward price strip as of April 30, 2021 will be realized or be realized for any particular length of time or in the Company’s local markets, or that producers will increase production volume as a result of any particular price level.

For additional information regarding impacts of commodity prices on the Company and related risks, see Part I, “Item 3. Quantitative and Qualitative Disclosures About Market Risk” of this Quarterly Report on Form 10-Q, as well as "Decreases in production of natural gas in our areas of operation have adversely affected, and future decreases could further adversely affect, our business and operating results and reduce our cash available to pay cash dividends to our shareholders." included in Item "1A. Risk Factors" of the Company’s Annual Report on Form 10-K for the year ended December 31, 2020.
Potential Future Impairments. During the first quarter of 2020, the Company recognized impairments of long-lived assets of approximately $55.6 million, including $37.9 million related to certain Hornet Midstream-related gathering assets and $17.7 million related to certain Hornet Midstream-related intangible assets. See Note 3 to the consolidated financial statements for additional information.
The accounting estimates related to impairments are susceptible to change, including estimating fair value which requires considerable judgment. For goodwill, management’s estimate of a reporting unit’s future financial results is sensitive to changes in assumptions, such as changes in stock prices, weighted-average cost of capital, terminal growth rates and industry multiples. Similarly, cash flow estimates utilized for purposes of evaluating long-lived assets and equity method investmentsinvestment (such as in the MVP Joint Venture) require the Company to make projections and assumptions for many years into the future for pricing, demand, competition, operating cost,costs, commencement of operations, resolution of relevant legal and regulatory matters, and other factors. The Company evaluates long-lived assets and equity method investments for impairment when events or changes in circumstances indicate, in management’s judgment, that the carrying value of such assets may not be recoverable (meaning, in the case of its equity method investments,investment, that such investments haveinvestment has suffered other-than-temporaryother-than-
28
Table of Contents

temporary declines in value under ASC 323). For the Company’s equity investment in the MVP Joint Venture, management must evaluate the Company’s investment for other-than-temporary declines in fair value under ASC 323. The Company believes the estimates and assumptions used in estimating its reporting units’, its long-lived assets' and its equity investment's fair values are reasonable and appropriate as of March 31, 2021;2022; however, assumptions and estimates are inherently subject to significant business, economic, competitive, regulatory, judicial and other risks that could materially affect the calculated fair values and the resulting conclusions regarding impairments, which could materially affect the Company’s results of operations and financial position. Additionally, actual results could differ from these estimates and assumptions may not be realized. The Company also continues to evaluate and monitor the ongoing legal and regulatory matters related toaffecting the MVP and MVP Southgate projects, that affect project completion, as further described in Part II, “Item 1. Legal Proceedings” in Part II of this Quarterly Report on Form 10-Q. AdverseFurther adverse or delayed developments with respect to such matters or other adverse developments including the most recently announced delay of the targeted in-service date for the MVP project, could require that the Company modify assumptions reflected in the probability-weighted scenarios of discounted future net cash flows (including with respect to the probability of success) utilized to estimate the fair value of its equity investment in the MVP Joint Venture, which could result in an other-than-temporary decline in value, resulting in an incremental impairment of that investment. See also Note 3 to the consolidated financial statements, as well as “Reviews of our goodwill, intangible and other long-lived assets and equity method investment in the MVP Joint Venture have resulted in significant impairment charges, and reviews of our goodwill, intangible and other long-lived assets and equity method investment in the MVP Joint Venture could result in future significant impairment charges, including with respect to our investment in the MVP Joint Venture.charges.” included in “Item 1A. Risk Factors" in the Company's Annual Report on Form 10-K for the year ended December 31, 20202021 and the Company's discussion of "Critical Accounting Policies and Estimates" included in "Item 7. Management's Discussion and Analysis of Financial Condition and Results of Operation"Operations" in the Company's Annual Report on Form 10-K for the year ended December 31, 2020.2021.
As of the filing of this Quarterly Report on Form 10-Q, the Company cannot predict the likelihood or magnitude of any future impairment.
39
Table of Contents


For a discussion of capital expenditures, see "Capital Requirements" below.
Capital Resources and Liquidity
The Company's liquidity requirements are to finance its operations, its capital expenditures, potential acquisitions and other strategic transactions and capital contributions to joint ventures, including the MVP Joint Venture, to pay cash dividends and to satisfy any indebtedness obligations. The Company's ability to meet these liquidity requirements depends on the Company's cash flow from operations, the continued ability of the Company to borrow under its credit facilities and the Company's ability to raise capital in banking and capital markets. We believe that our cash on hand and other markets (including refinancing existingfuture cash generated from operations, together with available borrowing capacity under our subsidiaries' credit facilities as they mature). Cashand our access to banking and capital markets, will provide adequate resources to fund our short-term and long-term capital, operating and financing needs. However, cash flow and capital raising activities (including the ability in refinancings to obtain similar terms to those currently present in existing credit facilities) may be affected by prevailing economic conditions in the natural gas industry, including, in the case of capital raising activities, volatility related to the ongoing conflict in Ukraine, and other financial and business factors (including those market forces causing shiftsdiscussed in investor sentiment away from fossil fuels“Our business is subject to climate change-related transitional risks (including evolving climate-focused regulation and credit allocations to industriesclimate change-driven trends emphasizing financing non-fossil fuel businesses and companies perceived as being more sustainable, having better growth opportunities and/or stronger ESG metricsprompting pursuit of emissions reductions, lower-carbon technologies and practices, as well asalternative forms of energy) and physical risks that could significantly increase our operating expenses and capital costs, adversely affect our customers’ development plans, and reduce demand for our products and services." included in "Item 1A. Risk Factors" in the COVID-19 outbreak)Company's Annual Report on Form 10-K for the year ended December 31, 2021), some of which are beyond the Company's control. The Company's available sources of liquidity include cash from operations, cash on hand, borrowings under its subsidiaries' revolving credit facilities, issuances of additional debt and issuances of additional equity securities. As of March 31, 2021,2022, pursuant to the terms of the Amended EQM Credit Facility, EQM would have been able to borrow approximately $1.9$1.1 billion under the Amended EQM Credit Facility. The amount the Company is able to borrow under the Amended EQM Credit Facility as amended by the Second Amendment, is bounded by a maximum consolidated leverage ratio. See Note 86 and Note 10 to the consolidated financial statements included in this Quarterly Report on Form 10-Q. See Note 12 for discussion of the Second Amendment (as defined in Note 12) tofurther information regarding the Amended EQM Credit Facility.

See “Security Ratings” below for a discussion of EQM’s credit ratings as of March 31, 2021. The non-investment grade ratings from Moody's, S&P and Fitch have caused the Company to incur higher borrowing costs under the Amended EQM Credit Facility and, prior to its termination, the Amended 2019 EQM Term Loan Agreement when compared to prior periods during which2022. Based on EQM's credit ratings were investment grade. As a result of downgrades in February 2020,rating levels, EQM was also obligated to deliver additionalhas delivered credit support to the MVP Joint Venture in the form of letters of credit, which, in the case of the MVP project, (based on the targeted cost for the project), is in the amount of approximately $273.1$219.7 million and is, in the case of the MVP Southgate project, $14.2 million, in each case as of March 31, 2022 and which are subject to adjustment based on the filing dateapplicable construction budget. In connection with delivering such letters of this Quarterly Report on Form 10-Q.credit as replacement performance assurances, EQM's performance guarantees associated with the MVP and MVP Southgate projects were terminated. Additionally, pursuant to the EQT Global GGA, if EQM does not maintain minimum credit ratings from two of three credit rating agencies of at least Ba3 with respect to Moody's and BB- with respect to S&P and Fitch, EQM will be obligated to provide additional credit support in an amount equal to approximately $196 million to EQT in support of the potential payment obligation related to the EQT Cash Option (the Cash Option Letter of Credit). See Note 5 to the consolidated financial statements for a discussion of the EQT Cash Option, which will become exercisable by EQT commencing on January 1, 2022. See "A further downgrade of EQM'sEQM’s credit ratings, including in connection with the MVP project or customer credit ratings changes, including EQT's, which are determined by independent third parties, could impact our liquidity, access to capital, and costs of doing
29
Table of Contents

business." included in "Item 1A. Risk Factors" in the Company’s Annual Report on Form 10-K for the year ended December 31, 2020.2021.
Operating Activities
Net cash flows provided by operating activities were $185.9 million for the three months ended March 31, 2022 compared to $229.6 million for the three months ended March 31, 2021 compared to $249.3 million for the three months ended March 31, 2020.2021. The decrease was primarily driven by higher interest payments and the timing of working capital receipts and payments.
Investing Activities
Net cash flows used in investing activities were $142.5 million for the three months ended March 31, 2022 compared to $70.7 million for the three months ended March 31, 2021 compared to $196.32021. Investing activities increased by approximately $71.8 million for the three months ended March 31, 2020. Capital expenditures decreased by approximately $91.1 million for the three months ended March 31, 2021,2022 as compared to the three months ended March 31, 2020,2021, primarily due to decreased spending on the Hammerhead pipeline and various wellhead gathering and transmission projects. In addition, net cash flows used in investing activities for the three months ended March 31, 2021 decreased as a result of a decreasean increase in capital contributions to the MVP Joint Venture consistent with a lower level of construction activities for the MVP project.related to work completed in late 2021 and ongoing right-of-way maintenance, as well as an increase in capital expenditure spending on various wellhead gathering and water projects. See “Capital Requirements” below for a discussion of forecasted 20212022 capital expenditures and capital contributions to the MVP Joint Venture.
40
Table of Contents


Financing Activities

Net cash flows used in financing activities were $136.5 million for the three months ended March 31, 2022 compared to $135.0 million for the three months ended March 31, 2021 compared to $65.3 million for2021. For the three months ended March 31, 2020.2022, the primary uses of financing cash flows were net repayments on borrowings under the revolving credit facilities, and the payment of dividends to shareholders, while the primary source of financing cash flows was borrowings under the revolving credit facilities. For the three months ended March 31, 2021, the primary useuses of financing cash flows waswere the payment for retirement of the EQM Term Loans and termination of the Amended 2019 EQM Term Loan Agreement, the Company's purchase of an aggregate principal amount of $500 million of EQM's 2023 Notes pursuant to the Tender Offers and the payment of dividends to shareholders, while the primary sourcessource of financing cash flows were the issuance of the 2021 Senior Notes and borrowings under the Former Eureka Credit Facility. For the three months ended March 31, 2020, the primary uses of financing cash flows were the payment for retirement of the ETRN Term Loans and termination of the ETRN Term Loan Credit Agreement, payments on borrowings under the Amended EQM Credit Facility, the payments of dividends and distributions to shareholders and unitholders (including distributions paid to holders of EQM Series A Preferred Units) and the payments under the Share Purchase Agreements. The source of financing cash flows for the three months ended March 31, 2020 was borrowings on the Amended EQM Credit Facility.
Capital Requirements
The gathering, transmission and storage and water services businesses are capital intensive, requiring significant investment to develop new facilities and to maintain and upgrade existing operations.
For 2021, capital contributions to the MVP Joint VentureCapital expenditures in 2022 are expected to be approximately $265$390 million to $315 million depending on timing of the construction of the MVP project and approximately $10 million related to the MVP Southgate project, and capital expenditures are expected to be $335 million to $385$440 million (including approximately $20 million attributable to the noncontrolling interest in Eureka Midstream). The Company expects to make capital contributions to the MVP Joint Venture in 2022 of approximately $175 million to $225 million for purposes of the MVP project primarily related to work completed in late 2021 and ongoing work required for right-of-way maintenance and approximately $5 million related to the MVP Southgate project. Capital contributions payable to the MVP Joint Venture are accrued upon the issuance of a capital call by the MVP Joint Venture. The Company's futureshort-term and long-term capital investments may vary significantly from period to period based on the available investment opportunities, the timing of the construction of the MVP, MVP Southgate and other projects, and maintenance needs. The Company expects to fund futureshort-term and long-term capital expenditures and capital contributions primarily through cash on hand, cash generated from operations, andavailable borrowings under its subsidiaries' credit facilities.facilities and its access to banking and capital markets.
See Note 10 for a discussion of the reduction of commitments under the Amended EQM Credit Facility pursuant to the Third Amendment.
Credit Facility Borrowings
See Note 86 and Note 10 to the consolidated financial statements for discussion of the Amended EQM Credit Facility, the Amended 2019 EQM Term Loan Agreement (prior to its termination) and the 2021 Eureka Credit Facility.
See Note 12 for discussion of the Second Amendment (as defined in Note 12) to the Amended EQM Credit Facility.

4130
Table of Contents


Security Ratings
The table below sets forth the credit ratings for EQM's debt instruments at March 31, 2021.2022.
EQM
Senior Notes
Rating ServiceRatingOutlook
Moody'sBa3Negative
S&PBB-Stable
FitchBBNegative

In January 2021, each of Moody's, S&P, and Fitch affirmed EQM's credit ratings in connection with the issuance of the 2021 Senior Notes. There were no changes to EQM's credit ratings during the three months ended March 31, 2021.2022. EQM's credit ratings are subject to revision or withdrawal at any time by the assigning rating organization, and each rating should be evaluated independently of any other rating. The Company cannot ensure that a rating will remain in effect for any given period of time or that a rating will not be lowered or withdrawn entirely by a credit rating agency if, in its judgment, circumstances so warrant, including in connection with the MVP project or the creditworthiness of EQM's customers, including EQT. As of March 31, 2021, EQT's public debt had credit ratings of BB from S&P (with a stable outlook), Ba2 from Moody's (with a stable outlook) and BB from Fitch (with a positive outlook).warrant. If any credit rating agency downgrades or withdraws EQM's ratings, including for reasons relating to the MVP project (such as delays in the targeted full in-service date of the MVP project or increases in such project’s targeted costs), EQM’s leverage or credit ratings of the Company's customers, the Company's access to the capital markets could become more challenging, borrowing costs will likely increase, the Company may be required to provide additional credit assurances (the amount of which may be substantial), including the Cash Option Letter of Credit, in support of commercial agreements such as joint venture agreements, and the potential pool of investors and funding sources may decrease. In order to be considered investment grade, a company must be rated Baa3 or higher by Moody's, BBB- or higher by S&P, or BBB- or higher by Fitch. All of EQM's credit ratings are considered non-investment grade.
Commitments and Contingencies
In the ordinary course of business, various legal and regulatory claims and proceedings are pending or threatened against the Company and its subsidiaries. While the amounts claimed may be substantial, the Company is unable to predict with certainty the ultimate outcome of such claims and proceedings. The Company accrues legal and other direct costs related to loss contingencies when incurred. The Company establishes reserves whenever it believes it to be appropriate for pending matters. Furthermore, after consultation with counsel and considering available insurance, the Company believes that the ultimate outcome of any matter currently pending against it or any of its consolidated subsidiaries will not materially affect its business, financial condition, results of operations, liquidity or ability to pay dividends to its shareholders.
See "The regulatory approval process for the construction of new midstream assets is very challenging, has significantly increased costs and delayed targeted in-service dates, and decisions by regulatory and judicial authorities in pending or potential proceedings couldare likely to impact our or the MVP Joint Venture's ability to obtain or maintain in effect all approvals and authorizations necessary to complete certain projects on the targeted time frame or at all or our ability to achieve the expected investment returns on the projects." under "Item 1A. Risk Factors" in the Company's Annual Report on Form 10-K for the year ended December 31, 20202021 and Part II, "Item 1. Legal Proceedings" in Part II of this Quarterly Report on Form 10-Q for discussion of certain litigation and regulatory proceedings, including related to the MVP and MVP Southgate projects.
See Note 16 to the annual consolidated financial statements included in the Company's Annual Report on Form 10-K for the year ended December 31, 20202021 for further discussion of the Company's commitments and contingencies.
Dividends
On April 27, 2021,26, 2022, the Board declared cash dividends for the first quarter of 20212022 of $0.15 per common share and $0.4873 per Equitrans Midstream Preferred Share in each case, payable on May 14, 2021 to shareholders of record at the close of business on May 5, 2021.4, 2022.
Critical Accounting Policies and Estimates
The Company's critical accounting policies are described in "Item 7. Management's Discussion and Analysis of Financial Condition and Results of Operations" contained in the Company's Annual Report on Form 10-K for the year ended December 31, 2020.2021. Any new accounting policies or updates to existing accounting policies as a result of new accounting
42
Table of Contents


pronouncements have been included in the notes to the Company's consolidated financial statements in Part I, "Item 1. Financial Statements" of this Quarterly Report on Form 10-Q. The application of the Company's critical accounting policies may require managementare considered critical due to makethe significant judgments and estimates about the amounts reflectedused in the preparation of the Company's consolidated financial statements. Management uses historical experience
31
Table of Contents

statements and all available information to make these estimates and judgments. Different amountsthe material impact on the results of operations or financial condition. Actual results could be reported using different assumptionsdiffer from those judgments and estimates.
Item 3. Quantitative and Qualitative Disclosures About Market Risk
Interest Rate Risk. Changes in interest rates affect the amount of interest the Company earns on cash, cash equivalents and short-term investments and the interest rates EQM and Eureka Midstream pay on borrowings under their respective revolving credit facilities. The Amended EQM Credit Facility and the 2021 Eureka Credit Facility provide for variable interest rates and thus expose the Company, through EQM and Eureka, Midstream, to fluctuations in market interest rates. In addition, EQM's interest rates under the Amended EQM Credit Facility are impacted by changes in EQM's credit ratings (which may be caused by factors outside of EQM's control). Eureka's interest rates under the 2021 Eureka Credit Facility are also impacted by changes in Eureka's Consolidated Leverage Ratio (as defined in the 2021 Eureka Credit Facility) which may fluctuate based on Eureka Midstream's liquidity needs. Suchneeds or operating results. Accordingly, changes in interest rates may accordingly impact the Company's results of operations and liquidity. Further, changes in interest rates may affect the dividend payable on Equitrans Midstream Preferred Shares after March 31, 2024, which could affect the amount of cash the Company has available to make quarterly cash dividends to its shareholders. Additionally, on April 16, 2021, EQM executed the Second Amendment to the Amended EQM Credit Facility, which, among other things, increased the interest rates applicable to the borrowings under the facility. EQM's senior notes are fixed rate and thus do not expose the Company to fluctuations in market interest rates. Changes in interest rates do affect the fair value of EQM's fixed rate debt. See Notes 86 and 97 to the consolidated financial statements for discussionsdiscussion of borrowings and for discussion of fair value measurements, respectively. See Note 12 for discussion of the Second Amendment (as defined in Note 12) to the Amended EQM Credit Facility. EQM and Eureka may from time to time hedge the interest on portions of borrowings under the revolving credit facilities, as applicable, in order to manage risks associated with floating interest rates (however, there may be no assurance that such hedges will fully mitigate interest rate risk).
See also "Changes in the method of determining the London Interbank Offered Rate (LIBOR), or the replacement of the LIBOR with an alternative reference rate, may adversely affect interest expense related to outstanding debt." included in "Item 1A. Risk Factors" in the Company's Annual Report on Form 10-K for the year ended December 31, 2020.
Credit Risk. The Company is exposed to credit risk, which is the risk that it may incur a loss if a counterparty fails to perform under a contract. The Company actively manages its exposure to credit risk associated with customers through credit analysis, credit approval and monitoring procedures. For certain transactions, the Company requests letters of credit, cash collateral, prepayments or guarantees as forms of credit support. Equitrans, L.P.'s FERC tariffs require tariff customers that do not meet specified credit standards to provide three months of credit support; however, the Company is exposed to credit risk beyond this three-month period when its tariffs do not require its customers to provide additional credit support. For some of the Company's long-term contracts associated with system expansions, it has entered into negotiated credit agreements that provide for other credit support if certain credit standards are not met. The Company has historically experienced only minimal credit losses in connection with its receivables.
The Company is exposed to the credit risk of its customers, including EQT. Asits largest customer, EQT, including as a result of December 31, 2020, EQT had $0.8 billion of letters ofchanges in customer credit outstanding under its revolving credit facility (inclusive of an $83.6 million letter of credit issuedratings, liquidity and access to the MVP Joint Venture).capital markets. At March 31, 2021,2022, EQT's public senior debt had investment grade credit ratings from Standard & Poor's Global Ratings and Fitch Ratings and a non-investment grade credit ratings. See "Security Ratings" under Part I, "Item 2. Management's Discussion and Analysis of Financial Condition and Results of Operations" for further information regarding EQT's credit ratings.
See Note 6 for information regarding the Credit Letter Agreement and associated EQT credit rating requirements.from Moody's Investor Services. In addition, EQT has guaranteed the payment obligations of certain of its subsidiaries, up to a maximum amount of $115 million, $131 million and $30 million related to gathering, transmission and water services, respectively, across all applicable contracts, for the benefit of the subsidiaries of the Company providing such services. See Note 15 to the annual consolidated financial statements included in the Company's Annual Report on Form 10-K for the year ended December 31, 20202021 for further discussion of the Company's exposure to credit risk.

See "Item 1A. Risk Factors" in the Company's Annual Report on Form 10-K for the year ended December 31, 2020 and "Gulfport Bankruptcy" under "Outlook" in this Quarterly Report on Form 10-Q for information on Gulfport's bankruptcy proceedings.

Commodity Prices. The Company's business is dependent on continued natural gas production and the availability and development of reserves in its areas of operation. Low pricesPrices for natural gas and NGLs, including those resulting from regional
43
Table of Contents


basis differentials, have previously adversely affected, and may in the future adversely affect, timing of development of additional reserves and production that is accessible by the Company’s pipeline and storage assets, which also negatively affects the Company’s water services business, and may affect the creditworthiness of the Company’s customers. Lower regional
Increases in natural gas prices could also cause producersdo not necessarily result in corresponding increases to determine in the future that drilling activities in areas outside of the Company's current areas of operation are strategically more attractive to them.

Natural gas and NGL prices affect capital spending levelsproduction forecasts of the Company's customers which in turn affect production levels and, accordingly, demand foras of the date of this Quarterly Report on Form 10-Q, the Company's services and therefore its results of operations. Certain oflargest customers have continued to maintain their production forecasts without significant increases. Even at commercially attractive natural gas prices, the Company’s customers, including EQT and Range Resources, have announced in February 2021 modest capital spending forecast increases as compared to 2020 actual capital expenditures. Although EQT announced a modest increase in its 2021 capital expenditure forecast compared to EQT's 2020 actual capital expenditures, EQT's 2021 sales volume forecast is approximately flat relative to its pro-forma 2020 sales volume (adjusted for acreage acquired by EQT from Chevron U.S.A Inc. in 2020). SuchCompany's customers may announce lower capital spending in the futurestill maintain flat or modest increases to production forecasts based on commodity prices,various factors, which could include regional takeaway capacity limitations, access to capital, investor expectations regarding free cash flow, a desire to reduce or refinance leverage (including the perceived ability to do so) or other factors. Additionally, prices may decline based on numerous factors, including levels of associated gas. See also “Decreases in production of natural gas in our areas of operation, whether as a result of producer corporate capital allocation strategies, lower regional natural gas prices, regional takeaway constraints, and/or other factors, have adversely affected, and in the future could adversely affect, our business and operating results and reduce our cash available to pay cash dividends to our shareholders.” and "The lack of diversification of our assets and geographic locations could adversely affect us." under "Item 1A. Risk Factors" in the Company's Annual Report on Form 10-K for the year ended December 31, 2021.
32
Table of Contents

Relatedly, lowerLower natural gas prices, particularly in the Appalachian region, have in the past caused, and may in the future cause, certain producers, including customers of the Company, to determine to reduce or hold generally steady their rig count (and thereby delay or not increase production), delay turning wells in line, temporarily shut in portions of their production or otherwise take actions to slow production growth and/or reduce production, which when effected by the Company's producer customers reduces the demand for, and usage of, the Company’s services. For instance, temporary production curtailments effected in 2020 by EQT and certain other Company customershave previously resulted in a decrease in the Company's volumetric-based fee revenues for portions of 2020.revenues. An extended period of low natural gas prices and/or a slow or inconsistent recovery ofinstability in natural gas prices in 2021 or future periods, including locally,especially in the Appalachian region, or other factors, could cause EQT or other producers to take similar actionscurtail production in the future, which could have a significant negative effect on the demand for the Company's services and therefore its results of operation. operations. Additionally, lower natural gas prices (including regionally), corporate capital allocation strategies or regional takeaway constraints, could cause producers to determine in the future that drilling activities in areas outside of the Company's current areas of operation are strategically more attractive to them.
Many of the Company’s customers, including EQT, have entered into long-term firm reservation gathering, transmission and gatheringwater contracts or contracts with MVCs on the Company's systems and approximately 66%71% of the Company’sCompany's operating revenuerevenues for the three months ended March 31, 20212022 was generated by firm reservation fees. As a result, the Company believes that the effect of temporary declines in volumes of gas gathered, transported or stored on its systems may be mitigated because firm reservation fee revenues are paid regardless of volumes supplied to the system by customers (although significant declines in gas production in the Company's areas of operations would adversely affect the Company's results of operations, financial condition and liquidity as approximately 34%29% of the Company’s operating revenues for the three months ended March 31, 20212022 was generated by generated by volumetric-based fee revenues).
See "
Our exposure to direct commodity price risk may increase in the future." under "Item 1A. Risk Factors" in the Company's Annual Report on Form 10-K for the year ended December 31, 2021.
Price declines and sustained periods of low natural gas and NGL prices could have an adverse effect on the creditworthiness of the Company's customers and related ability to pay firm reservation fees under long-term contracts and/or affect, as discussed above, activity levels and, accordingly, volumetric-based fees, which could affect the Company’s results of operations, liquidity or financial position. For example, each of S&P, Moody's and Fitch took negative ratings actions on EQT during 2020, citing, among other things, lower natural gas price assumptions and current and future financing needs (although all three ratings agencies later took positive action on EQT citing, among other things, subsequent debt reduction and improvements in natural gas fundamentals). On November 13, 2020, Gulfport filed for Chapter 11 bankruptcy protection, as further described above under "Gulfport Bankruptcy." Credit risk and related management is further discussed above under “Credit Risk” in Part I, “Item 3. Quantitative and Qualitative Disclosures About Market Risk” of this Quarterly Report on Form 10-Q.

Unless the Company is successful in attracting and retaining new customers, the Company's ability to maintain or increase the capacity subscribed and volumes transported, gathered or provided on its systems will be dependent on receiving consistent or increasing commitments and production from its existing customers, which may be impacted by commodity prices, including regional commodity prices.prices and/or other factors, including corporate capital allocation strategies. While EQT has dedicated a substantial portion of its core acreage to the Company and has entered into long-term firm gathering and transmission contracts and contracts with MVCs on certain of the Company's systems, EQT may determine in the future that drilling or continuing to produce gas from existing wells in the Company's areas of operations is not economical above the amount to fulfill its required MVCs. For example, in 2020, EQT publicly disclosed that it had madeMVCs or otherwise strategically determine to curtail volumes on the strategic decision to temporarily curtail significant portions of its production, and certain other Company customers also curtailed portions of their production during 2020.Company's systems. Other than with respect to its MVCs and other firm commitments under existing contracts, EQT is under no contractual obligation to continue to develop its acreage dedicated to the Company. See also Note 5 to the consolidated financial statements"Outlook" for a discussion of the EQT Global GGA and the 2021 Water Services Letter Agreement.
The fair value of the Company’s derivative instruments is, largelyin part, determined by estimates of the NYMEX Henry Hub natural gas forward price curve. A hypothetical 10% increase in NYMEX Henry Hub natural gas futures prices would increase the valuation of the Company’s derivative instruments by $15.8approximately $5.5 million, while a hypothetical 10% decrease in NYMEX Henry Hub natural gas futures prices would decrease the valuation of the Company’s derivative instruments by $17.0approximately $6.2 million. This fair value change assumes volatility based on prevailing market parameters at March 31, 2021.2022. See Notes 5"Outlook" and 9 to the consolidated financial statementsNote 7 for a discussion of the Henry Hub cash bonus payment provision.
44
Table of Contents


For further discussion of commodity prices and related risks, see "Commodity Prices" under "Outlook” in this Quarterly Report on Form 10-Q and "Our exposure to direct commodity price risk may increase in the future." and "Decreases in production of natural gas in our areas of operation, whether as a result of producer corporate capital allocation strategies, lower regional natural gas prices, regional takeaway constraints, and/or other factors have adversely affected, and in the future decreases could further adversely affect, our business and operating results and reduce our cash available to pay cash dividends to our shareholders" and "The lack of diversification of our assets and geographic locations could adversely affect us.", each under "Item 1A. Risk Factors" in the Company's Annual Report on Form 10-K for the year ended December 31, 2020.2021.
Other Market Risks. The Amended EQM Credit Facility as amended by the Second Amendment, is underwritten by a syndicate of 21 financial institutions eachuntil the Earlier Maturity Date, and a syndicate of which14 financial institutions from the Earlier Maturity Date through the Later Maturity Date. The 2021 Eureka Credit Facility is underwritten by a syndicate of 16 financial institutions. Each financial institution is obligated to fund its pro rata portion of any borrowings by EQM. NoEQM or Eureka, as applicable. In each case, no one lender of the financial institutions in the syndicate holds more than 10% of thesuch facility. EQM's and Eureka's respective large syndicate group
33
Table of Contents

groups and relatively low percentage of participation by each lender is expected to limit the Company's and Eureka's respective exposure to disruption or consolidation in the banking industry.

The Eureka Credit Facility is underwritten by a syndicate of 14 financial institutions, each of which is obligated to fund its pro-rata portion of any borrowings by Eureka. Only one lender of the financial institutions in the syndicate holds more than 10% of the facility (approximately 13% held by ABN AMRO Capital USA LLC). Eureka's large syndicate group and relatively low percentage of participation by each lender is expected to limit Eureka's exposure to disruption or consolidation in the banking industry.

See Note 8 to the consolidated financial statements and "Capital Resources and Liquidity" in Part I, "Item 2. Management's Discussion and Analysis of Financial Condition and Results of Operations"10 for additional information on the Amended EQM Credit Facility and the Eureka Credit Facility. See Note 12 fora discussion of the SecondThird Amendment (as defined in Note 12) to the Amended EQM Credit Facility.

4534
Table of Contents


Item 4. Controls and Procedures
Evaluation of Disclosure Controls and Procedures. Under the supervision and with the participation of management, including the Company’s Principal Executive Officer and Principal Financial Officer, an evaluation of the Company’s disclosure controls and procedures (as defined in Rule 13a-15(e) under the Exchange Act) was conducted as of the end of the period covered by this report. Based on that evaluation, the Principal Executive Officer and Principal Financial Officer concluded that the Company’s disclosure controls and procedures were effective as of the end of the period covered by this report.
Changes in Internal Control over Financial Reporting. There were no changes in the Company's internal control over financial reporting (as such term is defined in Rule 13a-15(f) under the Exchange Act) that occurred during the first quarter of 20212022 that have materially affected, or are reasonably likely to materially affect, the Company's internal control over financial reporting.
4635
Table of Contents


PART II.  OTHER INFORMATION
Item 1. Legal Proceedings
In the ordinary course of business, various legal and regulatory claims and proceedings are pending or threatened against the Company and its subsidiaries. While the amounts claimed may be substantial, the Company is unable to predict with certainty the ultimate outcome of such claims and proceedings. The Company accrues legal and other direct costs related to loss contingencies when incurred. The Company establishes reserves whenever it believes it to be appropriate for pending matters. Furthermore, after consultation with counsel and considering available insurance, the Company believes that the ultimate outcome of any matter currently pending against it or any of its consolidated subsidiaries will not materially affect its business, financial condition, results of operations, liquidity or ability to pay dividends to its shareholders.
Hammerhead Pipeline Dispute

See “Hammerhead Pipeline” under Part I, “Outlook” in “Item 2. Management’s Discussion and Analysis of Financial Condition and Results of Operations” for additional information.
Environmental Proceedings
SwartsPratt Storage Field. Field. On September 2, 2020,October 31, 2018, a gas explosion occurred in Morgan Township, Greene County, Pennsylvania (the Incident). Following the explosion, the Pennsylvania Department of Environmental Protection (the PADEP) notified, the Company that it was assessing a stipulated penalty inPennsylvania Public Utilities Commission and the amount of $490,000 due toPHMSA began investigating the alleged failure of the Company to submit information required pursuant to an October 29, 2019 Consent Order and Agreement.Incident. The Company disputed the PADEP’s claim and sought initial dispute resolution proceedings based on the Company’s position that it had submitted the information multiple times since October 2019. On September 29, 2020, the PADEP notified the Company that it was no longer pursuing penalties arisingis awaiting further direction or inquiry from the alleged violation referenced in the September 2, 2020 letter, butPADEP. If a penalty is imposed it did not officially withdraw the stipulated penalty. Despite the PADEP’s notification that it was no longer pursuing the stipulated penalty, as a result of the PADEP not officially withdrawing the stipulated penalty, the PADEP could pursue the stipulated penalty in the future. If penalties are pursued and ultimately imposed, these penalties could result in monetary sanctions in excess of $300,000. However, the Company does not believe that the penalties,penalty, if imposed, wouldwill have a material impact on the Company's financial condition, results of operations or liquidity.liquidity of the Company. Additionally, the Company is responding to civil and criminal investigations related to the Incident.
Separately, on April 8,EPA Finding of Violation. On October 28, 2021, the PADEP notifiedCompany submitted its annual report to the EPA pursuant to New Source Performance Standards subpart OOOOa (Subpart OOOOa) of the Clean Air Act that included deviations from Subpart OOOOa requirements related to certain high bleed controllers that were discovered in October 2020. On March 1, 2022, EPA issued a Finding of Violation for alleged violations of Subpart OOOOa in response to the deviations included in the annual report. Although all high bleed controllers identified in the Finding of Violation have been converted to compressed air or low bleed devices that comply with Subpart OOOOa, the Company thatcannot predict what criminal and/or civil enforcement action, if any, EPA may pursue against the Company. If a penalty is imposed, it considered certain aspects of the storage field to be out of compliance due to an alleged failure to plug or recondition wells within 2,000 feet of ongoing coal mining activities by CONSOL Energy Inc. and that a number of wells on the property allegedly did not meet current plugging standards. The Company disputes these claims and is working with the PADEP and CONSOL Energy Inc. to resolve these issues. Based on the discussion with the PADEP, the Company anticipates a notice of violation (NOV) will be issued. If penalties are pursued and ultimately imposed, the penalties could result in monetary sanctions in excess of $300,000. However, the Company does not believe that the penalties,penalty, if imposed, would have a material impact on the Company's financial condition, results of operations or liquidity.
PADEP Notice of Violations, Beta System. In the fourth quarter of 2020 and the first quarter of 2021, the Company received several NOVs from the PADEP related to the Company’s Beta gathering system. The NOVs include (i) a lack of permanent stabilization on two repaired slip areas, (ii) five current slip areas in need of repair that have not been repaired due to the PADEP’s ongoing review of the slip repair plans, (iii) an unpermitted disturbance that occurred during construction in 2017, and (iv) failure to implement and maintain erosion and sediment best management practices to minimize the potential for accelerated erosion and sedimentation. The Company also voluntarily notified the PADEP of other unpermitted, disturbed areas on the Beta gathering system. The Company is continuing to pursue negotiations with the PADEP. The Company expects that this matter could result in monetary penalties in excess of $300,000, but does not believe that if imposed the penalties will have a material impact on the Company's financial condition, results of operations or liquidity.liquidity of the Company.
MVP Matters
The MVP Joint Venture is currently defending certain agency actions and judicial challenges to the MVP, that must be resolved beforeany of which could affect the ability to complete or operate the project, can be completed, including the following:

•Sierra Club, et al. Petitioners v. State Water Control Board, et al. Respondents and Mountain Valley Pipeline, Intervenor, Docket No. 21-2425, Fourth Circuit Court of Appeals (Fourth Circuit). On December 20, 2021, the Virginia Department of Environmental Quality (VADEQ) certified that the MVP project would satisfy Virginia’s water quality standards based on its comprehensive nine-month review of the MVP Joint Venture’s Joint Permit Application (VA 401 Permit). On December 22, 2021, Petitioners filed their petition challenging the VADEQ’s approval of the VA 401 Permit with the Fourth Circuit. On December 22, 2021, the Petitioners filed a request for an administrative stay with the VADEQ which was denied on January 4, 2022. On January 4, 2022, the Petitioners filed a petition with the Fourth Circuit seeking a judicial stay of the VA 401 Permit pending a decision on the merits. On February 11, 2022, Petitioners withdrew the stay petition. Briefing is scheduled to be completed by June 2022 and oral argument to occur in the fall of 2022. If the challenge were successful on its merits, it could result in the MVP Joint Venture's VA 401 Permit being delayed or vacated and/or additional legal proceedings, the outcome of which the Company cannot predict, and cause a delay or further delay in the targeted full in-service date for the MVP project (and consequent impacts related to such delay), or otherwise adverse effects.
•Sierra Club, et al. Petitioners v. U.S. Army CorpsWest Virginia Department of Eng'rs (Huntington District) Fourth Circuit Court of Appeals (Fourth Circuit), Case No. 20-2039 and Sierra Club,Environmental Protection, et al. v. U.S. Army CorpsRespondents and Mountain Valley Pipeline, Intervenor, Docket No. 22-1008, Fourth Circuit. On December 30, 2021, the West Virginia Department of Eng'rs (Norfolk District),Environmental Protection (WVDEP) certified that the MVP project would satisfy West Virginia’s water quality standards based on its comprehensive nine-month review of the MVP Joint Venture’s Joint Permit Application (WV 401 Permit). On January 3, 2022, Petitioners filed their petition challenging the WVDEP’s approval of the WV 401 Permit with the Fourth Circuit Court of Appeals, Case No. 20-2042. In February 2018,Circuit. On January 4, 2022, the Sierra ClubPetitioners filed a lawsuit inrequest for an administrative stay with the WVDEP which was denied on January 11, 2022. On January 11, 2022, Petitioners filed a petition with the Fourth Circuit againstseeking a judicial stay of the Army Corps in Sierra Club, et al. v. U.S. Army Corps of Engineers, et al., consolidated under Case No. 18-1173.WV 401 Permit pending a decision on the merits. The lawsuit challenged the verificationstay petition was denied by the Huntington DistrictFourth Circuit on February 8, 2022. Briefing is scheduled to be completed by June 2022 and oral argument to occur in the fall of 2022. If the Army Corps that Nationwide Permit 12, which generally authorizes discharges of dredge or fill material into waters ofchallenge were successful on its merits, it could result in the United States and the construction ofMVP Joint
4736
Table of Contents


pipelines across such waters under Section 404Venture's WV 401 Permit being delayed or vacated and/or additional legal proceedings, the outcome of which the Clean Water Act, could be utilizedCompany cannot predict, and cause a delay or further delay in the Huntington District (which covers all but the northernmost area of West Virginia)targeted full in-service date for the MVP project. The crux of Sierra Club's position was that the MVP Joint Venture, pursuantproject (and consequent impacts related to its FERC license, planned to use a certain methodology (dry open cut creek crossing methodology) to construct the pipeline across streams in West Virginia that would take considerably longer than the 72 hours allowed for such activities pursuant to the terms of West Virginia's Clean Water Act Section 401 certification for Nationwide Permit 12. A three-judge panel of the Fourth Circuit agreed with the Sierra Club and on October 2, 2018, issued a preliminary order stopping the construction in West Virginia of that portion of the pipeline that is subject to Nationwide Permit 12. In August 2018, the WVDEP initiated an administrative process to revise its 401 Water Quality Certification for the Army Corps Nationwide Permits and requested public comment to, among other things, specifically revise the 72-hour limit for stream crossings noted as problematic by the Fourth Circuit as well as other conditions (the WVDEP 401 Rulemaking Proceedings). Pending the resolution of the WVDEP 401 Rulemaking Proceedings, the Army Corps' Pittsburgh District and Norfolk District (each of which had also verified use of Nationwide Permit 12 by the MVP Joint Venture) suspended their verifications that allowed the MVP Joint Venture to use Nationwide Permit 12 for stream and wetlands crossings in northern West Virginia and Virginia, respectively. On April 24, 2019, the WVDEP submitted a modification to its 401 Water Quality Certification developed in the WVDEP 401 Rulemaking Proceedings to the EPA for approval, which approval was received in August 2019. The Army Corps approved the WVDEP's modification on January 24, 2020, and the MVP Joint Venture submitted a new permit application to the Army Corps on January 28, 2020. On September 25, 2020, the Huntington and Pittsburgh districts approved MVP Joint Venture’s Nationwide Permit 12 and the Norfolk district lifted its suspension of the MVP Joint Venture's Nationwide Permit 12. On September 28, 2020, Appalachian Mountain Advocates, on behalf of Sierra Club and certain other petitioners, filed a petition for review of the Huntington and Norfolk permits. On October 5, 2020, Appalachian Mountain Advocates requested from the Fourth Circuit an administrative stay of the Army Corps' verifications to the MVP Joint Venture's Nationwide Permit 12. On November 9, 2020, the Court entered an order granting the motion to stay the verifications and issued a written opinion on December 1, 2020 on the issuance of the stay. While the case was scheduled to be fully briefed and argued by March 31, 2021, on February 19, 2021, the MVP Joint Venture, as part of its initiated broader strategy to obtain authorization for stream and wetland crossings discussed above under Part I, "Outlook" in "Item 2. Management's Discussion and Analysis of Financial Condition and Results of Operations," requested that the Army Corps' Huntington, Pittsburgh, and Norfolk Districts administratively revoke the previously-issued Nationwide Permit 12 verifications for the project. On March 2, 2021, the Army Corps revoked the Nationwide Permit 12 verifications for the project in accordance with the MVP Joint Venture's request. The parties have agreed to the dismissal of the existing litigation challenging the now-revoked verifications as moot pending resolution of administrative issues unrelated to the MVP.

delay), or otherwise adverse effects.
•Jefferson National Forest Crossing and Associated Authorizations. In a different Fourth Circuit appeal, Sierra Club, et al. v. U.S. Forest Service, et al., consolidated under Case No. 17-2399, Fourth Circuit Court of Appeals, filed in December 2017, the Sierra Club challenged a Bureau of Land Management (BLM) decision to grant a right-of-way to the MVP Joint Venture and a U.S. Forest Service (USFS) decision to amend its management plan to accommodate the MVP, both of which affect the MVP's approximate 3.5-mile segment in the Jefferson National Forest (JNF) in Virginia. On July 27, 2018, agreeing in part with the Sierra Club, the Fourth Circuit vacated the BLM and USFS decisions, finding fault with the BLM's analysis of the practicality of alternate routes and the USFS' analysis of erosion and sedimentation effects. The USFS published a draft Supplemental Environmental Impact Statement (SEIS) to the 2017 FERC Final Environmental Impact Statement for MVP in the Federal Register on September 25, 2020 with a public comment period that closed on November 9, 2020. On December 11, 2020, the USFS published a Final Supplemental Environmental Impact StatementSEIS that addressed the issues raised in the prior proceedings and evaluated the most recent sedimentation analysis submitted to the agency consistent with the findings presented in MVP’s Biological Opinion and Incidental Take Statement issued by the Department of the Interior's Fish and Wildlife Service (FWS) on September 4, 2020. See Appalachian Voices, et al. v. U.S. Dep’t of Interior below for additional information. On January 11, 2021, the MVP Joint Venture received final approval of the Record of Decision from the USFS and, on January 15, 2021, the BLM issued the required right-of-way permit for the MVP’s 3.5-mile segment in the JNF in Virginia (the JNF Right-of-Way). On January 11, 2021, Sierra Club, et al. filed a petition with the Fourth Circuit to reverse the USFS approval of the Record of Decision and, on January 15, 2021, filed a petition with the Fourth Circuit challenging BLM’s grant of the JNF Right-of-Way. See Wild Virginia, et al. v. United States Forest Service, et al., No. 21-1039(L). The Fourth Circuit consolidated the challenges to the Record of Decision and the JNF Right-of-Way and briefing is to be completedwas completed. Oral argument occurred on October 29, 2021. On January 25, 2022, the Fourth Circuit, agreeing in part with the petitioners, vacated and remanded the Record of Decision and the JNF Right-of-Way, finding fault with (i) the USFS’ and BLM’s consideration of certain data from the U.S. Geological Survey and (ii) the USFS’ and BLM’s authorization of the use of conventional bores for stream crossings within the JNF based on a variance issued by the endFERC, and, as a result of May 2021.such issues, (iii) the USFS’ amendments in connection with the Record of Decision to the Jefferson Forest plan. On March 11, 2022, the MVP Joint Venture requested that the Fourth Circuit review the January 25, 2022 decision en banc, which rehearing was denied by the Fourth Circuit on March 25, 2022. The vacatur of the Record of Decision and the JNF Right-of-Way caused a delay in the targeted full in-service date for the MVP project (and consequent impacts relating to such delay). The Company cannot predict whether and when any new authorizations will be received from the USFS and BLM and, if received, the result of any challenge to such authorizations.
On August 3, 2018, citing the court's vacatur and remand in Sierra Club, et al. v. U.S. Forest Service, et al., consolidated under Case No. 17-2399, the FERC issued a stop work order for the entire pipeline pending the agency actions on remand. The FERC modified its stop work order on August 29, 2018 to allow work to continue on all but approximately 25 miles of the project (the Exclusion Zone). On October 10, 2018, the Fourth Circuit granted a petition for rehearing filed by the MVP Joint Venture for the limited purpose of clarifying that the July 27, 2018 order did not vacate the portion of the BLM's Record of Decision authorizing a right-of-way and temporary use permit for the MVP
48
Table of Contents


to cross the Weston and Gauley Bridge Turnpike Trail in Braxton County, West Virginia. On October 15, 2018, the MVP Joint Venture filed with the FERC a request to further modify the August 3, 2018 stop work order to allow the MVP Joint Venture to complete the bore and install the pipeline under the Weston and Gauley Bridge Turnpike Trail. On October 24, 2018, the FERC granted the MVP Joint Venture's request to further modify the stop work order and authorize construction. Additionally, on October 9, 2020, the FERC authorized construction to resume project-wide (as it had been stopped by the FERC on October 15, 2019 in relation to a separate matter discussed below), other than with respect to the Exclusion Zone, which requires additional authorization. On December 17, 2020, the FERC again modified the stop work order and authorized construction to resume in 17 miles of the Exclusion Zone. The Company cannot guarantee whether or when the FERC will act in respect of any or all of the remaining portions of the Exclusion Zone (although the MVP Joint Venture anticipates seeking FERC authorization to lift the Exclusion Zone stop work order should water body crossing authorizations be received as discussed above under "Outlook" in Part I, "Item 2. Management's Discussion and Analysis of Financial Condition and Results of Operations").Zone. The FERC's October 9, 2020 and December 17, 2020 actions are the subject of challenges filed by the Sierra Club in Sierra Club, et al. v. FERC, Case No. 20-1512 (consolidated with No. 21-1040), D.C. Circuit Court of Appeals on December 22, 2020 and January 25, 2021, respectively (a stay request filed by the Sierra Club on January 29, 2021 was denied by the Court of Appeals for the D.C. Circuit (DC Circuit) on February 19, 2021). As of the filing date of this Quarterly Report on Form 10-Q, a briefing scheduleBriefing in respect of Sierra Club, et al. v. FERC, Case No. 20-1512 (consolidated with No. 21-1040), D.C. Circuit Court of Appeals has not been set.was completed in January 2022 and oral argument occurred on April 7, 2022. If any of the challenges to the Record of Decision, the JNF Right-of-Way or the FERC's October 9, 2020 and December 17, 2020 orders are successful, it could result in the Record of Decision, the JNF Right-of-Way or the FERC's orders as applicable, being vacated and/or additional agency proceedings (the outcome of which the Company cannot predict) and cause a delay or further
37
Table of Contents

delay in the targeted full in-service date for the MVP project (and consequent impacts relating to such delay).

, or otherwise adverse effects.
•Challenges to FERC Certificate, Court of Appeals for DC Circuit. Multiple parties have sought judicial review of the FERC's order issuing a certificate of public convenience and necessity to the MVP Joint Venture and/or the exercise by the MVP Joint Venture of eminent domain authority. On February 19, 2019, the DC Circuit issued an order rejecting multiple consolidated petitions seeking direct review of the FERC order under the Natural Gas ActNGA and certain challenges to the exercise by the MVP Joint Venture of eminent domain authority in Appalachian Voices, et al. v. FERC, et al., consolidated under Case No. 17-1271. No petitions for rehearing or petitions for rehearing en banc were filed by the April 5, 2019 deadline. The mandate was issued on April 17, 2019. Another group of parties filed a complaint in the U.S. District Court for the District of Columbia asserting that the FERC's order issuing certificates is unlawful on constitutional and other grounds in Bold Alliance, et al. v. FERC, et al., Case No. 17-1822. The district court plaintiffs sought declaratory relief as well as an injunction preventing the MVP Joint Venture from developing its project or exercising eminent domain authority. In December 2017 and January 2018, the FERC and the MVP Joint Venture, respectively, moved to dismiss the petitions for lack of subject matter jurisdiction. The court granted the motion and dismissed plaintiffs' complaint on September 28, 2018. On October 26, 2018, plaintiffs appealed the decision in Case No. 17-1822 to the DC Circuit in Bold Alliance, et al. v. FERC, et al., Case No. 18-5322. On December 3, 2018, the FERC, as appellee, filed a joint motion with the appellants to hold Case No. 18-5322 in abeyance pending completion of the appeals of the final agency orders related to the MVP certificate in consolidated Case No. 17-1271 and Atlantic Coast Pipeline’s (ACP) certificate. The MVP Joint Venture filed a motion to dismiss the case as to some of the plaintiffs. On February 15, 2019, the DC Circuit entered an order holding this appeal in abeyance pending rulings on the appeals from the ACP and MVP FERC proceedings. Although the members of the ACP project announced the cancellation of that project on July 5, 2020, ACP's proceeding remains pending. Case No. 18-5322 remains in abeyance. Similarly, another group of parties filed a complaint in the U.S. District Court for the District of Columbia in Bohon et al. v. FERC et al., Case No. 20-00006, asserting that the delegation of authority to FERC under the NGA violates the nondelegation doctrine and separation-of-powers principle of the U.S. Constitution. The MVP Joint Venture and the FERC filed motions to dismiss which were granted by the court. On July 6, 2020, the landowners filed a notice of appeal to the DC Circuit in Case No. 20-5203. On November 30, 2020, appellants asked the DC Circuit to overturn the decision of the lower court. Oral argument before the DC Circuit was scheduled for March 29, 2021, but the court cancelled and held oral argument in abeyance and directed the parties to file motions to govern future proceedings following a decision by the U.S. Supreme Court in PennEast Pipeline Co. v. New Jersey, Case No. 19-1039.19-1039, which decision was published on June 29, 2021. Briefing in Bohon et al. v. FERC et al., Case No. 20-00006 on the significance of the PennEast Pipeline Co. opinion was completed on July 29, 2021. The DC Circuit issued an order on September 15, 2021 denying appellants' motion for summary reversal of the decision of the lower court and supplemental briefing was completed as of October 6, 2021. Oral argument occurred on December 15, 2021 and the parties are awaiting a decision. Due to the uncertainty regarding the timing of permitting and the outcome of legal challenges facing the MVP project, on August 25, 2020, the MVP Joint Venture filed a request with the FERC for and, on October 9, 2020, the FERC granted, an extension of time to complete the MVP project for an additional two years through October 13, 2022. On December 22, 2020, a challenge to the FERC’s action to grant an extension of time to complete the MVP project was filed in the DC Circuit in Sierra Club, et al. v. FERC, Case No. 20-1512 (consolidated with No. 21-1040, DC Circuit). On January 29, 2021, Sierra Club requested a stay of the FERC’s action to grant the MVP Joint Venture an extension of time to complete the MVP project from the DC Circuit, which stay request was denied by the DC Circuit on February 19, 2021. Briefing in Sierra Club, et al. v. FERC, Case No. 20-1512 (consolidated with No. 21-1040, D.C. Circuit), was completed in January 2022 and oral argument occurred on April 7, 2022. If any of these challenges were successful, it could result in the MVP Joint Venture's
49
Table of Contents


certificate of public convenience and necessity being vacated and/or additional proceedings before the FERC, the outcome of which the Company cannot predict.

predict, and cause a delay or further delay in the targeted full in-service date for the MVP project (and consequent impacts related to such delay), or otherwise adverse effects.
•Appalachian Voices, et al. v. U.S. Dep’t of Interior, et al., Fourth Circuit Court of Appeals, Case No. 20-2159. In August 2019, Wild Virginia and certain other petitioners filed a petition in the Fourth Circuit in Wild Virginia et al. v. United States Department of the Interior; Case No. 19-1866, to challenge the MVP Joint Venture’s Biological Opinion and Incidental Take Statement issued by FWS which was approved in November 2017 (the Original BiOp). On October 11, 2019, the Fourth Circuit issued an order approving the petitioners’ requested stay of the Original BiOp and holding the litigation in abeyance until January 11, 2020. On October 15, 2019, the FERC issued an order requiring the MVP Joint Venture to cease all forward-construction progress (the FERC modified this order on October 9, 2020 and December 17, 2020, which the Sierra Club has appealed to the DC Circuit as discussed above under "Jefferson National Forest Crossing and Associated Authorizations"). On September 4, 2020, FWS issued the MVP Joint Venture a new Biological Opinion and Incidental Take Statement (the New BiOp) for the MVP project and the Fourth Circuit
38
Table of Contents

subsequently dismissed the litigation regarding the Original BiOp. On October 27, 2020, Appalachian Voices et al. filed a petition with the Fourth Circuit challenging the New BiOp and filed a request for an administrative stay of the New BiOp with FWS, which FWS subsequently denied. On November 2, 2020, the petitioners filed a motion to stay the New BiOp with the Fourth Circuit. On November 18, 2020, the Fourth Circuit issued an order denying the requested stay. The matter was fully briefed as of March 19, 20212021. Oral argument occurred on October 29, 2021. On February 2, 2022, the Fourth Circuit vacated and oral argument is expected to be scheduled by June 2021. If this challenge were successful, it could result inremanded the New BiOp being vacated and/or additional proceedings (the outcomeholding, in part, that the FWS did not adequately analyze the environmental context for species at issue. On March 11, 2022, the MVP Joint Venture requested that the Fourth Circuit review the February 2, 2022 decision en banc, which rehearing was denied by the Fourth Circuit on April 1, 2022. The vacatur of which the Company cannot predict) and causeNew BiOp caused a delay in the targeted full in-service date for the MVP project (and consequent impacts relating to such delay).
Other Proceedings Relevant to the MVP Project
Grand Jury Subpoena. On January 7, 2019, the MVP Joint Venture The Company cannot predict whether and when a new BiOp will be received a letter from the U.S. Attorney's Office forFWS and, if received, the Western Districtresult of Virginia stating that it and the EPA were investigating potential criminal and/or civil violations of the Clean Water Act and other federal statutes as they relateany challenge to the construction of the MVP. The January 7, 2019 letter requested that the MVP Joint Venture and its members, contractors, suppliers and other entities involved in the construction of the MVP preserve documents related to the MVP generated from September 1, 2018 to the present. In a telephone call on February 4, 2019, the U.S. Attorney's Office confirmed that it had opened a criminal investigation. On February 11, 2019, the MVP Joint Venture received a grand jury subpoena from the U.S. Attorney's Office for the Western District of Virginia requesting certain documents related to the MVP from August 1, 2018 to the present. The MVP Joint Venture began a rolling production of documents responsive to the subpoena after the U.S. Attorney’s office narrowed its subpoena inquiry to five farms in Virginia containing twenty streams or wetlands. On March 4, 2021, the U.S. Department of Justice notified the MVP Joint Venture that it had concluded its investigation without an adverse determination to the MVP Joint Venture.such BiOp.
MVP Southgate Matters
The MVP Joint Venture is currently challenging or defending certain agency actions and judicial challenges to the MVP Southgate project that must be resolved beforein connection with the project, can be completed,in addition to working to address matters affecting the MVP, including the following:
•Sierra Club et al. v. FERC; Case No. 20-1427, DC Circuit. On June 18, 2020, the FERC issued an order granting a certificate of public convenience and necessity for the MVP Southgate project. However, the FERC, while authorizing the project, directed the Office of Energy Projects not to issue a notice to proceed with construction until necessary federal permits are received for the MVP project and the Director of the Office of Energy Projects lifts the stop-work order and authorizes the MVP Joint Venture to continue constructing the MVP project. Certain opposition parties subsequently requested rehearing of the certificate order. On August 20, 2020, the FERC issued an order denying requests for rehearing of that certificate order, and on September 17, 2020, the FERC issued an order addressing the arguments raised on rehearing. On October 9, 2020, Sierra Club, among other petitioners, filed an appeal of these orders with the DC Circuit. The matter is scheduled to behas been fully briefed by August 18, 2021.and oral argument was held on January 19, 2022 and the parties are awaiting a decision. If this challenge were successful, it could result in the MVP Southgate project’s certificate of public convenience and necessity being vacated and/or additional proceedings before the FERC, the outcome of which the Company cannot predict.predict, and cause a further delay to the MVP Southgate project (and consequent impacts relating to such delay), or otherwise adverse effects.
•Mountain Valley Pipeline, LLC v. North Carolina Department of Environmental Quality, No. 20-1971, Fourth Circuit Court of Appeals. On August 11, 2020, the North Carolina Department of Environmental Quality (NCDEQ) denied the MVP Southgate project’s application for a Clean Water Act Section 401 Individual Water Quality Certification and Jordan Lake Riparian Buffer Authorization and such denial was reissued by the NCDEQ on April 29, 2021. See "MVP Southgate Project" underincluded in "Outlook" inunder Part I, "Item 2. Management's Discussion and Analysis of Financial Condition and Results of Operations"Operation." for additional information. The Company is evaluating next steps, including the NCDEQ's April 29, 2021 actionsubmission of a new application for a Clean Water Act Section 401 Individual Water Quality Certification and Jordan Lake Riparian Buffer Authorization for the MVP Southgate project, but cannot guarantee whether the application, if the denial is challenged, or a new application, if submitted, will ultimately be
50
Table of Contents


approved or, if approved, whether conditions may be included as part of such approval or whether the application would then be further challenged.
•Mountain Valley Pipeline, LLC v. State Air Pollution Control Board et al., U.S. Court of Appeals for the Fourth Circuit. On December 3, 2021, the Virginia State Air Pollution Control Board (VAPCB) voted 5-2 to deny the air permit for the MVP Southgate project’s Lambert Compressor Station (the Lambert Air Permit). On December 31, 2021, the MVP Joint Venture filed a Petition for Review in the Fourth Circuit to review the VAPCB’s December 3, 2021 denial of the Lambert Air Permit. On March 29, 2022, the Fourth Circuit granted the MVP Joint Venture's request to withdraw its request to review the denial of the Lambert Air Permit.
5139
Table of Contents


Item 1A. Risk Factors
There have been no material changes from the risk factors previously disclosed in the Company's Annual Report on Form 10-K for the year ended December 31, 2020, other than the risks described below.2021.

Risks Related to Our Operations

Increasing scrutiny and changing stakeholder expectations in respect of ESG and sustainability practices may adversely impact our business and our stock price and expose us to new or additional risks.

Companies across all industries are facing increasing scrutiny from stakeholders related to their ESG and sustainability practices. Investor advocacy groups, certain institutional investors, investment funds and other influential investors are also increasingly focused on ESG and sustainability practices and matters and on the implications and social cost of their investments. Stakeholders’ increased focus and activism related to ESG and sustainability matters may potentially adversely affect our business, financial condition, results of operations, and liquidity, as well as our stock price, and expose us to new or additional risks, including as described below.

Increased focus on ESG and sustainability matters, particularly in respect of climate change and related demand for renewable and alternative energy, may hinder our access to capital given our fossil fuel-based operations and/or adversely affect demand for our services. See “If we or our subsidiaries are unable to obtain needed capital or financing on satisfactory terms, our ability to execute our business strategy and pay dividends to our shareholders may be diminished. Additionally, financing transactions may increase our financial leverage or could cause dilution to our shareholders.” and “Increased competition from other companies that provide gathering, transmission and storage, and water services, or from alternative fuel sources, could have a negative impact on the demand for our services, which could adversely affect our financial results.” under "Item 1A. Risk Factors" in the Company's Annual Report on Form 10-K for the year ended December 31, 2020.

We recognize that our shareholders, employees, customers, regulators, and other stakeholders expect us to continue to focus on long-term sustainable performance, including by addressing significant, relevant ESG factors, further working to prioritize sustainable energy practices, reducing our carbon footprint and promoting sustainability. We expect to continue to incur costs in doing so. Further, if we do not adapt to or comply with investor or other stakeholder expectations and standards (or meet sustainability goals that we set), which are evolving, or if we are perceived not to have responded appropriately or quickly enough to growing concern for ESG and sustainability issues, our business could suffer, including from reputational damage.

In addition, as we continue to focus on long-term sustainable performance and address ESG factors, and as disclosure standards continue to evolve, including as a result of potential regulatory initiatives, we have expanded and expect to further expand our public disclosures in these areas. Such disclosures may reflect goals, cost estimates and other expectations and assumptions, including over long timelines, which goals, cost estimates, and other expectations and assumptions are necessarily uncertain and may not be realized. Failure to realize (or timely achieve progress on) such goals, cost estimates, and other expectations or assumptions may adversely impact us. Further, a multitude of organizations that provide information to investors have developed ratings processes for evaluating companies on their approach to ESG and sustainability matters, and unfavorable ratings or perceptions of (or activism directed towards) us or our industry as a result of such ratings or our ESG and sustainability practices may adversely affect investor sentiment and cause investment funds to be allocated to other companies or industries.

The occurrence of any of the foregoing may adversely affect our business, financial condition, results of operations, liquidity and/or our stock price.

Terrorist or cyber security attacks and threats aimed at us or third parties, as well as any noncompliance by us with applicable laws and regulations governing data privacy, could adversely affect us.

We have become increasingly dependent upon digital technologies, including information systems, infrastructure and cloud applications, to conduct our business, and the maintenance of our financial and other records has long been dependent upon such technologies. We depend on both our own systems, networks, and technology as well as the systems, networks and technology of our vendors, customers and other business partners. The U.S. government has issued public warnings that indicate that energy assets might be specific targets of cyber security threats. Our systems (or those of third parties with whom we are connected) that are designed to protect against cyber security risks may not be sufficient, and deliberate attacks on, or unintentional events or security breaches affecting, our systems or infrastructure, the systems or infrastructure of third parties or the cloud could adversely affect us, including by leading to corruption or loss of our proprietary data and potentially sensitive data, delays in the performance of services for our customers, difficulty in completing and settling transactions, challenges in
52
Table of Contents


maintaining our books and records, communication interruptions, environmental damage, regulatory scrutiny, personal injury, property damage and other operational disruptions, as well as damage to our reputation, financial condition and cash flows and potential legal claims and liabilities. Further, as cyber incidents continue to evolve, we likely will be required to expend additional resources to continue to modify or enhance our protective measures and/or to investigate and remediate vulnerabilities to or consequences of cyber incidents (and there can be no assurance that any protective or remedial measures are or will be adequate to address a risk that arises).

The regulatory landscape with regard to data privacy and the unauthorized disclosure of personal information also continues to develop. New laws and regulations governing data privacy and the unauthorized disclosure of personal information may potentially elevate our compliance costs. Any failure by us, a company that we acquire, or one of our technology service providers, to comply with these laws and regulations, where applicable, including as a result of a cyber incident, could adversely affect us, including by resulting in reputational harm, penalties, regulatory scrutiny, liabilities, and/or mandated changes in our business practices.

Our subsidiaries’ significant indebtedness, and any future indebtedness, as well as the restrictions under our subsidiaries’ debt agreements, could adversely affect our operating flexibility, business, financial condition, results of operations, liquidity and ability to pay dividends to our shareholders.

The respective debt agreements of EQM and Eureka contain various covenants and restrictive provisions that limit EQM’s and Eureka's, as applicable, ability to, among other things:

•incur or guarantee additional debt;

•make distributions on or redeem or repurchase units;

•incur or permit liens on assets;

•enter into certain types of transactions with affiliates;

•enter into burdensome agreements, subject to certain specified exceptions;

•enter into certain mergers or acquisitions; and

•dispose of all or substantially all of their respective assets.

See Note 8 to the consolidated financial statements for a discussion of the Amended EQM Credit Facility and the Eureka Credit Facility and Note 12 to the consolidated financial statements for a discussion of the Second Amendment to the Amended EQM Credit Facility. As amended by the Second Amendment, the Amended EQM Credit Facility contains certain negative covenants, that, among other things, establish for EQM a maximum consolidated leverage ratio that varies over the course of the term ranging from not more than 5.95 to 1.00 to not more than 5.00 to 1.00, tested as of the end of each fiscal quarter (which in limited circumstances is increased for certain measurement periods following the consummation of certain acquisitions). Under the Eureka Credit Facility, Eureka is required to maintain a consolidated leverage ratio of not more than 4.75 to 1.00 (which in limited circumstances is increased for certain measurement periods following the consummation of certain acquisitions). Additionally, as of the end of any fiscal quarter, Eureka may not permit the ratio of consolidated EBITDA (as defined in the Eureka Credit Facility) for the four fiscal quarters then ending to Consolidated Interest Charges (as defined in the Eureka Credit Facility) to be less than 2.50 to 1.00. EQM’s and Eureka’s ability to meet these covenants can be affected by events beyond their respective control and we cannot assure our shareholders that EQM or Eureka will continue to meet these covenants. In addition, the Amended EQM Credit Facility, as amended by the Second Amendment, and the Eureka Credit Facility each contain certain events of default, including the occurrence of a change of control.

In addition to the above-described facilities, EQM has issued senior unsecured notes which remain outstanding.

The provisions of the debt agreements may affect our ability to obtain future financing and pursue attractive business opportunities and our flexibility in planning for, and reacting to, changes in business conditions. In addition, a failure to comply with the provisions of the debt agreements could result in an event of default, which could enable creditors to, subject to the terms and conditions of the applicable agreement, declare any outstanding principal of that debt, together with accrued and unpaid interest, to be immediately due and payable. If the payment of the debt is accelerated, our assets may be insufficient to repay such debt in full, and in turn our shareholders could experience a partial or total loss of their investments. The Amended
53
Table of Contents


EQM Credit Facility, as amended by the Second Amendment, also has a cross default provision that applies to any other indebtedness EQM may have with an aggregate principal amount in excess of $25 million.

We and our subsidiaries may in the future incur additional debt. Our and our subsidiaries’ levels of debt could have important consequences to us, including the following:

•our ability to obtain additional financing, if necessary, for working capital, capital expenditures, acquisitions or other purposes may be impaired, or such financing may not be available on favorable terms;

•our funds available for operations, future business opportunities and dividends to our shareholders may be reduced by that portion of our cash flow required to make interest payments on our or our subsidiaries’ debt;

•we may be more vulnerable to competitive pressures or a downturn in our business or the economy generally; and

•our flexibility in responding to changing business and economic conditions may be limited.

Our ability to service our subsidiaries’ current, or our or our subsidiaries’ future, respective debts, will depend upon, among other things, our future financial and operating performance, which will be affected by prevailing economic conditions and financial, business, regulatory and other factors, some of which are beyond our control. If our operating results are not sufficient to service our subsidiaries’ current, or our or our subsidiaries’ future, indebtedness, as applicable, or our operating results affect our ability to comply with covenants in our debt agreements, we will be forced to take actions such as reducing dividends, reducing or delaying our business activities, acquisitions, investments or capital expenditures, selling assets or seeking additional equity capital. We may not be able to effect any of these actions on satisfactory terms or at all.

Our subsidiaries’ current substantial indebtedness and the additional debt we and/or our subsidiaries will incur in the future for, among other things, working capital, capital expenditures, capital contributions to the MVP Joint Venture, acquisitions or operating activities may adversely affect our liquidity and therefore our ability to pay dividends to our shareholders.

In addition, our subsidiaries’ significant indebtedness may be viewed negatively by credit rating agencies, which could result in increased costs for us to access the capital markets. Any future additional downgrade of the debt issued by EQM could significantly increase our capital costs or adversely affect our ability to raise capital in the future.
Item 2. Unregistered Sales of Equity Securities and Use of Proceeds
Purchases of Equity Securities
The following table sets forth the Company's repurchases of equity securities registered under Section 12 of the Exchange Act that occurred during the three months ended March 31, 2021:2022:
Period
Total number of shares purchased (a)
Average price paid per shareTotal number of shares purchased as part of publicly announced plans or programsApproximate dollar value of shares that may yet be purchased under the plans or programs
January 2021 (January 1 - January 31)— $— — $— 
February 2021 (February 1 - February 28)3,687 7.33 — — 
March 2021 (March 1 - March 31)9,290 8.04 — — 
Total12,977 $7.84 — $— 
Period
Total number of shares purchased (a)
Average price paid per shareTotal number of shares purchased as part of publicly announced plans or programsApproximate dollar value of shares that may yet be purchased under the plans or programs
January 2022 (January 1 - January 31)94,651 $10.34 — $— 
February 2022 (February 1 - February 28)— — — — 
March 2022 (March 1 - March 31)— — — — 
Total94,651 $10.34 — $— 
(a)Reflects shares withheld by the Company to pay taxes upon vesting of restricted stock.

5440
Table of Contents


Item 6. Exhibits
Exhibit No.Document DescriptionMethod of Filing
3.1
SecondFourth Amended and Restated Articles of IncorporationBylaws of Equitrans Midstream Corporation.Incorporated herein by reference to Exhibit 3.1 to Form 8-K (#001-38629) filed on April 28, 2021.
3.2
Third Amended and Restated Bylaws of Equitrans Midstream Corporation.Incorporated herein by reference to Exhibit 3.3 to Form 8-K (#001-38629) filed on April 28, 2021.
4.1
Indenture, dated as of January 8, 2021, by and between EQM Midstream Partners, LP and The Bank of New York Mellon Trust Company, N.A., as trustee.
Incorporated herein by reference to Exhibit 4.1 to Form 8-K (#001-38629) filed on January 8, 2021.27, 2022.
10.1
Purchase Agreement, dated January 4, 2021, by and among EQM Midstream Partners, LP, Equitrans Midstream Corporation (for certain limited purposes) and Barclays Capital Inc., as representative of the several initial purchasers named on Schedule 1 thereto.Incorporated herein by reference to Exhibit 10.1 to Form 8-K (#001-38629) filed on January 5, 2021.
10.2*
Equitrans Midstream Corporation Executive Short-Term Incentive Plan.

Incorporated herein by reference to Exhibit 10.46 to Annual Report on Form 10-K (#001-38629) filed on February 23, 2021.

10.3*
Equitrans Midstream Corporation 2021 Performance Share Unit Program.
Incorporated herein by reference to Exhibit 10.47 to Annual Report on Form 10-K (#001-38629) filed on February 23, 2021.
10.4*
Form of Participant Award Agreement under 2021 Performance Share Unit Program.Incorporated herein by reference to Exhibit 10.48 to Annual Report on Form 10-K (#001-38629) filed on February 23, 2021.
10.5*
Form of Equitrans Midstream Corporation Restricted Stock Award Agreement (2021 Awards).Incorporated herein by reference to Exhibit 10.49 to Annual Report on Form 10-K (#001-38629) filed on February 23, 2021.
10.6#
Letter Agreement, dated as of March 27, 2021, by and between Rice Drilling B LLC and Equitrans Water Services (PA) LLC (formerly known as Rice Water Services (PA) LLC).
Filed herewith as Exhibit 10.6.
10.7##
Letter Agreement, dated as of February 23, 2021,1, 2022, by and between EQM Olympus Midstream, LLC and Rice Drilling D LLC.Incorporated herein by reference to Exhibit 10.04(d) to Form 10-K (#001-38629) for the year ended December 31, 2021.
10.2#
Letter Agreement, dated as of February 4, 2022, by and among EQM Gathering Opco, LLC, EQT Corporation, EQT Production Company, Rice Drilling B LLC, and EQT Energy, LLC.Filed herewith asIncorporated herein by reference to Exhibit 10.7.10.34(m) to Form 10-K (#001-38629) for the year ended December 31, 2021.
10.8#10.3*
LetterEquitrans Midstream Corporation 2022 Performance Share Unit ProgramIncorporated herein by reference to Exhibit 10.44 to Form 10-K (#001-38629) for the year ended December 31, 2021.
10.04*
Form of Participant Award Agreement under 2022 Performance Share Unit ProgramIncorporated herein by reference to Exhibit 10.45 to Form 10-K (#001-38629) for the year ended December 31, 2021.
10.05*
Form of Equitrans Midstream Corporation Restricted Stock Award Agreement (2022 Awards)Incorporated herein by reference to Exhibit 10.46 to Form 10-K (#001-38629) for the year ended December 31, 2021.
10.06*
Equitrans Midstream Corporation Amended and Restated Executive Short-Term Incentive PlanIncorporated herein by reference to Exhibit 10.47 to Form 10-K (#001-38629) for the year ended December 31, 2021.
10.07
Third Amendment to Third Amended and Restated Credit Agreement, dated as of February 2, 2021,April 22, 2022, by and among EQM Gathering Opco, LLC, EQT Corporation, EQT Production Company, Rice Drilling B LLCMidstream Partners, LP, the lender parties thereto and EQT Energy, LLC.Wells Fargo Bank, National Association, as administrative agent.Filed herewith asIncorporated herein by reference to Exhibit 10.8.10.1 to Form 8-K (#001-38629) filed on April 25, 2022.
10.9#10.08**
Letter Agreement, dated as of February 9, 2021, by and among EQM Gathering Opco, LLC, EQM OlympusEquitrans Midstream LLC, EQT Corporation EQT Production Company, Rice Drilling B LLC, EQT Energy, LLC and Rice Drilling D LLC.Employee Stock Purchase PlanFiled herewith asIncorporated herein by reference to Exhibit 10.9.
10.10#
Letter Agreement, dated as of February 3, 2021, by and among EQM Gathering Opco, LLC, EQT Corporation, EQT Production Company, Rice Drilling B LLC and EQT Energy, LLC.Filed herewith as Exhibit 10.10.
10.11#
Letter Agreement, dated as of February 18, 2021, by and between EQM Olympus Midstream, LLC and Rice Drilling D LLC.Filed herewith as Exhibit 10.11.10.1 to Form 8-K (#001-38629) filed on April 27, 2022.
31.1
Rule 13(a)-14(a) Certification of Principal Executive Officer.Filed herewith as Exhibit 31.1.
31.2
Rule 13(a)-14(a) Certification of Principal Financial Officer.Filed herewith as Exhibit 31.2.
55
Table of Contents


32
Section 1350 Certification of Principal Executive Officer and Principal Financial Officer.Furnished herewith as Exhibit 32.
101Inline Interactive Data File.Filed herewith as Exhibit 101.
104Cover Page Interactive Data File (formatted as Inline XBRL and contained in Exhibit 101).Filed herewith as Exhibit 104.


*Management contract and compensatory arrangement in which any director or any named executive officer participates.participates

** Management contract and compensatory arrangement in which any named executive officer participates

# Certain portions of the exhibitexhibits that are not material and would be competitively harmful if publicly disclosedis of the type Equitrans Midstream treats as confidential have been redacted pursuant to Item 601(b)(10)(iv) of Regulation S-K. A copyCopies of the unredacted exhibitexhibits will be furnished to the SEC upon request. Omissions are designated with brackets containing asterisks.



5641

Signature
 
 
 
 
Pursuant to the requirements of the Securities Exchange Act of 1934, the Registrant has duly caused this report to be signed on its behalf by the undersigned thereunto duly authorized.
 
 
 
 Equitrans Midstream Corporation
 (Registrant)
  
 By:/s/ Kirk R. Oliver
  Kirk R. Oliver
  Senior Vice President and Chief Financial Officer
 
 
 
 
 
 
 
 
 
 
 
Date:  May 4, 20213, 2022

5742