UNITED STATES
SECURITIES AND EXCHANGE COMMISSION
Washington, D.C. 20549
FORM 10-Q
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| (Mark One) |
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| ☒ | QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934 |
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FOR THE QUARTERLY PERIOD ENDED SEPTEMBER 30, 20202021
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| or |
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| ☐ | TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934 |
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| FOR THE TRANSITION PERIOD FROM TO |
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| COMMISSION FILE NUMBER | 001-38629 |
EQUITRANS MIDSTREAM CORPORATION
(Exact name of registrant as specified in its charter)
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| 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
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| (Registrant's telephone number, including area code) |
Securities registered pursuant to Section 12(b) of the Act:
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| Title of each class | | Trading Symbol | | Name of each exchange on which registered |
| Common Stock, no par value | | ETRN | | New 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.
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| 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 ☒
AsThe number of October 31, 2020, 432,470 shares of common stock outstanding (in thousands), no par value, and 30,018 sharesas of Series A Perpetual Convertible Preferred Stock (in thousands), no par value, of the registrant were outstanding.October 31, 2021: 432,501
EQUITRANS MIDSTREAM CORPORATION
Index
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 (the 2021 Water Services Agreement) by the Company and EQT which 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.
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.
EQGPdelivery point – EQGP Holdings, LP (formerly known as EQT GP Holdings, LP) and its subsidiaries. the point where gas is delivered into a downstream gathering system or transmission pipeline.
EQM – EQM Midstream Partners, LP (formerly known as EQT 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) contracts.
gas – natural gas.
Minimumminimum 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,300-mile, 42-inch diameter natural gas interstate pipeline with a targeted capacity of 2.0 Bcf per day that will 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.
MVP Southgate – a proposed 75-mile interstate pipeline that will extend from the MVP at Pittsylvania County, Virginia to new delivery points in Rockingham and Alamance Counties, North Carolina.
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.
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.
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.
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."
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| Abbreviations | Measurements |
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 | BcfMcf = billionthousand cubic feet
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FERC – U.S. Federal Energy Regulatory Commission | Mcf MMBtu= thousand cubic feetmillion British thermal units
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GAAP – United States Generally Accepted Accounting Principles | MMBtu = million British thermal units
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IDRs – incentive distribution rights
| MMcf = million cubic feet |
NGA – Natural Gas Act of 1938 | MMgal = million gallons |
NYMEX – New York Mercantile Exchange | MMgal = million gallons
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NYSE – New York Stock Exchange |
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SEC – U.S. Securities and Exchange Commission | |
PART I. FINANCIAL INFORMATION
Item 1. Financial Statements
EQUITRANS MIDSTREAM CORPORATION
Statements of Consolidated Comprehensive Income (Unaudited)
| | | | Three Months Ended September 30, | | Nine Months Ended September 30, | | Three Months Ended September 30, | | Nine Months Ended September 30, |
| | | 2020 | | 2019 | | 2020 | | 2019 | | 2021 | | 2020 | | 2021 | | 2020 |
| | | (Thousands, except per share amounts) | | (Thousands, except per share amounts) |
Operating revenues (a) | Operating revenues (a) | $ | 350,000 | | | $ | 408,434 | | | $ | 1,143,703 | | | $ | 1,204,383 | | Operating revenues (a) | $ | 342,074 | | | $ | 350,000 | | | $ | 1,070,365 | | | $ | 1,143,703 | |
| Operating expenses: | Operating expenses: | | | | | Operating expenses: | | | | |
Operating and maintenance (a) | Operating and maintenance (a) | 33,905 | | | 43,021 | | | 113,990 | | | 117,460 | | Operating and maintenance (a) | 38,743 | | | 33,905 | | | 111,004 | | | 113,990 | |
Selling, general and administrative (a) | Selling, general and administrative (a) | 31,626 | | | 24,151 | | | 94,186 | | | 83,553 | | Selling, general and administrative (a) | 33,560 | | | 31,626 | | | 104,536 | | | 94,186 | |
| Separation and other transaction costs | 984 | | | 256 | | | 23,797 | | | 24,606 | | |
| Transaction costs | | Transaction costs | — | | | 984 | | | — | | | 23,797 | |
| Depreciation | Depreciation | 66,772 | | | 59,460 | | | 191,271 | | | 166,730 | | Depreciation | 66,021 | | | 66,772 | | | 203,954 | | | 191,271 | |
| Amortization of intangible assets | Amortization of intangible assets | 16,204 | | | 14,540 | | | 46,990 | | | 38,677 | | Amortization of intangible assets | 16,204 | | | 16,204 | | | 48,614 | | | 46,990 | |
Impairments of long-lived assets (b) | Impairments of long-lived assets (b) | 0 | | | 305,459 | | | 55,581 | | | 385,594 | | Impairments of long-lived assets (b) | — | | | — | | | 56,178 | | | 55,581 | |
| | Total operating expenses | Total operating expenses | 149,491 | | | 446,887 | | | 525,815 | | | 816,620 | | Total operating expenses | 154,528 | | | 149,491 | | | 524,286 | | | 525,815 | |
| Operating income (loss) | 200,509 | | | (38,453) | | | 617,888 | | | 387,763 | | |
| Operating income | | Operating income | 187,546 | | | 200,509 | | | 546,079 | | | 617,888 | |
Equity income (c) | Equity income (c) | 60,917 | | | 44,448 | | | 171,233 | | | 112,293 | | Equity income (c) | 8,461 | | | 60,917 | | | 14,385 | | | 171,233 | |
Other income (d) | Other income (d) | 21,864 | | | 70 | | | 39,006 | | | 2,637 | | Other income (d) | 21,199 | | | 21,864 | | | 38,251 | | | 39,006 | |
Loss on early extinguishment of debt (e) | 0 | | | 0 | | | 24,864 | | | 0 | | |
Loss on extinguishment of debt (e) | | Loss on extinguishment of debt (e) | — | | | — | | | 41,025 | | | 24,864 | |
Net interest expense (a) | Net interest expense (a) | 86,411 | | | 65,606 | | | 219,960 | | | 188,268 | | Net interest expense (a) | 94,101 | | | 86,411 | | | 284,887 | | | 219,960 | |
| Income (loss) before income taxes | 196,879 | | | (59,541) | | | 583,303 | | | 314,425 | | |
| Income before income taxes | | Income before income taxes | 123,105 | | | 196,879 | | | 272,803 | | | 583,303 | |
| Income tax expense | Income tax expense | 28,440 | | | 1,948 | | | 81,846 | | | 45,868 | | Income tax expense | 32,200 | | | 28,440 | | | 65,180 | | | 81,846 | |
| Net income (loss) | 168,439 | | | (61,489) | | | 501,457 | | | 268,557 | | |
| Net income | | Net income | 90,905 | | | 168,439 | | | 207,623 | | | 501,457 | |
| Net income attributable to noncontrolling interests | Net income attributable to noncontrolling interests | 3,973 | | | 4,336 | | | 210,765 | | | 203,562 | | Net income attributable to noncontrolling interests | 3,557 | | | 3,973 | | | 10,479 | | | 210,765 | |
| Net income (loss) attributable to Equitrans Midstream | 164,466 | | | (65,825) | | | 290,692 | | | 64,995 | | |
| Net income attributable to Equitrans Midstream | | Net income attributable to Equitrans Midstream | 87,348 | | | 164,466 | | | 197,144 | | | 290,692 | |
| Preferred dividends (f) | Preferred dividends (f) | 14,628 | | | 0 | | | 44,132 | | | 0 | | Preferred dividends (f) | 14,628 | | | 14,628 | | | 43,884 | | | 44,132 | |
| Net income (loss) attributable to Equitrans Midstream common shareholders | $ | 149,838 | | | $ | (65,825) | | | $ | 246,560 | | | $ | 64,995 | | |
| Net income attributable to Equitrans Midstream common shareholders | | Net income attributable to Equitrans Midstream common shareholders | $ | 72,720 | | | $ | 149,838 | | | $ | 153,260 | | | $ | 246,560 | |
| Earnings (loss) per share of common stock attributable to Equitrans Midstream common shareholders - basic (g) | $ | 0.35 | | | $ | (0.26) | | | $ | 0.78 | | | $ | 0.26 | | |
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) | $ | 0.17 | | | $ | 0.35 | | | $ | 0.35 | | | $ | 0.78 | |
| Earnings (loss) per share of common stock attributable to Equitrans Midstream common shareholders - diluted (g) | $ | 0.35 | | | $ | (0.26) | | | $ | 0.78 | | | $ | 0.25 | | |
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) | $ | 0.17 | | | $ | 0.35 | | | $ | 0.35 | | | $ | 0.78 | |
| | Weighted average common shares outstanding - basic | Weighted average common shares outstanding - basic | 432,773 | | | 254,915 | | | 314,411 | | | 254,868 | | Weighted average common shares outstanding - basic | 433,017 | | | 432,773 | | | 433,001 | | | 314,411 | |
| Weighted average common shares outstanding - diluted | Weighted average common shares outstanding - diluted | 432,821 | | | 254,915 | | | 314,411 | | | 254,887 | | Weighted average common shares outstanding - diluted | 433,675 | | | 432,821 | | | 433,412 | | | 314,411 | |
| | Statement of comprehensive income (loss): | | |
| Net income (loss) | $ | 168,439 | | | $ | (61,489) | | | $ | 501,457 | | | $ | 268,557 | | |
| Other comprehensive income (loss), net of tax: | | |
| Pension and other post-retirement benefits liability adjustment, net of tax expense of $10, $7, $30 and $22 | 30 | | | 21 | | | 90 | | | (252) | | |
| Other comprehensive income (loss) | 30 | | | 21 | | | 90 | | | (252) | | |
| Comprehensive income (loss) | 168,469 | | | (61,468) | | | 501,547 | | | 268,305 | | |
| Statement of comprehensive income: | | Statement of comprehensive income: | |
| Net income | | Net income | $ | 90,905 | | | $ | 168,439 | | | $ | 207,623 | | | $ | 501,457 | |
| 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, $10, $36, and $30 | | Pension and other post-retirement benefits liability adjustment, net of tax expense of $12, $10, $36, and $30 | 34 | | | 30 | | | 103 | | | 90 | |
| Other comprehensive income | | Other comprehensive income | 34 | | | 30 | | | 103 | | | 90 | |
| Comprehensive income | | Comprehensive income | 90,939 | | | 168,469 | | | 207,726 | | | 501,547 | |
| Less: Comprehensive income attributable to noncontrolling interests | Less: Comprehensive income attributable to noncontrolling interests | 3,973 | | | 4,336 | | | 210,765 | | | 203,562 | | Less: Comprehensive income attributable to noncontrolling interests | 3,557 | | | 3,973 | | | 10,479 | | | 210,765 | |
Less: Comprehensive income attributable to preferred dividends (f) | Less: Comprehensive income attributable to preferred dividends (f) | 14,628 | | | 0 | | | 44,132 | | | 0 | | Less: Comprehensive income attributable to preferred dividends (f) | 14,628 | | | 14,628 | | | 43,884 | | | 44,132 | |
| Comprehensive income (loss) attributable to Equitrans Midstream common shareholders | $ | 149,868 | | | $ | (65,804) | | | $ | 246,650 | | | $ | 64,743 | | |
| Comprehensive income attributable to Equitrans Midstream common shareholders | | Comprehensive income attributable to Equitrans Midstream common shareholders | $ | 72,754 | | | $ | 149,868 | | | $ | 153,363 | | | $ | 246,650 | |
| | Dividends declared per common share | Dividends declared per common share | $ | 0.15 | | | $ | 0.45 | | | $ | 0.45 | | | $ | 1.35 | | Dividends declared per common share | $ | 0.15 | | | $ | 0.15 | | | $ | 0.45 | | | $ | 0.45 | |
(a)Includes related party activity with EQT.EQT Corporation (EQT). See Note 7.6.
(b)See Note 43 for disclosure regarding impairments of long-lived assets.
(c)Represents equity income from theMountain Valley Pipeline, LLC (the MVP Joint Venture.Venture). See Note 8.7.
(d)See Note 109 for disclosures regarding derivative instruments.
(e)See Note 98 for disclosure regarding loss on early extinguishment of debt.
(f)See NotesNote 2 and 11 for disclosuresdisclosure regarding the Equitrans Midstream Preferred Shares (as defined in Note 1)2).
(g)See Note 1110 for disclosure regarding the Company's calculation of net income per share of common stock (basic and diluted).
The accompanying notes are an integral part of these consolidated financial statements.
EQUITRANS MIDSTREAM CORPORATION
Statements of Consolidated Cash Flows (Unaudited)
| | | | Nine Months Ended September 30, | | Nine Months Ended September 30, |
| | | 2020 | | 2019 | | 2021 | | 2020 |
| | | (Thousands) | | (Thousands) |
| Cash flows from operating activities: | Cash flows from operating activities: | | | | Cash flows from operating activities: | | | |
| Net income | Net income | $ | 501,457 | | | $ | 268,557 | | Net income | $ | 207,623 | | | $ | 501,457 | |
| Adjustments to reconcile net income to net cash provided by operating activities: | Adjustments to reconcile net income to net cash provided by operating activities: | | Adjustments to reconcile net income to net cash provided by operating activities: | |
| Depreciation | Depreciation | 191,271 | | | 166,730 | | Depreciation | 203,954 | | | 191,271 | |
| Amortization of intangible assets | Amortization of intangible assets | 46,990 | | | 38,677 | | Amortization of intangible assets | 48,614 | | | 46,990 | |
| Deferred income taxes | Deferred income taxes | 79,415 | | | 45,868 | | Deferred income taxes | 61,267 | | | 79,415 | |
| Impairments of long-lived assets (Note 4) | 55,581 | | | 385,594 | | |
| Equity income (Note 8) | (171,233) | | | (112,293) | | |
| Impairments of long-lived assets | | Impairments of long-lived assets | 56,178 | | | 55,581 | |
| Equity income | | Equity income | (14,385) | | | (171,233) | |
| Other income | Other income | (38,403) | | | (3,866) | | Other income | (38,160) | | | (38,403) | |
| Loss on early extinguishment of debt | 24,864 | | | 0 | | |
| Share-based compensation plans | 9,388 | | | 1,900 | | |
| Loss on extinguishment of debt | | Loss on extinguishment of debt | 41,025 | | | 24,864 | |
| Non-cash long-term compensation expense | | Non-cash long-term compensation expense | 10,590 | | | 9,388 | |
| Changes in other assets and liabilities: | Changes in other assets and liabilities: | | Changes in other assets and liabilities: | |
| Accounts receivable | Accounts receivable | (11,021) | | | 28,773 | | Accounts receivable | 73,348 | | | (11,021) | |
| | Accounts payable | Accounts payable | 3,151 | | | (72,369) | | Accounts payable | (1,765) | | | 3,151 | |
| Accrued interest | Accrued interest | (5,592) | | | (39,103) | | Accrued interest | (48,893) | | | (5,592) | |
| Deferred revenue | Deferred revenue | 148,770 | | | 0 | | Deferred revenue | 225,315 | | | 148,770 | |
| Other assets and other liabilities | Other assets and other liabilities | (10,443) | | | (17,999) | | Other assets and other liabilities | (2,687) | | | (10,443) | |
| Net cash provided by operating activities | Net cash provided by operating activities | 824,195 | | | 690,469 | | Net cash provided by operating activities | 822,024 | | | 824,195 | |
| Cash flows from investing activities: | Cash flows from investing activities: | | | | Cash flows from investing activities: | | | |
| Capital expenditures | Capital expenditures | (377,592) | | | (769,937) | | Capital expenditures | (211,072) | | | (377,592) | |
| Capital contributions to the MVP Joint Venture | Capital contributions to the MVP Joint Venture | (144,264) | | | (512,852) | | Capital contributions to the MVP Joint Venture | (178,953) | | | (144,264) | |
| Bolt-on Acquisition (as defined in Note 3), net of cash acquired | 0 | | | (837,231) | | |
| Principal payments received on the Preferred Interest | 3,726 | | | 3,471 | | |
| | Principal payments received on the Preferred Interest (as defined in Note 6) | | Principal payments received on the Preferred Interest (as defined in Note 6) | 3,885 | | | 3,726 | |
| | Net cash used in investing activities | Net cash used in investing activities | (518,130) | | | (2,116,549) | | Net cash used in investing activities | (386,140) | | | (518,130) | |
| Cash flows from financing activities: | Cash flows from financing activities: | | | | Cash flows from financing activities: | | | |
| Proceeds from revolving credit facility borrowings | Proceeds from revolving credit facility borrowings | 1,965,000 | | | 1,969,000 | | Proceeds from revolving credit facility borrowings | 457,500 | | | 1,965,000 | |
| Payments on revolving credit facility borrowings | Payments on revolving credit facility borrowings | (2,080,000) | | | (2,325,500) | | Payments on revolving credit facility borrowings | (600,000) | | | (2,080,000) | |
| Proceeds from the issuance of long-term debt | Proceeds from the issuance of long-term debt | 1,600,000 | | | 1,400,000 | | Proceeds from the issuance of long-term debt | 1,900,000 | | | 1,600,000 | |
| | Debt issuance costs and credit facility origination fees | (26,720) | | | (2,563) | | |
| Debt discounts, debt issuance costs and credit facility arrangement fees | | Debt discounts, debt issuance costs and credit facility arrangement fees | (29,904) | | | (26,720) | |
| | Payment for retirement of long-term debt | Payment for retirement of long-term debt | (594,000) | | | (32,825) | | Payment for retirement of long-term debt | (1,936,250) | | | (594,000) | |
| | Redemption of EQM Series A Preferred Units (as defined in Note 1) | (617,338) | | | 0 | | |
| Redemption of EQM Series A Preferred Units (as defined in Note 2) | | Redemption of EQM Series A Preferred Units (as defined in Note 2) | — | | | (617,338) | |
| | Distributions paid to noncontrolling interest EQM unitholders | Distributions paid to noncontrolling interest EQM unitholders | (128,770) | | | (285,834) | | Distributions paid to noncontrolling interest EQM unitholders | — | | | (128,770) | |
| Distributions paid to holders of EQM Series A Preferred Units (as defined in Note 1) | (61,931) | | | (22,979) | | |
| Distributions paid to holders of EQM Series A Preferred Units | | Distributions paid to holders of EQM Series A Preferred Units | — | | | (61,931) | |
| | Dividends paid to holders of Equitrans Midstream Preferred Shares | Dividends paid to holders of Equitrans Midstream Preferred Shares | (2,251) | | | 0 | | Dividends paid to holders of Equitrans Midstream Preferred Shares | (43,884) | | | (2,251) | |
| | Dividends paid to common shareholders | Dividends paid to common shareholders | (213,524) | | | (333,493) | | Dividends paid to common shareholders | (194,624) | | | (213,524) | |
| Cash Shares and Cash Amount (as defined in Note 6) | (52,323) | | | 0 | | |
| | Purchase of EQGP Common Units (as defined in Note 2) | 0 | | | (238,455) | | |
| Proceeds from issuance of EQM Series A Preferred Units, net of offering costs | 0 | | | 1,158,313 | | |
| Cash Shares and Cash Amount (as defined in Note 5) | | Cash Shares and Cash Amount (as defined in Note 5) | — | | | (52,323) | |
| | Net cash (used in) provided by financing activities | (211,857) | | | 1,285,664 | | |
| | Distributions to Eureka Midstream Holdings, LLC non-controlling member | | Distributions to Eureka Midstream Holdings, LLC non-controlling member | (2,500) | | | — | |
| Net cash used in financing activities | | Net cash used in financing activities | (449,662) | | | (211,857) | |
| | Net change in cash and cash equivalents | Net change in cash and cash equivalents | 94,208 | | | (140,416) | | Net change in cash and cash equivalents | (13,778) | | | 94,208 | |
| Cash and cash equivalents at beginning of period | Cash and cash equivalents at beginning of period | 88,322 | | | 294,172 | | Cash and cash equivalents at beginning of period | 208,023 | | | 88,322 | |
| Cash and cash equivalents at end of period | Cash and cash equivalents at end of period | $ | 182,530 | | | $ | 153,756 | | Cash and cash equivalents at end of period | $ | 194,245 | | | $ | 182,530 | |
| | Cash paid during the period for: | Cash paid during the period for: | | | | Cash paid during the period for: | | | |
| Interest, net of amount capitalized | Interest, net of amount capitalized | $ | 221,918 | | | $ | 223,257 | | Interest, net of amount capitalized | $ | 326,456 | | | $ | 221,918 | |
| Non-cash activity during the period for: | Non-cash activity during the period for: | | | | Non-cash activity during the period for: | | | |
| Issuance of Equitrans Midstream common stock pursuant to the EQM Merger (as defined in Note 1), net of tax | $ | 2,736,229 | | | $ | 0 | | |
| Issuance of Equitrans Midstream Preferred Shares pursuant to the Restructuring Agreement (as defined in Note 1) | 667,214 | | | 0 | | |
| Issuance of Equitrans Midstream common stock pursuant to the EQM Merger (as defined in Note 2), net of tax | | Issuance of Equitrans Midstream common stock pursuant to the EQM Merger (as defined in Note 2), net of tax | $ | — | | | $ | 2,736,229 | |
| Issuance of Equitrans Midstream Preferred Shares pursuant to the Restructuring Agreement (as defined in Note 2) | | Issuance of Equitrans Midstream Preferred Shares pursuant to the Restructuring Agreement (as defined in Note 2) | — | | | 667,214 | |
| Contract liability | Contract liability | 121,483 | | | 0 | | Contract liability | — | | | 121,483 | |
|
The accompanying notes are an integral part of these consolidated financial statements.
EQUITRANS MIDSTREAM CORPORATION
Consolidated Balance Sheets (Unaudited)
| | | | | | | | | | | |
| September 30, 2020 | | December 31, 2019 |
| (Thousands) |
| ASSETS | |
| Current assets: | | | |
| Cash and cash equivalents | $ | 182,530 | | | $ | 88,322 | |
| | | |
Accounts receivable (net of allowance for credit losses of $3,609 and allowance for doubtful accounts of $285 as of September 30, 2020 and December 31, 2019, respectively) (a)(b) | 263,657 | | | 255,344 | |
| | | |
| | | |
| | | |
Other current assets (a) | 86,855 | | | 31,546 | |
| Total current assets | 533,042 | | | 375,212 | |
| | | |
| Property, plant and equipment | 8,782,420 | | | 8,583,124 | |
| Less: accumulated depreciation | (943,687) | | | (859,157) | |
| Net property, plant and equipment | 7,838,733 | | | 7,723,967 | |
| | | |
| Investment in unconsolidated entity | 2,722,081 | | | 2,324,108 | |
| Goodwill | 486,698 | | | 486,698 | |
| Net intangible assets | 732,795 | | | 797,439 | |
| Deferred income tax asset | 0 | | | 90,597 | |
| | | |
| | | |
| | | |
Other assets (a) | 317,331 | | | 243,688 | |
| Total assets | $ | 12,630,680 | | | $ | 12,041,709 | |
| | | |
| LIABILITIES, MEZZANINE EQUITY AND SHAREHOLDERS' EQUITY | | | |
| Current liabilities: | | | |
Current portion of revolving credit facility borrowings and long-term debt (c) | $ | 302,500 | | | $ | 6,000 | |
| Accounts payable | 101,134 | | | 128,114 | |
| | | |
| Capital contributions payable to the MVP Joint Venture | 127,626 | | | 45,150 | |
| Accrued interest | 67,863 | | | 73,455 | |
| Accrued liabilities | 73,187 | | | 83,238 | |
| Total current liabilities | 672,310 | | | 335,957 | |
| | | |
| Long-term liabilities: | | | |
Revolving credit facility borrowings (d) | 485,000 | | | 902,500 | |
| Long-term debt | 6,440,628 | | | 5,421,983 | |
| | | |
| | | |
Contract liability (e) | 321,775 | | | 0 | |
| | | |
| Deferred income tax liability | 293,583 | | | 0 | |
| Regulatory and other long-term liabilities | 95,889 | | | 99,189 | |
| Total liabilities | 8,309,185 | | | 6,759,629 | |
| | | |
| | | |
| Mezzanine equity: | | | |
Equitrans Midstream Preferred Shares, 30,018 and 0 shares issued and outstanding as of September 30, 2020 and December 31, 2019, respectively (f) | 681,842 | | | 0 | |
| | | |
| Shareholders' equity: | | | |
| | | |
| Common stock, no par value, 432,470 and 254,745 shares issued and outstanding as of September 30, 2020 and December 31, 2019, respectively | 3,955,934 | | | 1,292,804 | |
| Retained deficit | (781,363) | | | (618,062) | |
| Accumulated other comprehensive loss | (1,936) | | | (2,026) | |
| Total common shareholders' equity | 3,172,635 | | | 672,716 | |
| Noncontrolling interests | 467,018 | | | 4,609,364 | |
| Total shareholders' equity | 3,639,653 | | | 5,282,080 | |
| Total liabilities, mezzanine equity and shareholders' equity | $ | 12,630,680 | | | $ | 12,041,709 | |
| | | | | | | | | | | |
| September 30, 2021 | | December 31, 2020 |
| (Thousands) |
| ASSETS | |
| Current assets: | | | |
| Cash and cash equivalents | $ | 194,245 | | | $ | 208,023 | |
| | | |
Accounts receivable (net of allowance for credit losses of $2,868 and $4,699 as of September 30, 2021 and December 31, 2020, respectively) (a) | 238,542 | | | 290,446 | |
| | | |
| | | |
| | | |
Other current assets (a) | 53,047 | | | 63,268 | |
| Total current assets | 485,834 | | | 561,737 | |
| | | |
| Property, plant and equipment | 8,929,199 | | | 8,835,652 | |
| Less: accumulated depreciation | (1,155,982) | | | (1,007,756) | |
| Net property, plant and equipment | 7,773,217 | | | 7,827,896 | |
| | | |
| Investment in unconsolidated entity | 3,089,091 | | | 2,796,316 | |
| Goodwill | 486,698 | | | 486,698 | |
| Net intangible assets | 667,976 | | | 716,590 | |
| | | |
| | | |
| | | |
| | | |
Other assets (a) | 365,586 | | | 336,615 | |
| Total assets | $ | 12,868,402 | | | $ | 12,725,852 | |
| | | |
| LIABILITIES, MEZZANINE EQUITY AND SHAREHOLDERS' EQUITY | | | |
| Current liabilities: | | | |
Current portion of revolving credit facility borrowings (b) | $ | — | | | $ | 302,500 | |
| Accounts payable | 64,226 | | | 72,098 | |
| | | |
| Capital contributions payable to the MVP Joint Venture | 108,231 | | | 10,723 | |
| Accrued interest | 77,298 | | | 126,191 | |
| Accrued liabilities | 68,484 | | | 83,366 | |
| Total current liabilities | 318,239 | | | 594,878 | |
| | | |
| Long-term liabilities: | | | |
Revolving credit facility borrowings (c) | 645,000 | | | 485,000 | |
| Long-term debt | 6,432,186 | | | 6,443,312 | |
| | | |
| | | |
Contract liability (a)(d) | 622,992 | | | 398,750 | |
| | | |
| Deferred income tax liability | 410,128 | | | 345,896 | |
| Regulatory and other long-term liabilities | 98,870 | | | 94,902 | |
| Total liabilities | 8,527,415 | | | 8,362,738 | |
| | | |
| | | |
| Mezzanine equity: | | | |
Equitrans Midstream Preferred Shares, 30,018 shares issued and outstanding as of September 30, 2021 and December 31, 2020 (e) | 681,842 | | | 681,842 | |
| | | |
| Shareholders' equity: | | | |
| | | |
| Common stock, no par value, 432,522 and 432,470 shares issued and outstanding as of September 30, 2021 and December 31, 2020, respectively | 3,952,896 | | | 3,941,295 | |
| Retained deficit | (770,769) | | | (728,959) | |
| Accumulated other comprehensive loss | (2,126) | | | (2,229) | |
| Total common shareholders' equity | 3,180,001 | | | 3,210,107 | |
| Noncontrolling interests | 479,144 | | | 471,165 | |
| Total shareholders' equity | 3,659,145 | | | 3,681,272 | |
| Total liabilities, mezzanine equity and shareholders' equity | $ | 12,868,402 | | | $ | 12,725,852 | |
(a)Includes related party activity with EQT. See Note 7.6.
(b)See Note 1 for a discussion of the adoption of ASU 2016-13, Financial Instruments-Credit Losses (Topic 326): Measurement of Credit Losses on Financial Instruments.
(c)Includes aggregate borrowings outstanding on the Former Eureka Credit Facility (as defined in Note 9)8) as of September 30,December 31, 2020. See Note 98 for further detail.
(d)(c)Includes aggregate borrowings outstanding on the Amended EQM Credit Facility (as defined in Note 9)8) as of September 30, 2020. As of December 31, 2019,2021 and on the Company had aggregate borrowings outstanding of approximately $610 million and $293 million on the
First Amended EQM Credit Facility and the Eureka Credit Facility, respectively. The Company had 0 borrowings outstanding under the Equitrans Midstream Credit Facility(as defined in Note 8) as of December 31, 2019.2020 and aggregate borrowings outstanding on the 2021 Eureka Credit Facility (as defined in Note 8) as of September 30, 2021. See Note 98 for further detail.
(e)(d)See Note 65 for disclosure regarding the Company's contract liabilities.
(f)(e)See Note 2 for disclosures regarding the Equitrans Midstream Preferred Shares.
The accompanying notes are an integral part of these consolidated financial statements.
EQUITRANS MIDSTREAM CORPORATION
Statements of Consolidated Shareholders' Equity and Mezzanine Equity (Unaudited)
| | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | |
| | | Common Stock | | | | | | | | |
| | | | | | | | | Accumulated | | | | |
| | | | | | | Retained | | Other | | | | |
| | | | Shares | | No | | Earnings | | Comprehensive | | Noncontrolling | | Total |
| | | | Outstanding | | Par Value | | (Deficit) | | Loss | | Interests | | Equity |
| | | | (Thousands, except per share and unit amounts) |
| Balance at January 1, 2019 | | | 254,271 | | | $ | 425,370 | | | $ | 33,932 | | | $ | (1,509) | | | $ | 4,801,840 | | | $ | 5,259,633 | |
| | | | | | | | | | | | | |
| Other comprehensive income (net of tax): | | | | | | | | | | | | | |
| | | | | | | | | | | | | |
| Net income | | | — | | | — | | | 56,299 | | | — | | | 143,267 | | | 199,566 | |
| Pension and other post-retirement benefits liability adjustment, net of tax expense of $8 | | | — | | | — | | | 316 | | | (295) | | | — | | | 21 | |
| Dividends ($0.41 per share) | | | — | | | — | | | (104,251) | | | — | | | — | | | (104,251) | |
| Share-based compensation plans | | | 413 | | | 853 | | | — | | | — | | | 255 | | | 1,108 | |
| Distributions paid to noncontrolling interest unitholders ($1.13 per common unit for EQM) | | | — | | | — | | | — | | | — | | | (94,030) | | | (94,030) | |
| Purchase of EQGP Common Units | | | — | | | (38,648) | | | — | | | — | | | (199,807) | | | (238,455) | |
| | | | | | | | | | | | | |
| Net changes in ownership of consolidated entities (See Note 2) | | | — | | | 991,098 | | | — | | | — | | | (1,337,641) | | | (346,543) | |
| Balance at March 31, 2019 | | | 254,684 | | | $ | 1,378,673 | | | $ | (13,704) | | | $ | (1,804) | | | $ | 3,313,884 | | | $ | 4,677,049 | |
| Other comprehensive income (net of tax): | | | | | | | | | | | | | |
| Net income | | | — | | | — | | | 74,521 | | | — | | | 55,959 | | | 130,480 | |
| Pension and other post-retirement benefits liability adjustment, net of tax expense of $7 | | | — | | | — | | | — | | | 22 | | | — | | | 22 | |
| Dividends ($0.45 per share) | | | — | | | — | | | (114,608) | | | — | | | — | | | (114,608) | |
| Share-based compensation plans | | | 7 | | | 1,510 | | | — | | | — | | | — | | | 1,510 | |
| Distributions paid to noncontrolling interest unitholders ($1.145 per common unit for EQM) | | | — | | | — | | | — | | | — | | | (95,278) | | | (95,278) | |
| Issuance of EQM Series A Preferred Units, net of offering costs | | | — | | | — | | | — | | | — | | | 1,158,313 | | | 1,158,313 | |
| Bolt-on Acquisition | | | — | | | — | | | — | | | — | | | 486,062 | | | 486,062 | |
| Net changes in ownership of consolidated entities | | | — | | | 1,627 | | | — | | | — | | | — | | | 1,627 | |
| Balance at June 30, 2019 | | | 254,691 | | | $ | 1,381,810 | | | $ | (53,791) | | | $ | (1,782) | | | $ | 4,918,940 | | | $ | 6,245,177 | |
| Other comprehensive income (net of tax): | | | | | | | | | | | | | |
| Net income (loss) | | | — | | | — | | | (65,825) | | | — | | | 4,336 | | | (61,489) | |
| Pension and other post-retirement benefits liability adjustment, net of tax expense of $7 | | | — | | | — | | | — | | | 21 | | | — | | | 21 | |
| Dividends ($0.45 per share) | | | — | | | — | | | (114,634) | | | — | | | — | | | (114,634) | |
| Share-based compensation plans, net | | | 53 | | | (718) | | | — | | | — | | | — | | | (718) | |
| Distributions paid to noncontrolling interest unitholders ($1.160 per common unit for EQM) | | | — | | | — | | | — | | | — | | | (96,526) | | | (96,526) | |
| Distribution paid to EQM Series A Preferred unitholders ($0.9339 per unit) | | | — | | | — | | | — | | | — | | | (22,979) | | | (22,979) | |
Bolt-on Acquisition measurement period adjustments
(Note 3) | | | — | | | — | | | — | | | — | | | (7,602) | | | (7,602) | |
| Balance at September 30, 2019 | | | 254,744 | | | $ | 1,381,092 | | | $ | (234,250) | | | $ | (1,761) | | | $ | 4,796,169 | | | $ | 5,941,250 | |
| | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | |
| | | | | | | | | | | | | | | Mezzanine |
| | | Common Stock | | | | | | | | | | Equity |
| | | | | | | | | Accumulated | | | | | | Equitrans |
| | | | | | | | | Other | | | | | | Midstream |
| | | | Shares | | No | | Retained | | Comprehensive | | Noncontrolling | | Total | | Preferred |
| | | | Outstanding | | Par Value | | Deficit | | Loss | | Interests | | Equity | | Shares |
| | | | (Thousands, except per share and unit amounts) | | |
| Balance at January 1, 2020 | | | 254,745 | | | $ | 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 | | | — | | | — | | | — | | | 30 | | | — | | | 30 | | | — | |
| Dividends on common shares ($0.45 per share) | | | (178) | | | — | | | (115,400) | | | — | | | — | | | (115,400) | | | — | |
| Share-based compensation plans | | | 85 | | | 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 | | | — | | | — | | | (3,718) | | | — | | | — | | | (3,718) | | | — | |
| | | | | | | | | | | | | | | |
| | | | | | | | | | | | | | | |
| Balance at March 31, 2020 | | | 229,352 | | | $ | 1,297,304 | | | $ | (858,440) | | | $ | (1,996) | | | $ | 4,607,450 | | | $ | 5,044,318 | | | $ | — | |
| Other comprehensive income (net of tax): | | | | | | | | | | | | | | | |
| Net income | | | — | | | — | | | 54,243 | | | — | | | 86,964 | | | 141,207 | | | 2,251 | |
| Pension and other post-retirement benefits liability adjustment, net of tax expense of $10 | | | — | | | — | | | — | | | 30 | | | — | | | 30 | | | — | |
| Dividends on common shares ($0.15 per share) | | | — | | | — | | | (34,634) | | | — | | | — | | | (34,634) | | | — | |
| Share-based compensation plans | | | (20) | | | 1,856 | | | — | | | — | | | — | | | 1,856 | | | — | |
| Distributions paid to noncontrolling interest unitholders ($0.3875 per common unit for EQM) | | | — | | | — | | | — | | | — | | | (32,244) | | | (32,244) | | | — | |
| Distributions paid to holders of EQM Series A Preferred Units ($1.0364 per EQM Series A Preferred Unit) | | | — | | | — | | | — | | | — | | | (25,501) | | | (25,501) | | | — | |
| Partial period distributions on EQM Series A Preferred Units converted in the EQM Merger | | | — | | | — | | | — | | | — | | | (10,929) | | | (10,929) | | | — | |
| Redemption of EQM Series A Preferred Units | | | — | | | — | | | (27,253) | | | — | | | (590,085) | | | (617,338) | | | — | |
| Restructuring Agreement | | | — | | | (82,717) | | | — | | | — | | | (579,157) | | | (661,874) | | | 667,214 | |
| EQM Merger | | | 203,137 | | | 2,736,229 | | | — | | | — | | | (2,993,453) | | | (257,224) | | | |
| Balance at June 30, 2020 | | | 432,469 | | | $ | 3,952,672 | | | $ | (866,084) | | | $ | (1,966) | | | $ | 463,045 | | | $ | 3,547,667 | | | $ | 669,465 | |
| Other comprehensive income (net of tax): | | | | | | | | | | | | | | | |
| Net income | | | — | | | — | | | 149,838 | | | — | | | 3,973 | | | 153,811 | | | 14,628 | |
| Pension and other post-retirement benefits liability adjustment, net of tax expense of $10 | | | — | | | — | | | — | | | 30 | | | — | | | 30 | | | — | |
| Dividends on common shares ($0.15 per share) | | | — | | | — | | | (65,117) | | | — | | | — | | | (65,117) | | | — | |
| Share-based compensation plans | | | 1 | | | 3,262 | | | — | | | — | | | — | | | 3,262 | | | — | |
| Dividends paid to holders of Equitrans Midstream Preferred Shares ($0.075 per share) | | | — | | | — | | | — | | | — | | | — | | | — | | | (2,251) | |
| | | | | | | | | | | | | | | |
| | | | | | | | | | | | | | | |
| Balance at September 30, 2020 | | | 432,470 | | | $ | 3,955,934 | | | $ | (781,363) | | | $ | (1,936) | | | $ | 467,018 | | | $ | 3,639,653 | | | $ | 681,842 | |
| | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | |
| | | | | | | | | | | | | Mezzanine |
| | | | | | | | | | | | | Equity |
| Common Stock | | | | | | | | | | |
| | | | | | | Accumulated | | | | | | Equitrans |
| | | | | Retained | | Other | | | | | | Midstream |
| Shares | | No | | Earnings | | Comprehensive | | Noncontrolling | | Total | | Preferred |
| Outstanding | | Par Value | | (Deficit) | | Loss | | Interests | | Equity | | Shares |
| (Thousands, except per share and unit amounts) |
| Balance at January 1, 2020 | 254,745 | | | $ | 1,292,804 | | | $ | (618,062) | | | $ | (2,026) | | | $ | 4,609,364 | | | $ | 5,282,080 | | | $ | 0 | |
| 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 | — | | | — | | | — | | | 30 | | | — | | | 30 | | | — | |
| Dividends on common shares ($0.45 per share) | (178) | | | — | | | (115,400) | | | — | | | — | | | (115,400) | | | — | |
| Share-based compensation plans | 85 | | | 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 6) | (25,300) | | | — | | | (190,992) | | | — | | | — | | | (190,992) | | | — | |
| | | | | | | | | | | | | |
| Adoption of Topic 326 (as defined in Note 1) | — | | | — | | | (3,718) | | | — | | | — | | | (3,718) | | | — | |
| | | | | | | | | | | | | |
| Balance at March 31, 2020 | 229,352 | | | $ | 1,297,304 | | | $ | (858,440) | | | $ | (1,996) | | | $ | 4,607,450 | | | $ | 5,044,318 | | | $ | 0 | |
| Other comprehensive income (net of tax): | | | | | | | | | | | | | |
| Net income | — | | | — | | | 54,243 | | | — | | | 86,964 | | | 141,207 | | | 2,251 | |
| Pension and other post-retirement benefits liability adjustment, net of tax expense of $10 | — | | | — | | | — | | | 30 | | | — | | | 30 | | | — | |
| Dividends on common shares ($0.15 per share) | — | | | — | | | (34,634) | | | — | | | — | | | (34,634) | | | — | |
| Share-based compensation plans | (20) | | | 1,856 | | | — | | | — | | | — | | | 1,856 | | | — | |
| Distributions paid to noncontrolling interest unitholders ($0.3875 per common unit for EQM) | — | | | — | | | — | | | — | | | (32,244) | | | (32,244) | | | — | |
| Distributions paid to holders of EQM Series A Preferred Units ($1.0364 per EQM Series A Preferred Unit) | — | | | — | | | — | | | — | | | (25,501) | | | (25,501) | | | — | |
| Partial period distributions on EQM Series A Preferred Units converted in the EQM Merger | — | | | — | | | — | | | — | | | (10,929) | | | (10,929) | | | — | |
| Redemption of EQM Series A Preferred Units | — | | | — | | | (27,253) | | | — | | | (590,085) | | | (617,338) | | | — | |
| Restructuring Agreement (as defined in Note 1) | — | | | (82,717) | | | — | | | — | | | (579,157) | | | (661,874) | | | 667,214 | |
| EQM Merger (as defined in Note 1) | 203,137 | | | 2,736,229 | | | — | | | — | | | (2,993,453) | | | (257,224) | | | — | |
| | | | | | | | | | | | | |
| | | | | | | | | | | | | |
| Balance at June 30, 2020 | 432,469 | | | $ | 3,952,672 | | | $ | (866,084) | | | $ | (1,966) | | | $ | 463,045 | | | $ | 3,547,667 | | | $ | 669,465 | |
| Other comprehensive income (net of tax): | | | | | | | | | | | | | |
| Net income | — | | | — | | | 149,838 | | | — | | | 3,973 | | | 153,811 | | | 14,628 | |
| Pension and other post-retirement benefits liability adjustment, net of tax expense of $10 | — | | | — | | | — | | | 30 | | | — | | | 30 | | | — | |
| Dividends on common shares ($0.15 per share) | — | | | — | | | (65,117) | | | — | | | — | | | (65,117) | | | — | |
| Share-based compensation plans | 1 | | | 3,262 | | | — | | | — | | | — | | | 3,262 | | | — | |
| Dividends paid to holders of Equitrans Midstream Preferred Shares ($0.075 per share) | | | | | | | | | | | | | (2,251) | |
| Balance at September 30, 2020 | 432,470 | | | $ | 3,955,934 | | | $ | (781,363) | | | $ | (1,936) | | | $ | 467,018 | | | $ | 3,639,653 | | | $ | 681,842 | |
| | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | |
| | | | | | | | | | | | | Mezzanine |
| | | | | | | | | | | | | Equity |
| Common Stock | | | | | | | | | | |
| | | | | | | Accumulated | | | | | | Equitrans |
| | | | | | | Other | | | | | | Midstream |
| Shares | | No | | Retained | | Comprehensive | | Noncontrolling | | Total | | Preferred |
| Outstanding | | Par Value | | Deficit | | Loss | | Interests | | Equity | | Shares |
| (Thousands, except per share amounts) |
| Balance at January 1, 2021 | 432,470 | | | $ | 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, net | 28 | | | 4,662 | | | — | | | — | | | — | | | 4,662 | | | — | |
| Distributions paid to noncontrolling interest in Eureka Midstream Holdings, LLC | — | | | — | | | — | | | — | | | (2,500) | | | (2,500) | | | — | |
| Dividends paid to holders of Equitrans Midstream Preferred Shares ($0.4873 per share) | — | | | — | | | — | | | — | | | — | | | — | | | (14,628) | |
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| Balance at March 31, 2021 | 432,498 | | | $ | 3,945,957 | | | $ | (735,888) | | | $ | (2,195) | | | $ | 472,579 | | | $ | 3,680,453 | | | $ | 681,842 | |
| Other comprehensive income (net of tax): | | | | | | | | | | | | | |
| Net income | — | | | — | | | 22,485 | | | — | | | 3,008 | | | 25,493 | | | 14,628 | |
| Pension and other post-retirement benefits liability adjustment, net of tax expense of $12 | — | | | — | | | — | | | 35 | | | — | | | 35 | | | — | |
| Dividends on common shares ($0.15 per share) | — | | | — | | | (64,750) | | | — | | | — | | | (64,750) | | | — | |
| Share-based compensation plans, net | 7 | | | 3,635 | | | — | | | — | | | — | | | 3,635 | | | — | |
| Dividends paid to holders of Equitrans Midstream Preferred Shares ($0.4873 per share) | — | | | — | | | — | | | — | | | — | | | — | | | (14,628) | |
| Balance at June 30, 2021 | 432,505 | | | $ | 3,949,592 | | | $ | (778,153) | | | $ | (2,160) | | | $ | 475,587 | | | $ | 3,644,866 | | | $ | 681,842 | |
| Other comprehensive income (net of tax): | | | | | | | | | | | | | |
| Net income | — | | | — | | | 72,720 | | | — | | | 3,557 | | | 76,277 | | | 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) | — | | | — | | | (65,336) | | | — | | | — | | | (65,336) | | | — | |
| Share-based compensation plans | 17 | | | 3,304 | | | — | | | — | | | — | | | 3,304 | | | — | |
| Dividends paid to holders of Equitrans Midstream Preferred Shares ($0.4873 per share) | — | | | — | | | — | | | — | | | — | | | — | | | (14,628) | |
| Balance at September 30, 2021 | 432,522 | | | $ | 3,952,896 | | | $ | (770,769) | | | $ | (2,126) | | | $ | 479,144 | | | $ | 3,659,145 | | | $ | 681,842 | |
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The accompanying notes are an integral part of these consolidated financial statements.
EQUITRANS MIDSTREAM CORPORATION
Notes to Consolidated Financial Statements (Unaudited)
1. Financial Statements
Organization.Nature of Business. On November 12, 2018, Equitrans Midstream Corporation (together withThe Company provides midstream services to its consolidated subsidiaries as applicable,customers in Pennsylvania, West Virginia and Ohio through its three primary assets: the Company or Equitrans Midstream), EQT and, for certain limited purposes, EQT Production Company, a wholly owned subsidiary of EQT, entered into a Separation and Distribution Agreement, pursuant togathering system, which among other things, EQT effected the separation of EQT's midstream business, which was composed of the separately-operated naturalincludes predominantly dry gas gathering systems of high-pressure gathering lines; the transmission system, which includes FERC-regulated interstate pipelines and storage and water services operations of EQT, from EQT's upstream business, which was composed of the natural gas, oil and natural gas liquids development, production and sales and commercial operations of EQT (the Separation), including the transfer of certain assets and liabilities to Equitrans Midstream, and distributed 80.1% of the then-outstanding shares of common stock, no par value, of Equitrans Midstream (Equitrans Midstream common stock) to EQT shareholders of record as of the close of business on November 1, 2018 (the Distribution). The Distribution was effective at 11:59 p.m., Eastern Time, on November 12, 2018. As part of the Separation, EQT retained the remaining 19.9% of the outstanding shares in Equitrans Midstream.
EQM Merger. On June 17, 2020, pursuant to that certain Agreement and Plan of Merger, dated as of February 26, 2020 (the EQM Merger Agreement), 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 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. See Note 2 for further information on the EQM Merger.
Preferred Restructuring Agreement. On February 26, 2020, Equitrans Midstream and EQM entered into a Preferred Restructuring Agreement (the Restructuring Agreement) with all of the holders of the Series A Perpetual Convertible Preferred Units representing limited partner interests in EQM (such units, EQM Series A Preferred Units and, such investors, collectively, the Investors), pursuant to which, at the effective time of the EQM Merger (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 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 (ii) 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 (collectively, the Restructuringsystems; and the closingwater network, which consists of the Restructuring, the Restructuring Closing). See Note 2water pipelines, impoundment facilities, above ground storage facilities, pumping stations, take point facilities and measurement facilities that provide water delivery, gathering and storage services that support well completion activities and produced water flowback for further information on the Restructuring Agreement.recycling.
Basis of Presentation. References in these financial statements to Equitrans Midstream or the Company refer collectively to Equitrans Midstream Corporation and as applicable, its consolidated subsidiaries for all periods presented, unless otherwise indicated.
The accompanying unaudited consolidated financial statements have been prepared in accordance with GAAPgenerally 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 September 30, 2020 and December 31, 2019,2021, the results of its operations and equity for the three and nine months ended September 30, 20202021 and 20192020 and its cash flows for the nine months ended September 30, 20202021 and 2019.2020. The consolidated balance sheet at December 31, 20192020 has been derived from the audited financial statements at that date, but it 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, 2019,2020, which includes all disclosures required by GAAP.
Due to, among other things, the seasonal nature of the Company's utility customer contracts, and temporary volume curtailments by certain of the Company's customers, including EQT, as well as producers’ well completion activities and varying needs for
fresh and produced water (which are partially driven by horizontal lateral lengths and the number of completion stages per well), the interim statements for the three and nine months ended September 30, 20202021 are not necessarily indicative of the results that may be expected for the year ending December 31, 2020.2021.
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, 2019,2020, as well as "Management'sPart I, "Item 2. Management's Discussion and Analysis of Financial Condition and Results of Operations" contained herein.
Recently Issued Accounting Standards
In June 2016, the FASB issued ASU 2016-13, Financial Instruments-Credit Losses (Topic 326): Measurement of Credit Losses on Financial Instruments. The standard amended guidance on reporting credit losses for assets held at amortized cost basis and available for sale debt securities. For assets held at amortized cost basis, this standard eliminated the probable initial recognition threshold in then current GAAP, and, in its place, requires an entity to recognize its current estimate of all expected credit losses. The amendments affected loans, debt securities, trade receivables, contract assets, net investments in leases, off balance sheet credit exposures, reinsurance receivables, and any other financial assets not excluded from the scope of the standard that have the contractual right to receive cash. In May 2019, the FASB issued ASU 2019-05, Financial Instruments – Credit Losses (Topic 326). The update provides entities with targeted transition relief that is intended to increase comparability of financial statement information for some entities that otherwise would have measured similar financial instruments using different measurement methodologies. In November 2019, the FASB issued ASU 2019-11, Codification Improvements to Topic 326, Financial Instruments – Credit Losses. The update clarifies and addresses stakeholders' specific issues in ASU 2016-13.
The Company adoptedconsolidated financial statements as of and for the standard on January 1, 2020, using the modified retrospective method for all financial assets recorded at amortized cost. Results for reporting periods beginning after January 1, 2020 are presented under Topic 326 while prior period amounts continue to be reported in accordance with previously applicable GAAP. The Company's current expected credit loss (CECL) methodology considers risks of collection based on a customer’s current credit status. The standard requires an entity to assess whether financial assets share similar risk characteristicsthree and if so, group such assets in a pool. Customer balances are aggregated for evaluation based on their credit risk rating, which takes into account changes in economic factors that impact a customer’s ability to meet its financial obligations. The Company's CECL methodology assigns a reserve, even if remote, to each customer based on credit risk. The table below summarizes the changes in the allowance for credit losses by outstanding receivable for the nine months ended September 30, 2020:
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| Accounts Receivable | | Contract Asset (a) | | Other Assets (b) | | Total |
| Balance at December 31, 2019 | $ | (285) | | | $ | 0 | | | $ | 0 | | | $ | (285) | |
| Adoption of Topic 326 | (2,708) | | | 0 | | | (1,010) | | | (3,718) | |
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| Provision for (recovery of) expected credit losses | (616) | | | (222) | | | 26 | | | (812) | |
| Balance at September 30, 2020 | $ | (3,609) | | | $ | (222) | | | $ | (984) | | | $ | (4,815) | |
(a) Included in other current assets in2021 and 2020, and the consolidated balance sheets.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.
(b) Includes the Company's Preferred Interest in EES and other long-term receivables.Recently Issued Accounting Standards.
In August 2018, the FASB issued ASU 2018-13, Fair Value Measurement, Changes to the Disclosure Requirements for Fair Value Measurement, which makes a number of changes to the hierarchy associated with Level 1, 2 and 3 fair value measurements and the related disclosure requirements. This guidance is effective for fiscal years beginning after December 15, 2019, including interim periods within those fiscal years. The Company adopted this standard on January 1, 2020. The adoption of this standard did not have an impact on the Company's financial statements.
In December 2019, the FASB issued ASU 2019-12, Simplifying the Accounting for Income Taxes, which enhances and simplifies various aspects of the income tax accounting guidance including the elimination of certain exceptions related to the approach for intra-period tax allocation, the methodology for calculating income taxes in an interim period and the recognition of deferred tax liabilities for outside basis differences. The guidance also simplifies aspects of the accounting for franchise taxes and enacted changes in tax laws or rates and clarifies the accounting for transactions that result in a step-up in the tax basis of goodwill. The guidance will be effective for fiscal years, and interim periods within those fiscal years, beginning after December 15, 2020, with early adoption permitted. The Company early-adopted the standard in the first quarter of 2020 with no significant effect on its financial statements or related disclosures.
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 Amended 2019 EQM Term Loan Agreement (as2021 Eureka Credit Facility (each as defined in Note 9) and the Eureka Credit Facility,8), 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 iswas 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.
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 be 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 of this standard on its financial statements.
2. Investments in Consolidated, Non-Wholly Owned Entities
Investment in EQM
EQM IDR TransactionMerger. . On February 22, 2019, the Company completed a simplification transactionJune 17, 2020, pursuant to that certain Agreement and Plan of Merger, dated as of February 13, 2019,26, 2020, by and among the Company, and certain related parties, pursuant to which, among other things, (i) EquitransEQM LP Corporation, a wholly owned subsidiary of the Company (EQM LP), LS Merger Sub, LP merged with and into EQGP (the IDR Merger) with EQGP continuing as the surviving limited partnership andLLC, a wholly owned subsidiary of EQM and (ii) each of (a) the IDRs in EQM, (b) the economic portion of the general partner interest inLP (Merger Sub), EQM and (c) the issued and outstanding common units representing limited partner interests in EQGP (EQGP Common Units) were canceled, and, as consideration for such cancellation, certain affiliates of the Company received on a pro rata basis 80,000,000 newly-issued EQM Common Units and 7,000,000 newly-issued Class B units representing limited partner interests in EQM (Class B units), and the EQM General Partner retained the non-economic general partner interest in EQM (such transactions, collectively, the EQM IDR Transaction). Additionally, as part of the EQM IDR Transaction, 21,811,643 EQM Common Units held by EQGP were canceled and 21,811,643 EQM Common Units were issued pro rata to certain subsidiaries of the Company. As a result of the EQM IDR Transaction, the EQM General Partner replaced EQM Midstream Services, LLC, as the general partner of EQM.
After giving effect to the EQM IDR Transaction, including the issuance of Class B units, Equitrans Gathering Holdings, LLC (Equitrans Gathering Holdings), EQM GP Corporation (EQM GP Corp) and Equitrans Midstream Holdings, LLC (EMH), each a wholly owned subsidiary of Equitrans Midstream, held 89,505,616, 89,536 and 27,650,303 EQM Common Units, respectively, for a total of 117,245,455 EQM Common Units. Additionally, Equitrans Gathering Holdings, EQM GP Corp and EMH held 6,153,907, 6,155 and 839,938 Class B units, respectively, for a total of 7,000,000 Class B units.
During the first quarter of 2019, as a result of the EQM IDR Transaction, the Company recorded, in the aggregate, a $991.1 million increase of common stock, no par value, a decrease in noncontrolling interest of $1.3 billion and a decrease in deferred tax asset of $346.5 million.
EQM Merger. As discussed in Note 1, on June 17, 2020, the Company, EQM, EQM LP, Merger Sub and the(the EQM General Partner completed the EQM Merger, pursuant to whichPartner), Merger Sub merged with and into EQM (the EQM Merger), with EQM continuing and surviving as an indirect, wholly owned subsidiary of the Company. As a resultUpon 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 iswas no longer a publicly traded entity.
At the effective time of the EQM Merger (the Effective Time,Time), subject to applicable tax withholding, (i) each outstanding EQM Common Unit,common unit, other than EQM Common Unitscommon 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 UnitsUnits) 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 PricePrice) 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;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 Unitcommon 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 Unitcommon 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 (including the Class B units) 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,common units, offset by an increase in common stock, no par value.value, during the second quarter of 2020. No gain or loss was recognized in the Company’s statementstatements of consolidated comprehensive income as a result of the EQM Merger. In addition, the tax effects of the EQM Merger arewere 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,common units were reflected within noncontrolling interest in the Company's consolidated balance sheets asprior to completion of March 31, 2020.the EQM Merger. The portion of EQM earnings attributable to publicly held EQM Common Unitscommon 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.
During the second quarter of 2020, as a result of the EQM Merger, the Company recorded, in the aggregate, a $2.7 billion increase of common stock, no par value, a decrease in noncontrolling interest of $3.0 billion and an increase in deferred tax liability of $257.2 million.
Additionally, for the period from January 1, 2020 to June 17, 2020, the Company determined that EQM was a variable interest entity. Through the Company's ownership and control of the general partner of EQM during that period, 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 $1.0 million and $23.8 million in expenses related to the EQM Merger and the EQT Global GGA (defined(as defined in Note 4)3) during the three and nine months ended September 30, 2020, respectively. The expenses consisted ofprimarily included advisor, legal and accounting fees related to the transactions and are included in separation and other transaction costs in the statements of consolidated comprehensive income.
Preferred Restructuring Agreement. As discussed in Note 1, on June 17,On February 26, 2020, concurrentlythe Company and EQM entered into a Preferred Restructuring Agreement (the Restructuring Agreement) with all of the closingholders of the EQM Merger: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 Effective TimeRestructuring Closing (as 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.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.
On June 17, 2020, the Company paid cash of $617.3 million to redeem $600 million aggregate principal amount of the Investors’ EQM Series A Preferred Units and pay partial period distributions on such EQM Series A Preferred Units. At the time of the redemption, the carrying value of the EQM Series A Preferred Units was $590.1 million, resulting in a premium over the carrying value of $27.3 million. The premium represented a return similar to distributions to the holders of the EQM Series A Preferred Units and, as such, reduced net income attributable to Equitrans Midstream common shareholders, and was recorded in retained earnings (deficit) in the statements of consolidated shareholders' equity and mezzanine equity.
Pursuant to the Restructuring Agreement, in connection with the Restructuring Closing, the Company filed a statement with respect to shares, attaching a Certificate of Designations (the Certificate of Designations), with the Pennsylvania Department of State on June 17, 2020 to, among other things, authorize and establish the designations, rights and preferences of the Equitrans Midstream Preferred Shares. On August 13, 2020, pursuant to the terms of the Certificate of Designations,Restated Articles (as defined below), the Company paid
$10.9 $10.9 million in the aggregate to holders of Equitrans Midstream Preferred Shares related to forgone partial period distributions on the EQM Series A Preferred Units that were converted into Equitrans Midstream Preferred Shares in connection with the EQM Merger.
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 securitysecurities 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 Certificate of Designations or the Company’s Amended and Restated Articles of Incorporation 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.
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 Certificate of Designations)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”)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.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 Certificate of Designations)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 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 Company's Board of Directors (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.
During the second quarter of 2020, as a result of the Restructuring Closing, the Company recorded an increase in mezzanine equity of $667.2 million, a decrease in noncontrolling interest of $579.2 million and a decrease in common stock, no par value, of $82.7 million, net of deferred taxes of $5.3 million.
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. Mergers and Acquisitions
EQM Merger. See Note 2.
Bolt-on Acquisition. On March 13, 2019, the Company (through EQM) entered into a Purchase and Sale Agreement with North Haven Infrastructure Partners II Buffalo Holdings, LLC (NHIP), an affiliate of Morgan Stanley Infrastructure Partners, pursuant to which the Company acquired from NHIP a 60% Class A interest in Eureka Midstream Holdings, LLC (Eureka Midstream) and a 100% interest in Hornet Midstream Holdings, LLC (Hornet Midstream) (collectively, the Bolt-on Acquisition) for total consideration of approximately $1.04 billion, composed of approximately $852 million in cash, net of purchase price adjustments, and approximately $192 million in assumed pro-rata debt. At the time of the acquisition, Eureka Midstream owned a 190-mile gathering header pipeline system in Ohio and West Virginia that services both dry Utica and wet Marcellus Shale production and Hornet Midstream owned a 15-mile, high-pressure gathering system in West Virginia that connects to the Eureka Midstream system. The Bolt-on Acquisition closed on April 10, 2019 and was funded through proceeds from the March
2019 private placement by EQM of an aggregate of 24,605,291 EQM Series A Preferred Units that closed concurrently with the Bolt-on Acquisition.
At the closing of the Bolt-on Acquisition, a subsidiary of Hornet Midstream terminated all of its obligations under its term loan credit agreement and repaid the $28.2 million outstanding principal balance and $0.1 million in related interest and fees.
The Company recorded $0.3 million and $17.0 million in acquisition-related expenses related to the Bolt-on Acquisition during the three and nine months ended September 30, 2019, respectively. The Bolt-on Acquisition acquisition-related expenses included $0.3 million for professional fees for the three months ended September 30, 2019 and $15.3 million for professional fees and $1.7 million for compensation arrangements for the nine months ended September 30, 2019, and are included in separation and other transaction costs in the statements of consolidated comprehensive income.
The Bolt-on Acquisition was accounted for as a business combination using the acquisition method. As a result of the acquisition, the Company recognized $99.2 million of goodwill, which was allocated to the Gathering segment. Such goodwill primarily related to additional commercial opportunities, a diversified producer customer mix, increased exposure to dry Utica and wet Marcellus acreage and operating leverage within the Gathering segment. The purchase price allocation and related adjustments were finalized during the fourth quarter of 2019. The following table summarizes the final purchase price and allocation of the fair value of the assets acquired and liabilities assumed in the Bolt-on Acquisition as of April 10, 2019 by the Company, as well as certain measurement period adjustments made subsequent to the Company's initial valuation.
| | | | | | | | | | | | | | | | | | | | |
| (in thousands) | | Preliminary Purchase Price Allocation (As initially reported) | | Measurement Period Adjustments (a) | | Purchase Price Allocation (As adjusted) |
| Consideration given: | | | | | | |
Cash consideration (b) | | $ | 861,250 | | | $ | (11,404) | | | $ | 849,846 | |
| Buyout of portion of Eureka Midstream Class B Units and incentive compensation | | 2,530 | | | — | | | 2,530 | |
| Total consideration | | 863,780 | | | (11,404) | | | 852,376 | |
| | | | | | |
| Fair value of liabilities assumed: | | | | | | |
| Current liabilities | | 52,458 | | | (9,857) | | | 42,601 | |
| Long-term debt | | 300,825 | | | — | | | 300,825 | |
| | | | | | |
| Other long-term liabilities | | 10,203 | | | — | | | 10,203 | |
| Amount attributable to liabilities assumed | | 363,486 | | | (9,857) | | | 353,629 | |
| | | | | | |
| Fair value of assets acquired: | | | | | | |
| Cash | | 15,145 | | | — | | | 15,145 | |
| Accounts receivable | | 16,817 | | | — | | | 16,817 | |
| Inventory | | 12,991 | | | (26) | | | 12,965 | |
| Other current assets | | 882 | | | — | | | 882 | |
| Net property, plant and equipment | | 1,222,284 | | | (8,906) | | | 1,213,378 | |
Intangible assets (c) | | 317,000 | | | (6,000) | | | 311,000 | |
| Deferred tax asset | | 5,773 | | | (5,268) | | | 505 | |
| Other assets | | 14,567 | | | — | | | 14,567 | |
| Amount attributable to assets acquired | | 1,605,459 | | | (20,200) | | | 1,585,259 | |
| | | | | | |
| Noncontrolling interests | | (486,062) | | | 7,602 | | | (478,460) | |
| | | | | | |
| Goodwill as of April 10, 2019 | | $ | 107,869 | | | $ | (8,663) | | | $ | 99,206 | |
Impairment of goodwill (d) | | | | | | (99,206) | |
| Goodwill as of September 30, 2020 | | | | | | $ | 0 | |
(a) The Company recorded measurement period adjustments to its preliminary acquisition date fair values due to the refinement of its valuation models, assumptions and inputs. The measurement period adjustments were based upon information obtained about facts and circumstances that existed at the acquisition date that, if known, would have affected the measurement of the amounts recognized at that date.
(b) The cash consideration for the Bolt-on Acquisition was adjusted by approximately $11.4 million related to working capital adjustments and the release of all escrowed indemnification funds to EQM.
(c) After considering the refinements to the valuation models, the Company estimated the fair value of the customer-related intangible assets acquired as part of the Bolt-on Acquisition to be $311.0 million. As a result, the fair value of the customer-related intangible assets was decreased by $6.0 million on September 30, 2019 with a corresponding increase to goodwill. In addition, the change to the provisional amount resulted in a decrease in amortization expense and accumulated amortization of approximately $0.4 million.
(d) During the third quarter of 2019, the Company identified impairment indicators that suggested the fair value of its goodwill was more likely than not below its carrying amount. As such, the Company performed an interim goodwill impairment assessment, which resulted in the Company recognizing impairment to goodwill of approximately $268.1 million, of which $99.2 million was associated with its Eureka/Hornet reporting unit, bringing the reporting unit's goodwill balance to 0. See Note 4 for further detail.
The estimated fair value of midstream facilities and equipment, generally consisting of pipeline systems and compression stations, was estimated using the cost approach. Significant unobservable inputs in the estimate of fair value under this approach included management's assumptions about the replacement costs for similar assets, the relative age of the acquired assets and any potential economic or functional obsolescence associated with the acquired assets. As a result, the estimated fair value of the midstream facilities and equipment represented a Level 3 fair value measurement.
As a result of the acquisition, the noncontrolling interest in Eureka Midstream was estimated to be $478.5 million. The fair value of the noncontrolling interest was calculated based on the enterprise value of Eureka Midstream and the percentage ownership not acquired by the Company. Significant unobservable inputs in the enterprise value of Eureka Midstream include future revenue estimates and future cost assumptions. As a result, the fair value measurement is based on significant inputs that are not observable in the market and thus represents a Level 3 fair value measurement.
As part of the preliminary purchase price allocation, the Company identified intangible assets for customer relationships with third-party customers. The fair value of the customer relationships with third-party customers was determined using the income approach, which requires a forecast of the expected future cash flows generated and an estimated market-based weighted average cost of capital. Significant unobservable inputs in the determination of fair value include future revenue estimates, future cost assumptions and estimated customer retention rates. As a result, the estimated fair value of the identified intangible assets represents a Level 3 fair value measurement. The Company calculates amortization of intangible assets using the straight-line method over the estimated useful life of the intangible assets.
The Company previously utilized a useful life of 20 years for the Eureka Midstream- and Hornet Midstream-related intangible assets. As a result of expected changes in cash flows due to decreases in producer activity driven by lower natural gas prices, as of April 1, 2020, the Company prospectively changed the remaining useful life of the Eureka Midstream-related intangible assets to 10.75 years, increasing the expected annual amortization expense by $9.1 million. In addition, as a result of then expected reductions in future cash flows, as of October 1, 2019, the useful life of the Hornet Midstream-related intangible assets was prospectively changed to 7.25 years. The estimated annual amortization expense for the Eureka Midstream- and Hornet Midstream-related intangible assets for the remaining three months of 2020 and over the successive five years is as follows: 2020 $5.8 million, 2021 $23.3 million, 2022 $23.3 million, 2023 $23.3 million, 2024 $23.3 million and 2025 $23.3 million.
As discussed in Note 4, during the third quarter of 2019, as a result of a recoverability test conducted due to a decrease in producer activity, the Company determined that the estimated fair value of the Hornet Midstream-related intangible assets was not in excess of the assets’ carrying value, which resulted in an impairment charge of $36.4 million related to certain of such intangibles within the Company’s Gathering segment. The Company also performed a recoverability test during the first quarter of 2020 due to significant declines in the unit price of EQM Common Units and corresponding market capitalization, which resulted in an additional impairment charge of $17.7 million to the Hornet Midstream-related intangible assets (see Note 4). The useful life of the Hornet Midstream-related intangible assets remained 7.25 years following the first quarter 2020 recoverability test.
In conjunction with the Bolt-on Acquisition, the Company recorded tax deductible goodwill of $43.0 million. The Company does not have tax basis on the portion attributable to the former noncontrolling limited partners of EQM or on the portion attributable to the noncontrolling member of Eureka Midstream.
4. Impairments of Long-Lived Assets and Other-Than-Temporary Decline in Value
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 6)5). Prior to the EQT Global GGA Effective Date, the Company operated 3 reportable operating segments and 7 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 merger withacquisition 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 MVCminimum 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.
As of September 30, 2021, the Company's goodwill balance was associated entirely with the EQM Opco reporting unit. During the first quarter of 2020, the Company identifiedthree and nine months ended September 30, 2021, no impairment indicators were identified that would indicate, in the form of significant declines in the unit price of EQM Common Units and corresponding market capitalization. Management considered these declines as indicatorsmanagement's judgment, that it is more likely than not that the fair value of the RMP PA Gas GatheringEQM Opco reporting unit was more likelyless than not 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 andvalue. However, the EQM Opco reporting unit is susceptible to impairment risk from future adverse market or economic conditions and Company-specific qualitative factors, contractual changes or modifications or other adverse factors such as unexpected future production curtailments by 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 determinedCompany's customers that the fair values of the RMP PA Gas Gathering reporting unit and the merged EQM Opco reporting unit, as applicable, 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. Additionalhave contracts with volumetric-based fees. Any such adverse changes in the future could reduce the underlying cash flows used to estimate the fair value of the merged EQM Opco reporting unit and could result in a decline in fair value that could trigger future impairment charges relating to the EQM Opco reporting unit.
The three reporting units to which the Company had goodwill during 2019 were (i) the Ohio gathering assets acquired in connection with EQM’s acquisition of the outstanding limited liability company interests in each of EQM West Virginia Midstream LLC (EQM West Virginia), EQM Olympus Midstream LLC (EQM Olympus) and Strike Force Midstream Holdings LLC (Strike Force Holdings) (collectively, Rice Retained Midstream) (ii) RMP PA Gas Gathering and (iii) the Ohio and West Virginia gathering assets acquired in the Bolt-on Acquisition (Eureka/Hornet, collectively with Rice Retained Midstream and RMP PA Gas Gathering, the Reporting Units).
During the third quarter of 2019, the Company identified impairment indicators in the form of significant declines in the unit price of EQM's Common Units and corresponding market capitalization, primarily as a result of continued suppressed natural gas prices and decreased producer drilling activity. Management considered these declines as indicators that the fair value of goodwill was more likely than not below the carrying amounts for the respective Reporting Units. As such, the performance of an interim goodwill impairment assessment was required. In estimating the fair value of each of the Reporting Units, the Company used a combination of the income approach and the market approach, both as described above.
As of August 31, 2019, the Company determined that the fair value of Rice Retained Midstream was greater than its carrying value; however, the carrying values of RMP PA Gas Gathering and Eureka/Hornet were each greater than their respective fair values. As a result, the Company recognized impairment of goodwill of $168.9 million and $99.2 million on RMP PA Gas Gathering and Eureka/Hornet, respectively. The non-cash impairment charge is included in the impairments of long-lived assets line on the Company's statements of consolidated comprehensive income.
Long-lived assets, including intangible assets and equity method investments.Assets. The Company evaluates long-lived assets, including related intangibles, for impairment when events or changes in circumstances indicate, in management's judgment, that the carrying value of such assets may not be recoverable. Asset recoverability is measured by comparing the carrying value of the asset or asset group with its expected future pre-tax undiscounted cash flows. These cash flow estimates require the Company to make projections and assumptions for many years into the future for pricing, demand, competition, operating cost and other factors. If the carrying amount exceeds the expected future undiscounted cash flows, the Company recognizes an
impairment equal to the excess of net book value over fair value as determined by quoted market prices in active markets or present value techniques if quotes are unavailable. The determination of the fair value using present value techniques requires the Company to make projections and assumptions regarding the probability of a range of outcomes and the rates of interest used in the present value calculations. Any changes the Company makes to these projections and assumptions could result in significant revisions to its evaluation of recoverability of its property, plant and equipment and the recognition of additional impairments.
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 ofless than 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 third quarterAs of 2019,June 30, 2021, the Company assessed itsperformed a recoverability test of the Equitrans Water Services (OH) LLC (Ohio Water) long-lived asset groups for impairmentassets due to decreased producer activity in Ohio within the triggering events described in the goodwill impairment summary above.Company's Water segment. As a result of the recoverability test, management determined that the carrying value of certainthe Ohio Water long-lived assets associated with Eureka/Hornet (specifically, Hornet Midstream customer-related intangible assets) werewas not recoverable.recoverable under ASC 360, Impairment Testing: Long-Lived Assets Classified as Held and Used. The Company estimated the fair value of the Hornet Midstream-related intangible assetsOhio Water asset group and determined that the fair value was not in excess ofless than the assets’ carrying value, which resulted in an impairment chargecharges of approximately $36.4$56.2 million related to certain of such intangiblethe Ohio Water assets within the Company's GatheringWater segment. The non-cash impairment charge was recognized during the second quarter of 2021 and is included in the impairments of long-lived assets line on the statements of consolidated comprehensive income.
Equity Method Investment. During 2019,2020, the Company reassessed its asset groupings for its regulated pipelines due toMVP Joint Venture received certain regulatory ratemaking policy changes affectingadverse court rulings in the regulated pipelines, changesU.S. Fourth Circuit Court of Appeals as described in strategic focus and plans for segmentationPart II, “Item 1. Legal Proceedings” of operations. Prior to the second quarter of 2019, the Company defined its regulated asset grouping to include the FERC-regulated transmission and storage assets, integrated with the low-pressure assets due to overlapping operations, a shared costs structure and similar ratemaking structures. During the second quarter of 2019, Equitrans L.P. reached a settlement related to its FERCthis Quarterly Report on Form 501-G report, which was focused solely on the Company’s FERC-regulated transmission and storage assets. Further, management increased its operational focus and emphasis on high-pressure gathering assets as illustrated by the consummation of the Bolt-on Acquisition.10-Q. As a result, of these regulatory changes and shift in operational focus, beginning with the second quarter of 2019, the Company grouped its FERC-regulated assets in two asset groupings: FERC-regulated transmission and storage assets and FERC-regulated low-pressure gathering assets. Upon the change in asset grouping, management evaluated whether any indicators of impairment were present and, in conjunction with the evaluation, the Company determined that the carrying values for the non-core FERC-regulated low-pressure gathering assets exceeded their undiscounted cash flows. Additionally, following the settlement related to the FERC Form 501-G report, management did not, and currently does not, plan to seek to recover the deficient cash flows through a future rate proceeding. The Company therefore estimated the fair values of FERC-regulated low-pressure gathering assets and determined that their fair values were not in excess of the assets’ carrying values, which resulted in recognized impairments of property and equipment of approximately $80.1 million during the second quarter of 2019 related to the assets within the Company's Gathering segment. As a result of the impairment, the assets carry no book value. The non-cash impairment charge is included in the impairments of long-lived assets line on the statements of consolidated comprehensive income.
The Company is also required to evaluate its equity method investments, including investmentsinvestment in the MVP Joint Venture to determine whether they are impaired under ASC 323, Investments - Equity Methodfor impairment during the fourth quarter of 2020 and Joint Ventures. The standard for determining whether an impairment must be recorded under ASC 323 is whether there occurred an other-than-temporary decline in value. The evaluation and measurement of impairments under ASC 323 involves the same uncertainties as described above for long-lived assetsdetermined that the fair value of the investment continued to exceed the carrying value and, therefore, no impairment was necessary. The Company owns directlyestimated 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 accounts for in accordance with ASC 360. The estimates that the Company makes with respect to its equity method investments are based uponrevenues as of December 31, 2020. These scenarios reflected assumptions that management believes are reasonable,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 variationsthe 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 these estimates or the underlying assumptions could be material. Additionally, ifanalysis derived based on a market participant approach. Based on the Company’s expectations for the MVP Joint Venture's projects, inand 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 holds these investments recognize an impairmentreceived all required legal and regulatory approvals and authorizations and certain compression expansion opportunities are realized. A low probability was assigned to the scenario under ASC 360,which the Company would record its proportionate share of that impairment loss and would evaluate its investment for an other-than-temporary decline in value under ASC 323. project is cancelled.
The Company evaluated its equity method investments, including investmentsinvestment in the MVP Joint Venture as of September 30, 20202021 and determined that there was not an other-than-temporary decline in value.
There is risk that the carrying value of the Company's investmentsinvestment in the MVP Joint Venture may be impaired in the future. There are ongoing legal and regulatory matters that must be resolved favorably before each of the MVP and MVP Southgate projects
can be completed. Assumptions and estimates utilized to testin assessing the Company’s investmentsinvestment in the MVP Joint Venture for impairment may change if adversedepending on the nature or delayedtiming of resolutions to these legal or regulatory matters wereor based on other relevant developments. Adverse changes in circumstances relevant to occur, whichthe 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 investmentsinvestment in the MVP Joint Venture.Venture and potentially result in an impairment, the results of which could have a material adverse effect on the Company's results of operations and financial position.
5.4. Financial Information by Business Segment
The Company reports its operations in 3 segments that reflect its 3 lines of business:business of Gathering, Transmission and Water. Gathering includes predominantly dry gas gathering systems of high-pressure gathering linesWater, which reflects the manner in which management evaluates the business for making operating decisions and FERC-regulated low-pressure gathering lines; Transmission includes FERC-regulated interstate pipelines and storage systems; and Water consists of the Company's water pipelines, impoundment facilities, pumping stations, take point facilities and measurement facilities.assessing performance.
| | | | Three Months Ended September 30, | | Nine Months Ended September 30, | | Three Months Ended September 30, | | Nine Months Ended September 30, |
| | | 2020 | | 2019 | | 2020 | | 2019 | | 2021 | | 2020 | | 2021 | | 2020 |
| | | (Thousands) | | (Thousands) |
| Revenues from customers: | Revenues from customers: | | | | | Revenues from customers: | | | | |
| Gathering | Gathering | $ | 232,651 | | | $ | 299,491 | | | $ | 764,229 | | | $ | 847,038 | | Gathering | $ | 243,816 | | | $ | 232,651 | | | $ | 733,844 | | | $ | 764,229 | |
| Transmission | Transmission | 93,329 | | | 87,299 | | | 288,869 | | | 289,926 | | Transmission | 90,886 | | | 93,329 | | | 295,203 | | | 288,869 | |
| Water | Water | 24,020 | | | 21,644 | | | 90,605 | | | 67,419 | | Water | 7,372 | | | 24,020 | | | 41,318 | | | 90,605 | |
| Total operating revenues | Total operating revenues | $ | 350,000 | | | $ | 408,434 | | | $ | 1,143,703 | | | $ | 1,204,383 | | Total operating revenues | $ | 342,074 | | | $ | 350,000 | | | $ | 1,070,365 | | | $ | 1,143,703 | |
| Operating income (loss): | | | | | | | | |
| Operating income: | | Operating income: | | | | | | | |
Gathering (a) | Gathering (a) | $ | 129,186 | | | $ | (98,489) | | | $ | 400,647 | | | $ | 177,720 | | Gathering (a) | $ | 132,582 | | | $ | 129,186 | | | $ | 399,309 | | | $ | 400,647 | |
| Transmission | Transmission | 63,460 | | | 59,690 | | | 201,714 | | | 207,684 | | Transmission | 59,703 | | | 63,460 | | | 203,153 | | | 201,714 | |
Water | Water | 10,118 | | | 7,722 | | | 40,173 | | | 18,980 | | Water | (4,414) | | | 10,118 | | | (55,577) | | | 40,173 | |
Headquarters (b)(c) | Headquarters (b)(c) | (2,255) | | | (7,376) | | | (24,646) | | | (16,621) | | Headquarters (b)(c) | (325) | | | (2,255) | | | (806) | | | (24,646) | |
| Total operating income (loss) | $ | 200,509 | | | $ | (38,453) | | | $ | 617,888 | | | $ | 387,763 | | |
| Total operating income | | Total operating income | $ | 187,546 | | | $ | 200,509 | | | $ | 546,079 | | | $ | 617,888 | |
| | Reconciliation of operating income (loss) to net income (loss): | | | |
| Reconciliation of operating income to net income: | | Reconciliation of operating income to net income: | | |
Equity income (c)(d) | Equity income (c)(d) | $ | 60,917 | | | $ | 44,448 | | | $ | 171,233 | | | $ | 112,293 | | Equity income (c)(d) | $ | 8,461 | | | $ | 60,917 | | | $ | 14,385 | | | $ | 171,233 | |
Other income | Other income | 21,864 | | | 70 | | | 39,006 | | | 2,637 | | Other income | 21,199 | | | 21,864 | | | 38,251 | | | 39,006 | |
| Loss on early extinguishment of debt | 0 | | | 0 | | | 24,864 | | | 0 | | |
| Loss on extinguishment of debt | | Loss on extinguishment of debt | — | | | — | | | 41,025 | | | 24,864 | |
| Net interest expense | Net interest expense | 86,411 | | | 65,606 | | | 219,960 | | | 188,268 | | Net interest expense | 94,101 | | | 86,411 | | | 284,887 | | | 219,960 | |
| Income tax expense | Income tax expense | 28,440 | | | 1,948 | | | 81,846 | | | 45,868 | | Income tax expense | 32,200 | | | 28,440 | | | 65,180 | | | 81,846 | |
| Net income (loss) | $ | 168,439 | | | $ | (61,489) | | | $ | 501,457 | | | $ | 268,557 | | |
| Net income | | Net income | $ | 90,905 | | | $ | 168,439 | | | $ | 207,623 | | | $ | 501,457 | |
(a)Impairments of long-lived assets of $298.7 million for the three months ended September 30, 2019 and $55.6 million and $378.8 million for the nine months ended September 30, 2020 and 2019, respectively, were included in Gathering operating income (loss).income. See Note 43 for further information.
(b)Impairments of long-lived assets of $56.2 million for the nine months ended September 30, 2021 were included in Water operating income. See Note 3 for further information.
(c)Includes separation and other transaction costs and other unallocated corporate expenses.
(c)Equity income is included in the Transmission segment.
| | | | | | | | | | | |
| September 30, 2020 | | December 31, 2019 |
| | (Thousands) |
| Segment assets: | | | |
| Gathering | $ | 7,743,615 | | | $ | 7,572,911 | |
Transmission (a) | 4,279,330 | | | 3,903,707 | |
| Water | 208,899 | | | 202,440 | |
| Total operating segments | 12,231,844 | | | 11,679,058 | |
| Headquarters, including cash | 398,836 | | | 362,651 | |
| Total assets | $ | 12,630,680 | | | $ | 12,041,709 | |
(a)The equity investments in the MVP Joint Venture are included in the Transmission segment.
| | | | | | | | | | | | | | | | | | | | | | | |
| | Three Months Ended September 30, | | Nine Months Ended September 30, |
| | 2020 | | 2019 | | 2020 | | 2019 |
| | (Thousands) |
| Depreciation: | | | | | | | |
| Gathering | $ | 44,648 | | | $ | 38,943 | | | $ | 126,915 | | | $ | 104,502 | |
| Transmission | 13,659 | | | 13,347 | | | 40,787 | | | 38,474 | |
| Water | 8,105 | | | 6,907 | | | 22,720 | | | 19,801 | |
| Headquarters | 360 | | | 263 | | | 849 | | | 3,953 | |
| Total | $ | 66,772 | | | $ | 59,460 | | | $ | 191,271 | | | $ | 166,730 | |
| Capital expenditures for segment assets: | | | | | | | |
Gathering (a) | $ | 90,452 | | | $ | 271,860 | | | $ | 303,063 | | | $ | 686,178 | |
Transmission (b) | 6,721 | | | 16,296 | | | 32,983 | | | 46,287 | |
| Water | 2,530 | | | 13,466 | | | 8,377 | | | 31,490 | |
| Headquarters | 447 | | | 1,068 | | | 3,234 | | | 6,787 | |
Total (c) | $ | 100,150 | | | $ | 302,690 | | | $ | 347,657 | | | $ | 770,742 | |
(e)Includes unrealized gains on derivative instruments recorded in the Gathering segment.
| | | | | | | | | | | |
| September 30, 2021 | | December 31, 2020 |
| | (Thousands) |
| Segment assets: | | | |
| Gathering | $ | 7,706,463 | | | $ | 7,739,836 | |
Transmission (a) | 4,617,136 | | | 4,357,382 | |
| Water | 133,871 | | | 185,802 | |
| Total operating segments | 12,457,470 | | | 12,283,020 | |
| Headquarters, including cash | 410,932 | | | 442,832 | |
| Total assets | $ | 12,868,402 | | | $ | 12,725,852 | |
(a)The equity investment in the MVP Joint Venture is included in the Transmission segment.
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| | Three Months Ended September 30, | | Nine Months Ended September 30, |
| | 2021 | | 2020 | | 2021 | | 2020 |
| | (Thousands) |
| Depreciation: | | | | | | | |
| Gathering | $ | 47,441 | | | $ | 44,648 | | | $ | 140,899 | | | $ | 126,915 | |
| Transmission | 13,835 | | | 13,659 | | | 41,461 | | | 40,787 | |
| Water | 4,364 | | | 8,105 | | | 20,740 | | | 22,720 | |
| Headquarters | 381 | | | 360 | | | 854 | | | 849 | |
| Total | $ | 66,021 | | | $ | 66,772 | | | $ | 203,954 | | | $ | 191,271 | |
| Expenditures for segment assets: | | | | | | | |
Gathering (a) | $ | 62,916 | | | $ | 90,452 | | | $ | 170,709 | | | $ | 303,063 | |
Transmission (b) | 5,755 | | | 6,721 | | | 17,050 | | | 32,983 | |
| Water | 10,803 | | | 2,530 | | | 20,430 | | | 8,377 | |
| Headquarters | 83 | | | 447 | | | 1,455 | | | 3,234 | |
Total (c) | $ | 79,557 | | | $ | 100,150 | | | $ | 209,644 | | | $ | 347,657 | |
(a)Includes approximately $13.5 million and $37.1 million of capital expenditures related to the noncontrolling interest in Eureka Midstream Holdings, LLC (Eureka Midstream) of approximately $4.8 million and $10.6 million for the three and nine months ended September 30, 2021, respectively, and approximately $13.5 million and $37.1 million for the three and nine months ended September 30, 2020, respectively, and includes approximately $6.7 million and $17.6 million of capital expenditures related to the noncontrolling interest in Eureka Midstream for the three and nine months ended September 30, 2019, 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 $65.6$94.3 million and $211.7$179.0 million for the three months ended September 30, 2020and2019, respectively, and $144.3 million and $512.9 million for the nine months ended September 30, 20202021, respectively, and 2019,$65.6 million and $144.3 million for the three and nine months ended September 30, 2020, 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, assumed capital expenditures associated with the Bolt-on Acquisition, transfers to/from inventory as assets are completed/assigned to a project and capitalized share-based compensation costs, was $8.3$1.2 million and $(15.3)$1.4 million for the three and nine months ended September 30, 20202021, respectively, and 2019, respectively,$8.3 million and $29.9 million and $(0.8) million for the three and nine months ended September 30, 2020, and 2019, respectively.
6.5. Revenue from Contracts with Customers
For the three and nine months ended September 30, 20202021 and 2019,2020, all revenues recognized on the Company's statements of consolidated comprehensive income are from contracts with customers. As of September 30, 20202021 and December 31, 2019,2020, all receivables recorded on the Company's consolidated balance sheets representrepresented performance obligations that have been satisfied and for which an unconditional right to consideration exists.
Summary of Disaggregated Revenues.disaggregated revenues. The tables below provide disaggregated revenue information by business segment.
| | | Three Months Ended September 30, 2020 | | Three Months Ended September 30, 2021 |
| | Gathering | | Transmission | | Water | | Total | | Gathering | | Transmission | | Water | | Total |
| | (Thousands) | | (Thousands) |
Firm reservation fee revenues (a) | Firm reservation fee revenues (a) | | $ | 145,533 | | | $ | 84,612 | | | $ | 9,005 | | | $ | 239,150 | | Firm reservation fee revenues (a) | | $ | 151,004 | | | $ | 84,053 | | | $ | 1,061 | | | $ | 236,118 | |
| Volumetric-based fee revenues | Volumetric-based fee revenues | | 87,118 | | | 8,717 | | | 15,015 | | | 110,850 | | Volumetric-based fee revenues | | 92,812 | | | 6,833 | | | 6,311 | | | 105,956 | |
| | Total operating revenues | Total operating revenues | | $ | 232,651 | | | $ | 93,329 | | | $ | 24,020 | | | $ | 350,000 | | Total operating revenues | | $ | 243,816 | | | $ | 90,886 | | | $ | 7,372 | | | $ | 342,074 | |
| | | Three Months Ended September 30, 2019 | | Three Months Ended September 30, 2020 |
| | Gathering | | Transmission | | Water | | Total | | Gathering | | Transmission | | Water | | Total |
| | (Thousands) | | (Thousands) |
Firm reservation fee revenues | Firm reservation fee revenues | | $ | 154,791 | | | $ | 81,990 | | | $ | 840 | | | $ | 237,621 | | Firm reservation fee revenues | | $ | 145,533 | | | $ | 84,612 | | | $ | 9,005 | | | $ | 239,150 | |
| Volumetric-based fee revenues | Volumetric-based fee revenues | | 144,700 | | | 5,309 | | | 20,804 | | | 170,813 | | Volumetric-based fee revenues | | 87,118 | | | 8,717 | | | 15,015 | | | 110,850 | |
| | Total operating revenues | Total operating revenues | | $ | 299,491 | | | $ | 87,299 | | | $ | 21,644 | | | $ | 408,434 | | Total operating revenues | | $ | 232,651 | | | $ | 93,329 | | | $ | 24,020 | | | $ | 350,000 | |
| | | | Nine Months Ended September 30, 2021 |
| | | Gathering | | Transmission | | Water | | Total |
| | | (Thousands) |
Firm reservation fee revenues (a) | | Firm reservation fee revenues (a) | | $ | 448,556 | | | $ | 269,239 | | | $ | 3,834 | | | $ | 721,629 | |
| Volumetric-based fee revenues | | Volumetric-based fee revenues | | 285,288 | | | 25,964 | | | 37,484 | | | 348,736 | |
| | Total operating revenues | | Total operating revenues | | $ | 733,844 | | | $ | 295,203 | | | $ | 41,318 | | | $ | 1,070,365 | |
| | | | Nine Months Ended September 30, 2020 |
| | | Gathering | | Transmission | | Water | | Total |
| | | (Thousands) |
Firm reservation fee revenues (a) | | Firm reservation fee revenues (a) | | $ | 446,721 | | | $ | 267,973 | | | $ | 32,788 | | | $ | 747,482 | |
| Volumetric-based fee revenues | | Volumetric-based fee revenues | | 317,508 | | | 20,896 | | | 57,817 | | | 396,221 | |
| | Total operating revenues | | Total operating revenues | | $ | 764,229 | | | $ | 288,869 | | | $ | 90,605 | | | $ | 1,143,703 | |
| | | | | | | | | | | | | | | | | | | | | | | | | | |
| | Nine Months Ended September 30, 2020 |
| | Gathering | | Transmission | | Water | | Total |
| | (Thousands) |
Firm reservation fee revenues (a) | | $ | 446,721 | | | $ | 267,973 | | | $ | 32,788 | | | $ | 747,482 | |
| Volumetric-based fee revenues | | 317,508 | | | 20,896 | | | 57,817 | | | 396,221 | |
| | | | | | | | |
| Total operating revenues | | $ | 764,229 | | | $ | 288,869 | | | $ | 90,605 | | | $ | 1,143,703 | |
| | | | | | | | |
| | Nine Months Ended September 30, 2019 |
| | Gathering | | Transmission | | Water | | Total |
| | (Thousands) |
| Firm reservation fee revenues | | $ | 431,520 | | | $ | 263,051 | | | $ | 4,531 | | | $ | 699,102 | |
| Volumetric-based fee revenues | | 415,518 | | | 26,875 | | | 62,888 | | | 505,281 | |
| | | | | | | | |
| Total operating revenues | | $ | 847,038 | | | $ | 289,926 | | | $ | 67,419 | | | $ | 1,204,383 | |
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(a) For the three months ended September 30, 2020, firmFirm reservation fee revenues associated with Gathering and Water included MVC unbilled revenues of approximately $5.5 million and $0.5 million, respectively, for the three months ended September 30, 2021, approximately $12.4 million and $1.5 million, respectively, for the nine months ended September 30, 2021, approximately $2.6 million and $1.9 million, respectively, of MVC unbilled revenues. Forfor the ninethree months ended September 30, 2020 firm reservation fee revenues associated with Gathering and Water included approximately $13.7 million and $11.4 million, respectively, of MVC unbilled revenues. There were 0 MVC unbilled revenues associated with Gathering and Water duringfor the three and nine months ended September 30, 2019.2020.
Contract Assets.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(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 monthtwelve-month periods after that date, and (ii) that a significant reversal of revenue recognized currently for the future MVC deficiency payment will not occur.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 nine months ended September 30, 2021 and 2020:
| | | | | | | | | | |
| | Unbilled Revenue | | |
| | (Thousands) | | |
Balance as of January 1, 2020 | | $ | 0 | | | |
Revenue recognized in excess of amounts invoiced (a)
| | 25,086 | | | |
Minimum volume commitments invoiced (b)
| | 0 | | | |
Balance as of September 30, 2020 | | $ | 25,086 | | | |
| | | | |
| | | | | | | | | | | | | |
| Unbilled Revenue | | |
| 2021 | | 2020 | | |
| (Thousands) | | |
| Balance as of beginning of period | $ | 18,618 | | | $ | — | | | |
Revenue recognized in excess of amounts invoiced (a) | 21,908 | | | 25,086 | | | |
Minimum volume commitments invoiced (b) | (23,373) | | | — | | | |
Amortization (c) | (78) | | | — | | | |
| Balance as of end of period | $ | 17,075 | | | $ | 25,086 | | | |
| | | | | |
(a)RevenuesPrimarily includes revenues associated with unbilled MVCs that are generally included in firm reservation fee revenues within the Gathering and Water segments, as described in the Summary of Disaggregated Revenues table above.above, and other contractual commitments of approximately $6.4 million during the nine months ended September 30, 2021.
(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.liabilities. As of September 30, 2020, theThe Company's contract liabilities consistconsisted 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 contract liabilities are classified as current or non-current according to when such amounts are expected to be recognized. As of September 30, 2021, total contract liabilities were $624.1 million, of which $1.1 million was classified as current and recorded in accrued liabilities and $623 million was classified as non-current and recorded in contract liability on the Company's consolidated balance sheets. As of December 31, 2020, the contract liabilities are classified as non-current as none ofwere $398.8 million, which was recorded in contract liability on the deferred revenue is expected to be recognized in revenue during the next five years.Company's consolidated balance sheets.
Contracts requiring advance payments and the recognition of contract liabilities are evaluated to determine whether the advance payments provide the Company with a significant financing benefit. This determination requires significant judgment and is based on the combined effect of the expected length of time between when the Company transfers the promised goodgoods or serviceservices to the customer and when the customer pays for those goods or services and the prevailing interest rates. The Company has assessed the EQT Global GGA and determined that this agreement does not contain a significant financing component.
The following table presents changes in the Company's deferred revenuecontract liability balances during the nine months ended September 30, 2021 and 2020:
| | | | | | | | | | |
| | | | Deferred Revenue |
| | | | (Thousands) |
Balance as of January 1, 2020 | | | | $ | 0 | |
Amounts recorded during the period (a)
| | | | 321,775 | |
Amounts transferred during the period (b)
| | | | 0 | |
Balance as of September 30, 2020 | | | | $ | 321,775 | |
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| | | Contract Liability |
| | | 2021 | | 2020 |
| | | (Thousands) |
| Balance as of beginning of period | | | $ | 398,750 | | | $ | — | |
Amounts recorded during the period (a) | | | 225,583 | | | 321,775 | |
Amounts transferred during the period (b) | | | (268) | | | — | |
| Balance as of end of period | | | $ | 624,065 | | | $ | 321,775 | |
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(a)Includes deferred billed revenue of approximately $74.6 million and $148.8 million recorded during the three and nine months ended September 30, 2021 and 2020 respectively, 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.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 as of September 30, 20202021 that the Company will invoice or transfer from contract liabilities and recognize in future periods.
| | | | | 2020(a) | | 2021 | | 2022 | | 2023 | | 2024 | | Thereafter | | Total | | | 2021(a) | | 2022 | | 2023 | | 2024 | | 2025 | | Thereafter | | Total |
| | | (Thousands) | | (Thousands) |
| Gathering firm reservation fees | Gathering firm reservation fees | | $ | 22,081 | | | $ | 106,127 | | | $ | 158,721 | | | $ | 158,628 | | | $ | 157,127 | | | $ | 1,433,923 | | | $ | 2,036,607 | | Gathering firm reservation fees | | $ | 22,204 | | | $ | 124,168 | | | $ | 158,652 | | | $ | 157,148 | | | $ | 149,626 | | | $ | 1,329,341 | | | $ | 1,941,139 | |
| Gathering revenues supported by MVCs | Gathering revenues supported by MVCs | | 125,591 | | | 526,413 | | | 585,384 | | | 617,532 | | | 635,649 | | | 5,367,726 | | | 7,858,295 | | Gathering revenues supported by MVCs | | 127,397 | | | 546,734 | | | 593,693 | | | 554,327 | | | 563,596 | | | 4,813,080 | | | 7,198,827 | |
| Transmission firm reservation fees | Transmission firm reservation fees | | 94,112 | | | 360,242 | | | 380,890 | | | 342,566 | | | 282,962 | | | 2,609,294 | | | 4,070,066 | | Transmission firm reservation fees | | 94,964 | | | 370,983 | | | 346,970 | | | 284,898 | | | 249,107 | | | 2,404,935 | | | 3,751,857 | |
| Water revenues supported by MVCs | Water revenues supported by MVCs | | 9,006 | | | 16,521 | | | 60,000 | | | 60,000 | | | 60,000 | | | 105,000 | | | 310,527 | | Water revenues supported by MVCs | | 500 | | | 31,250 | | | 37,500 | | | 37,500 | | | 37,500 | | | 231,250 | | | 375,500 | |
Total (b) | Total (b) | | $ | 250,790 | | | $ | 1,009,303 | | | $ | 1,184,995 | | | $ | 1,178,726 | | | $ | 1,135,738 | | | $ | 9,515,943 | | | $ | 14,275,495 | | Total (b) | | $ | 245,065 | | | $ | 1,073,135 | | | $ | 1,136,815 | | | $ | 1,033,873 | | | $ | 999,829 | | | $ | 8,778,606 | | | $ | 13,267,323 | |
(a) October 1, 20202021 through December 31, 2020.2021.
(b) Includes assumptions regarding timing for placing certain projects in-service, including the MVP in-service.in summer 2022. Delays in the in-service dates for projects may substantially alter the remaining performance obligations for certain contracts with firm reservation fees and/or MVCs. The MVP Joint Venture is accounted for as an equity investment and those amounts are not included in the 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, in each case, weighted average remaining terms of approximately 15 years and 14 years respectively, as of September 30, 2020.2021.
EQT Global GGA. On the EQT Global GGA Effective Date, the Company (through EQM) 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 itsthe 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 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 shouldwas 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 (or its affiliates) 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, if the MVP in-service date has not occurred bycommencing on January 1, 2022 EQT has an option, exercisable for a periodand continuing until the earlier of twelve months (or such shorter period if(i) the
in-service date of the MVP occurs),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 (through EQM) 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 and 2021 Water Services Agreement. On February 26, 2020, the Company (through EQM) entered into a letter agreement with EQT pursuantrelating 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). TheSubject to the effect of the 2021 Water Services Agreement (defined below), the Water Services Letter Agreement iswould have been effective as of the first day of the first month following the MVP in-service date and shall expirewould have expired on the fifth anniversary of such date. During each year of the Water Services Letter Agreement, EQT had agreed that fixed MVC fees payable to pay the Company a minimum $60 million per year Annual Revenue Commitment (ARC) for volumetric water services incurred on a volumetric basis, provided in Pennsylvania, all in accordance with existing water service agreements and new water service agreements entered into between the parties pursuant to the Water Services Letter Agreement (or the related agreements), shall be.
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 (2021 Water Services Agreement). The 2021 Water Services Agreement, which replaces the Water Services Letter Agreement and certain other existing Pennsylvania water services agreements, will become effective with the earlier of the commencement of water delivery service to a certain EQT well pad (anticipated in late February 2022) or April 1, 2022. Pursuant to the 2021 Water Services Agreement, EQT has agreed to pay the Company a minimum ARC for water services equal to or greater than $60$40 million in each of the first five years of the 10-year contract term and equal to $35 million per year.year for the remaining five years of the contract term.
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(as defined in Note 9)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.
7.6. Related Party Transactions
Related Party Transactions with EQT
As of September 30, 2020,2021, EQT remained a related party of the Company due to its ownership of 25,296,026 shares of Equitrans Midstream common stock, which represented an approximately 5.9%5.8% 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.
Operating revenues includedThe following table summarizes the Company's related party revenues from EQT of approximately $222.7 million and $275.4 million fortransactions.
| | | | | | | | | | | | | | | | | | | | | | | |
| Three Months Ended September 30, | | Nine Months Ended September 30, |
| 2021 | | 2020 | | 2021 | | 2020 |
| (Thousands) |
| Operating revenues | $ | 220,781 | | | $ | 222,700 | | | $ | 668,837 | | | $ | 741,200 | |
| Equity income | 8,461 | | | 60,917 | | | 14,385 | | | 171,233 | |
| Interest income from the preferred interest in EQT Energy Supply, LLC (the Preferred Interest) | 1,433 | | | 1,504 | | | 4,353 | | | 4,566 | |
| Capital contributions to the MVP Joint Venture | (94,298) | | | (65,630) | | | (178,953) | | | (144,264) | |
| Principal payments received on the Preferred Interest | 1,313 | | | 1,259 | | | 3,885 | | | 3,726 | |
| | | | | | | |
The following table summarizes the three months ended September 30, 2020 and 2019, respectively, and $741.2 million and $843.9 million for the nine months ended September 30, 2020 and 2019, respectively. Operating and maintenance expense included charges to EQT of approximately $2.4 million for both the three and nine months ended September 30, 2019. Selling, general and administrative expense included charges from EQT of approximately $1.0 million for both the three and nine months ended September 30, 2019. Additionally, net interest expense included interest income on the Preferred Interest in EES of approximately $1.5 million and $1.6 million for the three months ended September 30, 2020 and 2019, respectively, and $4.6 million and $4.8 million for the nine months ended September 30, 2020 and 2019, respectively.
Accounts receivable as of September 30, 2020 and December 31, 2019 included approximately $194.3 million and $175.2 million, respectively, ofCompany's related party accounts receivable from EQT. Other current assets as of September 30, 2020 included approximately $11.4 million of MVC unbilled revenue from EQT. In addition, as of September 30, 2020, the Preferred Interest in EES was approximately $106.3 million, of which $5.2 million was recorded in other current assetsreceivables and $101.1 million was recorded in other assets on the Company's consolidated balance sheets. As of December 31, 2019, the Preferred Interest in EES was approximately $110.1 million, of which $5.0 million was recorded in other current assets and $105.1 million was recorded in other assets on the Company's consolidated balance sheets.payables.
| | | | | | | | | | | |
| September 30, 2021 | | December 31, 2020 |
| (Thousands) |
| Accounts receivable | $ | 184,946 | | | $ | 199,674 | |
| Contract asset | 1,500 | | | 2,207 | |
| Investment in unconsolidated entity | 3,089,091 | | | 2,796,316 | |
| Preferred Interest | 101,170 | | | 105,056 | |
| Capital contributions payable to the MVP Joint Venture | 108,231 | | | 10,723 | |
Tax Matters Agreement.
On November 12, 2018, in connection with the Separation and Distribution, the Company and EQT entered into a tax matters agreement that governs the parties' respective rights, responsibilities and obligations with respect to taxes (including taxes arising in the ordinary course of business and taxes, if any, incurred as a result of any failure of the Distribution and certain related transactions to qualify as generally tax-free for U.S. federal income tax purposes), tax attributes, the preparation and filing of tax returns, the control of audits and other tax proceedings and assistance and cooperation with respect to tax matters (the Tax Matters Agreement). In addition, the Tax Matters Agreement imposes certain restrictions on the Company and its subsidiaries, including restrictions on certain equity issuances, business combinations, sales of assets and similar transactions, that are designed to preserve the tax-free status of the Distribution and certain related transactions.
The Tax Matters Agreement provides special rules that allocate tax liabilities in the event that the Distribution, together with certain related transactions, is not tax-free. In general, under the Tax Matters Agreement, each party is expected to be responsible for any taxes, whether imposed on the Company or EQT, that arise (i) from the failure of the Distribution, together with certain related transactions, to qualify for tax-free treatment, or (ii) if certain related transactions were to fail to qualify for their intended tax treatment, in each case, to the extent that the failure to qualify is attributable to actions, events or transactions relating to such party's respective stock, assets or business or a breach of the relevant representations or covenants made by that party in the Tax Matters Agreement.
Credit Letter Agreement. On February 26, 2020, in connection with the execution of the EQT Global GGA, the Company (through EQM) 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 the Company,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. See Notes 4 and 6Note 5 for further detail.
Water Services Letter Agreement and 2021 Water Services Agreement. See Note 65 for further detail.
Share Purchase Agreements. See Note 65 for further detail.
8. Investments7. Investment in Unconsolidated Entity
The MVP Joint Venture is constructing the MVP,Mountain Valley Pipeline (MVP), an estimated 300-mile natural gas interstate pipeline that will span from northern West Virginia to southern Virginia. The Company will operate the MVP and owned a 45.9%46.6% interest in the MVP project as of September 30, 2020.2021. On November 4, 2019, ConConsolidated 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 midpointproject's targeted cost of the project's $5.8 billion to $6.0approximately $6.2 billion (excluding AFUDC) targeted cost,, the Company's equity ownership in the MVP project will progressively increase from approximately 45.9%46.6% to approximately 47.6%47.8%. 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, a proposed 75-mile interstate pipeline that will extend from the MVP at Pittsylvania County, Virginia to new delivery points in Rockingham and Alamance Counties, North Carolina. The Company will operate the MVP Southgate pipeline and owned a 47.2% interest in the MVP Southgate project as of September 30, 2020.2021.
In September 2020,August 2021, 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 $126.6$108.1 million, of which $14.4$35.4 million and $112.2$40.0 million was paid in October 20202021 and November 2020, respectively. In September 2020, the MVP Joint Venture issued a capital call notice for the funding of the MVP Southgate project to MVP Holdco for $0.72021, respectively, and $32.7 million which was paid in October 2020. In addition, in October 2020, the MVP Joint Venture issued a capital call notice for the funding of the MVP Southgate project to MVP Holdco for $0.3 million, which is expected to be paid in November 2020.December 2021. The capital contributions payable and the corresponding increase to the investment balance are reflected on the consolidated balance sheet as of September 30, 2020.
The Company's interests in the MVP and MVP Southgate projects are equity method investments for accounting purposes because the Company has the ability to exercise significant influence, but not control, over the MVP Joint Venture's operating and financial policies. Accordingly, the Company records adjustments to the investment balance for contributions to or distributions from the MVP Joint Venture and for the Company's pro-rata share of MVP Joint Venture earnings.
Equity income, which is primarily related to the Company's pro-rata share of the MVP Joint Venture's AFUDC on the construction of the MVP, is reported in equity income in the Company's statements of consolidated comprehensive income.2021.
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 2019, EQM issued performance guarantees in an amount equal to 33% of MVP Holdco's proportionate share of the then-remaining construction budget for the MVP project. As of December 31, 2019, EQM's performance guarantee was approximately $223 million, adjusted for capital contributions made by EQM during the fourth quarter of 2019.
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. In 2019, EQM issued a performance guarantee of $14 million in favor of the MVP Joint Venture for the MVP Southgate project.
As a result of EQM’s credit rating downgrades in the first quarter of 2020, EQM delivered replacement credit support to the MVP Joint Venture in the form of letters of credit in the amounts of approximately $220.2 million and $14.2 million with respect to the MVP project and MVP Southgate project,projects, 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 September 30, 2020,November 2, 2021, the letters of credit with respect to the MVP project and MVP Southgate project were in the amounts of approximately $220.2 million and $14.2 million, respectively. As of November 3, 2020, based on the midpoint of the targeted project cost, MVP Holdco's obligation to deliver a replacement letter of credit with respect to the MVP project was in the amount of approximately $231.2 million.$219.7 million as a result of the capital contribution made in October 2021. Upon the FERC’s initial release to begin construction of the MVP Southgate project, the Company’s 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 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 September 30, 2020,2021, the Company's maximum financial statement exposure related to the MVP Joint Venture was approximately $2,829$3,246 million, which consisted primarily of the investment in unconsolidated entity balance on the consolidated balance sheet as of September 30, 2020, net of capital contributions payable,2021 and the letters of credit outstanding under the Amended EQM Credit Facility. As of November 3, 2020, 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 $2,967 million.
The following tables summarize the unaudited condensed consolidated financial statements of the MVP Joint Venture in relation to the MVP project.
Condensed Consolidated Balance Sheets
| | | September 30, 2020 | | December 31, 2019 | | September 30, 2021 | | December 31, 2020 |
| | (Thousands) | | (Thousands) |
| Current assets | Current assets | $ | 290,541 | | | $ | 102,638 | | Current assets | $ | 153,301 | | | $ | 146,054 | |
| Non-current assets | Non-current assets | 5,540,846 | | | 4,951,521 | | Non-current assets | 6,282,972 | | | 5,848,298 | |
| Total assets | Total assets | $ | 5,831,387 | | | $ | 5,054,159 | | Total assets | $ | 6,436,273 | | | $ | 5,994,352 | |
| | Current liabilities | Current liabilities | $ | 187,826 | | | $ | 223,645 | | Current liabilities | $ | 200,454 | | | $ | 217,086 | |
| | Equity | Equity | 5,643,561 | | | 4,830,514 | | Equity | 6,235,819 | | | 5,777,266 | |
| Total liabilities and equity | Total liabilities and equity | $ | 5,831,387 | | | $ | 5,054,159 | | Total liabilities and equity | $ | 6,436,273 | | | $ | 5,994,352 | |
Condensed Statements of Consolidated Operations
| | | | | | | | | | | | | | | | | | | | | | | |
| | Three Months Ended September 30, | | Nine Months Ended September 30, |
| | 2020 | | 2019 | | 2020 | | 2019 |
| (Thousands) |
| Environmental remediation reserve | $ | 20 | | | $ | (516) | | | $ | (295) | | | $ | (2,682) | |
| Other income | 13 | | | 1,165 | | | 275 | | | 5,863 | |
| Net interest income | 39,280 | | | 29,100 | | | 110,868 | | | 73,035 | |
| AFUDC — equity | 91,653 | | | 67,902 | | | 258,693 | | | 170,416 | |
| Net income | $ | 130,966 | | | $ | 97,651 | | | $ | 369,541 | | | $ | 246,632 | |
| | | | | | | | | | | | | | | | | | | | | | | |
| | Three Months Ended September 30, | | Nine Months Ended September 30, |
| | 2021 | | 2020 | | 2021 | | 2020 |
| (Thousands) |
| Operating expenses | $ | (201) | | | $ | 20 | | | $ | (351) | | | $ | (295) | |
| Other income | 5 | | | 13 | | | 15 | | | 275 | |
| Net interest income | 5,512 | | | 39,280 | | | 9,387 | | | 110,868 | |
| AFUDC — equity | 12,862 | | | 91,653 | | | 21,904 | | | 258,693 | |
| Net income | $ | 18,178 | | | $ | 130,966 | | | $ | 30,955 | | | $ | 369,541 | |
9.8. 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). The Company received net proceeds from the ETRN Term Loans of $568.1 million, inclusive of a discount of $18.0 million and estimated debt issuance costs of $13.9 million. The net proceeds were primarily used to fund the purchase of the public EQGP Common Units (the EQGP Buyout), including certain fees, costs and expenses in connection therewith, and the remainder was used for general corporate purposes. On March 3, 2020, EQM drew $650.0 million under the Amended 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 early 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. As of December 31, 2019, the current portion of the ETRN Term Loans was $6.0 million and was recorded in the current portion of long-term debt on the consolidated balance sheet. The Company had $594.0 million of borrowings outstanding and 0 letters of credit outstanding under the ETRN Term Loan Credit Agreement as of December 31, 2019. During the period from January 1, 2020 to March 3, 2020, the weighted average annual interest rate on the ETRN Term Loans was approximately 6.2%. For the three and nine months ended September 30, 2019, the weighted average annual interest rates were approximately 6.8% and 6.9%, respectively.
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 early 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 as of December 31, 2019 and during the period from January 1, 2020 to March 3, 2020. There were no borrowings on the Equitrans Midstream Credit Facility during the three months ended September 30, 2019. For the nine months ended September 30, 2019, the maximum outstanding borrowings was approximately $44 million, the average daily balance was approximately $4 million and the weighted average annual interest rate was approximately 4.3%. Commitment fees paid to maintain credit availability under the credit facility were approximately $0.1 million for the period from January 1, 2020 to March 3, 2020, and approximately $0.1 million and $0.3 million for the three and nine months ended September 30, 2019, respectively.
Amended EQM Revolving Credit Facility and Amended 2019 EQM Term Loan Agreement.Facility. On October 31, 2018, EQM amended and restated its unsecured revolving credit facility to increase the borrowing capacity from $1 billion to $3 billion and extend the term to October 2023 (the EQM Credit Facility). 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.
Additionally, onOn March 30, 2020, EQM entered into (i) an amendment (the First Amendment) to the EQM Credit Facility (as amended, the First Amended EQM Credit Facility) and (ii) 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 EQM Credit Facility. On April 16, 2021, EQM entered into a second amendment (the Second Amendment) to the EQM Credit Facility (as amended by the First Amendment and the 2019Second Amendment, the Amended EQM Term Loan Agreement.Credit Facility), which amended, among other things, certain defined terms, and specified that the maximum Consolidated Leverage Ratio (as defined in the Amended EQM Credit Facility) vary over the course of the remaining term, ranging from not more than 5.95 to 1.00 to not more than 5.00 to 1.00, with the then-applicable ratio being tested as of the end of each fiscal quarter. The Second Amendment also reduced the aggregate commitments available under the Amended EQM Credit Facility to $2.25 billion.
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 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 subject to the satisfaction of certain conditions. As of September 30, 2020, 0 term loans were outstanding under the Amended EQM Credit Facility. Suchconditions (which term loans would be secured by cash, qualifying investment grade securities or a combination thereof.
Under the termsthereof). The Company’s obligations in respect of the Amended EQM Credit Facility, EQM can obtain committed loans as Base Rate Loans (as defined in the Amended EQM Credit Facility) or Eurodollar Rate Loans (as defined in the Amended EQM Credit Facility). Base Rate Loans are denominated in dollars and bear interest at a base rate plus a margin of 0.125% to 1.750% determined on the basis of a combination of EQM’s then-current debt issuer credit ratings by Moody’s, S&P and Fitch. Eurodollar Rate Loans bear interest at a Eurodollar Rate (as defined in the Amended EQM Credit Facility) plus a margin of 1.125% to 2.750% determined on the basis of a combination of EQM’s then-current debt issuer credit ratings with Moody’s, S&P and Fitch. EQM may voluntarily prepay itsrevolving borrowings made under the Amended EQM Credit Facility in whole or in part, without premium or penalty, but subject to reimbursementare unsecured. As of funding losses with respect to certain prepayments of Eurodollar Rate Loans. Revolving amounts prepaidSeptember 30, 2021, no term loans were outstanding under the Amended EQM Credit Facility may be re-borrowed.Facility.
As of September 30, 2020,2021, EQM had approximately $485$350 million of borrowings and $235$266 million of letters of credit outstanding under the Amended EQM Credit Facility. As of December 31, 2019,2020, EQM had approximately $610$485 million of borrowings and $1$246 million of letters of credit outstanding under the First Amended EQM Credit Facility. During the three and nine months ended September 30, 2021, the maximum outstanding borrowings at any time were approximately $390 million and $525 million, respectively, and the average daily balances were approximately $358 million and $440 million, respectively. EQM incurred interest at weighted average annual interest rates of approximately 2.7% and 2.6% for the three and nine months ended September 30, 2021, respectively. During the three and nine months ended September 30, 2020, the maximum outstanding borrowings at any time were approximately $485 million and $2,040 million, respectively, and the average daily balances were approximately $485 million and $975 million, respectively. EQM incurred interest at weighted average annual interest rates of approximately 2.6% and 2.9% for the three and nine months ended September 30, 2020, respectively. During the three and nine months ended September 30, 2019, the maximum outstanding borrowings at any time was approximately $1,690 million for both periods, the average daily balances were approximately $865 million and $950 million, respectively, and the weighted average annual interest rates were approximately 3.7%2.6% and 3.8%2.9%, respectively. For the three and nine months ended September 30, 2021, commitment fees of $1.7 million and $5.6 million, respectively, were paid to maintain credit availability under the Amended EQM Credit Facility. For the three and nine months ended September 30, 2020, commitment fees of $2.4 million and $5.0 million, respectively, were paid to maintain credit availability under the Amended EQM Credit Facility. For the three and nine months ended September 30, 2019, commitment fees of $1.2 million and $3.3 million, respectively, were paid to maintain credit availability under theFirst Amended EQM Credit Facility.
Amended 2019 EQM Term Loans matureLoan 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 August 2022.an aggregate principal amount of $1.4 billion. On March 30, 2020, EQM received netentered 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 EQM Term Loans of $1,397.4 million, inclusive of debt issuance costs of $2.6 million. The net proceeds were primarily used2021 Senior Notes (as defined below) to repay borrowings under the Amended EQM Credit Facilityprepay all principal, interest, fees and the remainder was used for general partnership purposes. The Amended 2019 EQM Term Loan Agreement provides EQM with the right to request incremental term loans in an aggregate amount of up to $300 million, subject to, among other things, obtaining additional commitments from existing lenders or commitments from new lenders. As of September 30, 2020 and December 31, 2019, EQM had $1.4 billion of borrowingsobligations outstanding under the Amended 2019 EQM Term Loan Agreement for both periods.and (ii) terminated the Amended 2019 EQM Term Loan Agreement and the loan documents associated therewith. EQM repaid outstanding 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, the weighted average annual interest rate was approximately 2.4%. During the three and nine months ended September 30, 2020, the weighted average annual interest rates for the periods were approximately 2.4% and 2.8%, respectively. During the applicable
portion of the two months ended September 30, 2019, the weighted average annual interest rate for the period was approximately 3.6%.
Under the terms of the Amended 2019 EQM Term Loan Agreement, EQM can obtain Base Rate Loans (as defined in the Amended 2019 EQM Term Loan Agreement) or Eurodollar Rate Loans (as defined in the Amended 2019 EQM Term Loan Agreement). Base Rate Loans are denominated in dollars and bear interest at a base rate plus a margin of 0.000% to 1.625% determined on the basis of a combination of EQM’s then-current debt issuer credit ratings with Moody’s, S&P and Fitch. Eurodollar Rate Loans bear interest at a Eurodollar Rate (as defined in the Amended 2019 EQM Term Loan Agreement) plus a margin of 1.000% to 2.625% determined on the basis of a combination of EQM’s then-current debt issuer credit ratings with Moody’s, S&P and Fitch. EQM may voluntarily prepay its borrowings under the Amended 2019 EQM Term Loan Agreement, in whole or in part, without premium or penalty, but subject to reimbursement of funding losses with respect to certain prepayments of Eurodollar Rate Loans. Amounts prepaid under the Amended 2019 EQM Term Loan Agreement may not be reborrowed.
The Amended EQM Credit Facility and the Amended 2019 EQM Term Loan Agreement each contain certain negative covenants, that, among other things, limit the ability of EQM and certain of its subsidiaries to incur or permit liens on assets, establish a maximum consolidated leverage ratio that varies over the course of the term ranging from not more than 5.75 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), limit transactions with affiliates, mergers and other fundamental changes, asset dispositions, the incurrence of new debt and entry into burdensome agreements, in each case and as applicable, subject to certain specified exceptions. The Amended EQM Credit Facility and the Amended 2019 EQM Term Loan Agreement each also contains certain specified events of default, including, among others, failure to make certain payments (subject to specified grace periods in some cases), failure to observe covenants (subject to specified grace periods in some cases), cross-defaults to certain other material debt, certain specified insolvency or bankruptcy events and the occurrence of a change of control event, in each case, the occurrence of which would allow the lenders to accelerate EQM’s payment obligations under the Amended EQM Credit Facility or the Amended 2019 EQM Term Loan Agreement, as applicable.
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 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). No early termination or prepayment penalties were incurred as a result of the termination of the Former Eureka Credit Facility or the repayment of outstanding amounts under the facility. In connection with the termination of the Former Eureka Credit Facility, all guaranties and liens securing the obligations under the Former Eureka Credit Facility were terminated and released. Prior to its termination, the Former Eureka Credit Facility was scheduled to mature on August 25, 2021.
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 thatwith Sumitomo Mitsui Banking Corporation, as administrative agent, the lenders party thereto from time to time and any other persons party thereto from time to time (the 2021 Eureka Credit Facility). The 2021 Eureka Credit Facility matures on November 13, 2024, and is available for general business purposes, including financing maintenance and expansion capital expenditures related to the Eureka system and providing working capital for Eureka’s operations (as amended,operations. During the Eureka Credit Facility). Theterm of the 2021 Eureka Credit Facility, matures on August 25, 2021.Eureka is required to maintain (i) a Consolidated Leverage Ratio (as defined in the 2021 Eureka Credit Facility) of not more than 4.75 to 1.00, and (ii) a ratio of Consolidated EBITDA (as defined in the 2021 Eureka Credit Facility) for the four fiscal quarters then ending to Consolidated Interest Charges (as defined in the 2021 Eureka Credit Facility) of not less than 2.50 to 1.00, each tested as of the end of each fiscal quarter. Subject to the satisfaction of certain conditions, the 2021 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.million of total commitments. The 2021 Eureka Credit Facility also has a sublimit of up to $25 million for same-day swing line advances.
As of September 30, 2020 and2021, Eureka had approximately $295 million of borrowings outstanding under the 2021 Eureka Credit Facility. As of December 31, 2019,2020, Eureka had approximately $303 million and $293 million, respectively, of borrowings outstanding under the Former Eureka Credit Facility. For the three and nine months ended September 30, 2021, the maximum amount of outstanding borrowings under either of the Eureka credit facilities at any time was approximately $300 million and $315 million, respectively, the average daily balances were approximately $299 million and $305 million, respectively, and Eureka incurred interest at weighted average annual interest rates of approximately 2.8% and 2.5%, respectively. For the three and nine months ended September 30, 2021, commitment fees of $0.1 million and $0.3 million, respectively, were paid to maintain credit availability under the Eureka credit facilities. For the three and nine months ended September 30, 2020, the maximum amount of outstanding borrowings under the Former Eureka Credit Facility at any time was approximately $323 million for both periods, the average daily balances were approximately $310 million and $300 million, respectively, and Eureka incurred interest at weighted average annual interest rates of approximately 2.4% and 2.6%, respectively. For the three months ended September 30, 2019 and for the period from April 10, 2019 through September 30, 2019, the maximum amount of outstanding borrowings under the Eureka Credit Facility at any time was approximately $293 million for both periods, the average daily balances were approximately $293 million and $285 million, respectively, and Eureka incurred interest at a weighted average annual interest rate of approximately 4.3% for both periods. For the three and nine months ended September 30, 2020, commitment fees of $0.1 million and $0.4 million, respectively, were paid to maintain credit availability under the Former Eureka Credit Facility. For
2021 Senior Notes. During the three months ended September 30,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 the period from April 10, 2019 through September 30, 2019, commitment feesgeneral partnership purposes.
2020 Senior Notes. During the second quarter of 2020, EQM issued $700 million aggregate principal amount of new 6.000%6.00% senior unsecured notes due July 1, 2025 and $900 million aggregate principal amount of new 6.500%6.50% senior unsecured notes due July 1, 2027 (collectively, the 2020 Senior Notes) and received net proceeds from the offering of approximately $1,576.1 million, inclusive of a discount of $20.0 million and debt issuance costs of $3.9 million. TheA portion of the net proceeds were used to repay a portion of the borrowings outstanding under the First Amended EQM Credit Facility, and the remainder was used for general partnership purposes.purposes
The 2020 Senior Notes were issued under and are governed by an indenture, dated June 18, 2020 (the 2020 Indenture), between EQM and the Bank of New York Mellon Trust Company, N.A., as trustee. The 2020 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. Upon the occurrence of a Change of Control Triggering Event (as defined in the 2020 Indenture), EQM may be required
to offer to purchase On January 15, 2021 (the early tender deadline), the 2020 Seniormaximum principal amount for the Tender Offers was fully subscribed by the 2023 Notes at a purchase price equal to 101%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 2020 Seniorapplicable early tender premium for the 2023 Notes repurchased,described in that certain Offer to Purchase of EQM dated January 4, 2021, as amended, plus accrued and unpaid interest, if any, to, but excluding, the repurchase date.interest).
The 2020 Senior Notes are unsecured and rank equally with allCompany incurred a loss on the extinguishment of EQM’s existing and future senior obligations. The 2020 Senior Notes are senior in rightdebt of payment to any of EQM’s future obligations that are, by their terms, expressly subordinated in right of payment$41.0 million during the nine months ended September 30, 2021 related to the 2020 Senior Notes. The 2020 Senior Notes are effectively subordinated to EQM’s secured obligations, if any,payment of the Tender Offer premium and write off of unamortized discounts and financing costs related to the extentprepayment of the valueEQM Term Loans under, and termination of, the collateral securing such obligations,Amended 2019 EQM Term Loan Agreement and structurally subordinated to all indebtedness and obligations, including trade payables,purchase of EQM’s subsidiaries, other than any subsidiaries that may guarantee the 2020 Senior2023 Notes in the future.Tender Offers. This amount is included in the loss on extinguishment of debt line on the statements of consolidated comprehensive income.
As of September 30, 2020,2021, EQM and Eureka were in compliance with all debt provisions and covenants.
10.9. 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 Henry Hub cash bonus payment provision, as described in Note 6,5, is 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 of the MVP, risk-free 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 38% was utilized in the valuation model, which is based on market-quoted volatilities of relevant NYMEX Henry Hub natural gas forward prices. As of September 30, 2021 and December 31, 2020, the fair valuevalues of the Henry Hub cash bonus payment provision was $89.2were $105.9 million ofand $68.0 million, respectively, which $35.3 million was recorded in other current assets and $53.9 million waswere recorded in other assets on the Company's consolidated balance sheets. During the three and nine months ended September 30, 2021, the Company recognized gains of $21.3 million and $37.9 million, respectively, representing the change in estimated fair value of the derivative instrument during the respective periods. During the three and nine months ended September 30, 2020, the Company recognized gains of $21.0 million and $37.7 million, respectively, representing the change in estimated fair value of the derivative instrument during the applicable period.respective periods. The gain isgains are reflected in other income 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 (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. Effective on March 3, 2020, the ETRN Term Loans were paid off with proceeds from the Amended EQM Credit Facility (see Note 9), and the ETRN Term Loan Credit Agreement was terminated. As of December 31, 2019, the estimated fair value of the ETRN Term Loans was approximately $595 million and the carrying value of the ETRN Term Loans was approximately $568 million. As of September 30, 20202021 and December 31, 2019,2020, the estimated fair values of EQM's senior notes were approximately $5,139$7,030 million and $3,421$5,495 million, respectively, and the carrying values of EQM's senior notes were approximately $5,043$6,432 million and $3,462$5,046 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 September 30, 20202021 and December 31, 2019,2020, the estimated fair values of the Preferred Interest were approximately $127$119 million and $126$127 million, respectively, and the carrying values of the Preferred Interest were approximately $106$101 million and $110$105 million, respectively.
11.
10. Earnings (Loss) Per Share
The following tables settable sets forth the computation of the basic and diluted earnings (loss) per share attributable to Equitrans Midstream common shareholders for the three and nine months ended September 30, 20202021 and 2019:2020:
| | | | | | | | | | | | | | | | | | | | | | | |
| Three Months Ended September 30, |
| 2020 | | 2019 |
| Basic | | Diluted | | Basic | | Diluted |
| (In thousands, except per share data) |
| Net income (loss) | $ | 168,439 | | | $ | 168,439 | | | $ | (61,489) | | | $ | (61,489) | |
| Less: Net income (loss) attributable to noncontrolling interests (excluding EQM Series A Preferred Units) | 3,973 | | | 3,973 | | | (44,144) | | | (44,144) | |
| Less: EQM Series A Preferred Units interest in net income | 0 | | | 0 | | | 48,480 | | | 48,480 | |
| Less: Preferred dividends | 14,628 | | | 14,628 | | | 0 | | | 0 | |
| | | | | | | |
| Net income (loss) attributable to Equitrans Midstream common shareholders | $ | 149,838 | | | $ | 149,838 | | | $ | (65,825) | | | $ | (65,825) | |
| | | | | | | |
| Basic weighted average common shares outstanding | 432,773 | | | 432,773 | | | 254,915 | | | 254,915 | |
Dilutive securities (a)(b) | — | | | 48 | | | — | | | 0 | |
| Diluted weighted average common shares outstanding | 432,773 | | | 432,821 | | | 254,915 | | | 254,915 | |
| | | | | | | |
| Earnings (loss) per share of common stock attributable to Equitrans Midstream common shareholders | $ | 0.35 | | | $ | 0.35 | | | $ | (0.26) | | | $ | (0.26) | |
| | | | Three Months Ended September 30, |
| | | 2021 | | 2020 |
| | | Basic | | Diluted | | Basic | | Diluted |
| | | (In thousands, except per share data) |
| Net income | | Net income | $ | 90,905 | | | $ | 90,905 | | | $ | 168,439 | | | $ | 168,439 | |
| Less: Net income attributable to noncontrolling interests | | Less: Net income attributable to noncontrolling interests | 3,557 | | | 3,557 | | | 3,973 | | | 3,973 | |
| | Less: Preferred dividends | | Less: Preferred dividends | 14,628 | | | 14,628 | | | 14,628 | | | 14,628 | |
| | Net income attributable to Equitrans Midstream common shareholders | | Net income attributable to Equitrans Midstream common shareholders | $ | 72,720 | | | $ | 72,720 | | | $ | 149,838 | | | $ | 149,838 | |
| | Basic weighted average common shares outstanding | | Basic weighted average common shares outstanding | 433,017 | | | 433,017 | | | 432,773 | | | 432,773 | |
Dilutive securities (a) | | Dilutive securities (a) | — | | | 658 | | | — | | | 48 | |
| Diluted weighted average common shares outstanding | | Diluted weighted average common shares outstanding | 433,017 | | | 433,675 | | | 432,773 | | | 432,821 | |
| | Earnings per share of common stock attributable to Equitrans Midstream common shareholders | | Earnings per share of common stock attributable to Equitrans Midstream common shareholders | $ | 0.17 | | | $ | 0.17 | | | $ | 0.35 | | | $ | 0.35 | |
| | | Nine Months Ended September 30, | | Nine Months Ended September 30, |
| | 2020 | | 2019 | | 2021 | | 2020 |
| | Basic | | Diluted | | Basic | | Diluted | | Basic | | Diluted | | Basic | | Diluted |
| | (In thousands, except per share data) | | (In thousands, except per share data) |
| Net income | Net income | $ | 501,457 | | | $ | 501,457 | | | $ | 268,557 | | | $ | 268,557 | | Net income | $ | 207,623 | | | $ | 207,623 | | | $ | 501,457 | | | $ | 501,457 | |
| Less: Net income attributable to noncontrolling interests (excluding EQM Series A Preferred Units) | Less: Net income attributable to noncontrolling interests (excluding EQM Series A Preferred Units) | 163,406 | | | 163,406 | | | 155,082 | | | 155,082 | | Less: Net income attributable to noncontrolling interests (excluding EQM Series A Preferred Units) | 10,479 | | | 10,479 | | | 163,406 | | | 163,406 | |
| Less: EQM Series A Preferred Units interest in net income | Less: EQM Series A Preferred Units interest in net income | 47,359 | | | 47,359 | | | 48,480 | | | 48,480 | | Less: EQM Series A Preferred Units interest in net income | — | | | — | | | 47,359 | | | 47,359 | |
| | Less: Preferred dividends | Less: Preferred dividends | 44,132 | | | 44,132 | | | 0 | | | 0 | | Less: Preferred dividends | 43,884 | | | 43,884 | | | 44,132 | | | 44,132 | |
| | Net income attributable to Equitrans Midstream common shareholders | Net income attributable to Equitrans Midstream common shareholders | $ | 246,560 | | | $ | 246,560 | | | $ | 64,995 | | | $ | 64,995 | | Net income attributable to Equitrans Midstream common shareholders | $ | 153,260 | | | $ | 153,260 | | | $ | 246,560 | | | $ | 246,560 | |
| | Basic weighted average common shares outstanding | Basic weighted average common shares outstanding | 314,411 | | | 314,411 | | | 254,868 | | | 254,868 | | Basic weighted average common shares outstanding | 433,001 | | | 433,001 | | | 314,411 | | | 314,411 | |
Dilutive securities (a)(b) | — | | | 0 | | | — | | | 19 | | |
Dilutive securities (a) | | Dilutive securities (a) | — | | | 411 | | | — | | | — | |
| Diluted weighted average common shares outstanding | Diluted weighted average common shares outstanding | 314,411 | | | 314,411 | | | 254,868 | | | 254,887 | | Diluted weighted average common shares outstanding | 433,001 | | | 433,412 | | | 314,411 | | | 314,411 | |
| | Earnings per share of common stock attributable to Equitrans Midstream common shareholders | Earnings per share of common stock attributable to Equitrans Midstream common shareholders | $ | 0.78 | | | $ | 0.78 | | | $ | 0.26 | | | $ | 0.25 | | Earnings per share of common stock attributable to Equitrans Midstream common shareholders | $ | 0.35 | | | $ | 0.35 | | | $ | 0.78 | | | $ | 0.78 | |
(a)For the periods presented, as applicable, EQM's dilutivethree and nine months ended September 30, 2021, the Company excluded 30,018 (in thousands), in each case, of weighted average anti-dilutive securities issued and outstanding priorrelated to the EQM Merger did not have a material impact on the Company's diluted earnings per share.
(b)Equitrans Midstream Preferred Shares. For the three and nine months ended September 30, 2020, the Company excluded 30,099 and 11,995 (in thousands), respectively, of weighted average anti-dilutive securities related to the Equitrans Midstream Preferred Shares and stock-based compensation awards. For the threenine months ended September 30, 2019,2020, EQM's dilutive securities issued and outstanding prior to the EQM Merger did not have a material impact on the Company's diluted earnings per share.
The Company excluded 45grants 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, 498 and 495 (in thousands) Equitrans Midstream phantom units were included in the computation of basic and diluted weighted average anti-dilutive securities related to stock-based compensation awards.common shares outstanding for the three and nine months ended September 30, 2021, respectively, and 303 and 279 (in thousands) Equitrans Midstream phantom units were included in the computation of basic and diluted weighted average common shares outstanding for the three and nine months ended September 30, 2020.
Preferred dividends include a $27.3 million premium recognized on the redemption of the EQM Series A Preferred Units as part of the Restructuring Closing during the nine months ended September 30, 2020.
12.11. Income Taxes
The Company's effective tax rate was 26.2% for the three months ended September 30, 2021, compared to 14.4% for the three months ended September 30, 2020, compared to (3.3)% for the three months ended September 30, 2019.2020. The Company's effective tax rate was 23.9% for the nine months ended September 30, 2021, compared to 14.0% for the nine months ended September 30, 2020, compared to 14.6% for2020. For the nine months ended September 30, 2019.2021 and 2020, 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 higher for the three and nine months ended September 30, 2021 compared to the three and nine months ended September 30, 2020 compared to the three months ended September 30, 2019 primarily due to the tax impact of the impairments of long-lived assets (see Note 4) during the three months ended September 30, 2019 and, for the three months ended September 30, 2020, the decrease in net income attributable to noncontrolling interests as a result of the EQM Merger
and a decrease in AFUDC – equity and related effect on the Company's estimated annual effective tax rate partially offset by an increase in AFUDC - equity. Excluding other items,for the nine months ended September 30, 2021. The effective tax ratesrate for the three and nine months ended September 30, 2020 and 2019 werewas lower than the statutory ratesrate primarily because the Company doesdid not record income tax expense on the portion 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 did not record income tax expense on the portion of its income attributabledue to the noncontrolling limited partnersimpact of EQM and EQGP for the periods priorAFUDC - equity related to the closing of the EQM Merger and the EQGP Buyout, respectively.MVP project.
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.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 "Management'sPart 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 and its subsidiaries,affiliates, 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, 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 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 expansion projects);
•the cost, capacity, shippers for, timing of regulatory approvals (including permitting timelines with respect to the MVP project water crossings), final design and project scope (including expansions or scope extensions or refinements and capital related thereto), ability to contract additional capacity on, mitigate emissions from and targeted in-service dates of current or in-service projects or assets, in each case as applicable;
•the ultimate terms, partnerspartner 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 provision;provision of the EQT Global 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’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 (a Water Services Agreement) entered into pursuant to the termscost of the Water Services Letter Agreement;Company's development of a mixed-use water system;
•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;
•the impact of a dispute with EQT (or resolution thereof)the arbitration decision in favor of the Company regarding the Hammerhead gathering agreement and/orand 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;EQT and the ability to achieve, and time for achieving, Hammerhead pipeline in-service;
•the effect and outcome of future 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 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;
•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;
•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;
•dividend amounts, timing and rates;
•changes in commodity prices and the effect of commodity prices on the Company's business, including business;
•future decisions of customers in respect of curtailing (or subsequently bringing back online) 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 productionnatural gas and water volumes in the Company's areas of operations;
•the Company's ability to achieve the anticipated benefits associated with the execution of the EQT Global GGA, the 2021 Water Services Letter Agreement and related 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, commodity prices, access to capital and costs which may be incurred as a result of, and compliance with, any vaccine or testing mandate issued by the durationU.S. Department of Labor's Occupational Safety and Health Administration (OSHA) or any other government agency;
•the Company's ability to achieve its environmental, social and governance (ESG) and sustainability goals (including goals set forth in its climate policy);
•the effectiveness of the reduction or curtailment of production of associated gas from basins such as the Permian Basin, commodity pricesCompany's information technology systems and accesspractices to capital;defend against evolving cyber attacks on United States critical infrastructure;
•the effects of government regulation; 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 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, 2019,2020, as are updated by this Quarterly Report on Form 10-Q.
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.
Executive Overview
Net income attributable to Equitrans Midstream common shareholders was $72.7 million for the three months ended September 30, 2021 compared to $149.8 million for the three months ended September 30, 2020 compared with a net loss attributable to Equitrans Midstream common shareholders of $65.8 million for the three months ended September 30, 2019.2020. The increasedecrease resulted primarily from a decrease in impairment charges associated with long-lived assets, unrealized gains on derivative instruments associated with the Henry Hub cash bonus payment provision and higherlower equity income from the Company's investment in the MVP Joint Venture, lower operating revenues on Water and higher net interest expense, partially offset by higher operating revenues on Gathering.
Net income attributable to Equitrans Midstream common shareholders was $153.3 million for the nine months ended September 30, 2021 compared to $246.6 million for the nine months ended September 30, 2020. The decrease resulted primarily from lower volumetric-based feeequity income from the Company's investment in the MVP Joint Venture, lower operating revenues primarilyon Gathering (primarily due to the impacts of the EQT Global GGA, higher income tax expense,GGA) and Water, higher net interest expense, and preferred dividends associated withadditional loss on extinguishment of debt charges, partially offset by lower net income attributable to noncontrolling interest, transaction costs recorded during the Equitrans Midstream Preferred Shares.first nine months of 2020 and lower income tax expense. See Note 65 to the consolidated financial statements for a discussion of deferred revenues under the EQT Global GGA.
Net income attributable to Equitrans Midstream common shareholders was $246.6 million for the nine months ended September 30, 2020 compared with $65.0 million for the nine months ended September 30, 2019. The increase resulted primarily from a decrease in impairment charges associated with long-lived assets, higher equity income from the Company's investment in the MVP Joint Venture, increased revenue from firm reservation fees on Gathering and Water and unrealized gains on derivative instruments associated with the Henry Hub cash bonus payment provision, partially offset by lower volumetric-based fee revenues primarily due to the impacts of the EQT Global GGA, higher income tax expense, preferred dividends associated with the Equitrans Midstream Preferred Shares, higher net interest expense and a loss on early extinguishment of debt.
COVID-19 Update
The COVID-19 outbreak has resulted in a severe global economic downturn and a recession of unknown duration and has caused increased volatility in and intermittent disruptions to the global financial and credit markets. The outbreak has directly resulted in a significant decrease in demand for oil and natural gas liquids, at least in the short term, which caused extreme volatility in oil and other liquids prices and a significant negative impact to, at a minimum, the short- and medium-term outlook for oil prices. The downward pressure on oil prices was further exacerbated by the failure, in March 2020, of Saudi Arabia and Russia to agree to cut oil production, which contributed to a sharp drop in the price of oil (and at one point negative prices for oil) and an imbalance between the supply and demand for oil. The revised outlook for oil and other liquids prices caused a significant reduction in the number of operating drilling rigs in the United States, with a substantial portion of this reduction in rigs accounted for in shale plays targeted primarily at developing oil resources, including the Permian Basin. According to Baker Hughes, the average U.S. rig count fell to approximately 257 during September 2020, compared to an average rig count of approximately 791 during January 2020. This dramatic decrease in the number of operating drilling rigs has positively impacted the natural gas forward price strip based on the market expectation that the reduced or curtailed production of associated gas from basins such as the Permian Basin will at least in the near- and medium-term cause a reduction in the overall supply of natural gas which will more than offset reduced demand for natural gas as a result ofWhile the COVID-19 outbreak. See “Commodity Prices” under “Outlook” below for a further discussion of the current commodity price environment for the Company and its producer customers.
Future disruptions to the global financial and credit markets from the COVID-19 outbreak and related economic impacts could, both directly and indirectly, negatively impact the Company’s financial condition and results of operations. The Company closed EQM’s offering of the 2020 Senior Notes in June 2020, resulting in net proceeds of approximately $1.58 billion, which the Company primarily used to repay a portion of the outstanding borrowings under the Amended EQM Credit Facility; however, there can be no guarantee that future disruptions to the financial and credit markets as a result of the COVID-19 outbreak and related economic impacts would not affect the Company’s ability to again access such markets, if needed, on acceptable terms or at all. Further, certain of the Company’s producer customers have significant capital needs, primarily to refinance existing indebtedness that matures next year and during the next several years, and further disruptions or instability in financial and credit markets as a result of COVID-19 and the economic disruptions therefrom may have a significant, negative impact on such producers’ abilities to access the financial and credit markets and refinance existing indebtedness as it becomes due. If such producer customers have difficulty refinancing such indebtedness on acceptable terms or at all (or undertaking other transactions to generate cash for debt service), the Company’s exposure to risk of nonpayment and/or nonperformance by its customers would increase. Additionally, the ability of the Company’s producer customers to maintain or grow their production would likely be adversely affected as a result of such refinancing challenges, which would have a negative impact on demand for the Company’s current services as well as the prospect of future pipeline expansion projects that would enhance the Company’s business.
From an operational perspective, while the COVID-19 outbreak has significantly impacted the manner in which the Company’s employees and contractors perform their job functions,pandemic is continuing, 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 theThe Company continues to actively manage its response to the COVID-19 pandemic in collaboration with relevant parties and, given that the situation surrounding COVID-19 remains fluid, a number of Company-wide measures undertaken in response to COVID-19 remain in effect to continue to promote the safety and health of field and office-based employees and contractors. On September 9, 2021, President Biden announced that OSHA is developing a rule that will require all employers with 100 or more employees to ensure their workforce is fully vaccinated or require any workers who remain unvaccinated to produce a negative test result on at least a weekly basis before coming to work. As an employer with more than 100 employees, the Company will be required to comply with the rule. The Company is currently monitoring the rulemaking and evaluating the potential impact of this mandate on the Company, including its employees, contractors, customers and
suppliers. As a midstream energy company, during applicable state-issued stay-at-home orders,Notwithstanding the outbreak’s minimal direct impact to date on the Company’s overall operations, the Company was recognized as an essential business under various regulations related toacknowledges that the COVID-19 outbreakpandemic is still ongoing and continued to operate as permitted under these regulations. Thetherefore the Company has proactively undertaken a numbercannot predict that the pandemic, or further developments regarding variants of companywide measures intended to promoteCOVID-19 or the safety of field and non-field level employees and contractors (including, among other things, establishing an Infectious Disease Response Team, instituting enhanced self-protection and office sanitation measures, eliminating non-essential business travel, implementing a mandatory work-from-home protocol for a substantial majority of the Company’s employees through at least June 1, 2021, instituting face covering protocols, providing certain medical benefit enhancements, practicing social distancingabove-referenced rulemaking, will not have any impact in the field where possible, sharing the Company’s infectious disease response plan with suppliers and contractors, and timely communicating updates to employees and other relevant parties). In addition, the Company is focused on implementing additional mitigation efforts in connection with the remobilization of certain field level employees and contractors. The Company’s Infectious Disease Response Team continues to monitor and assist in implementing mitigation efforts in respect of potential areas of risk for the Company and its stakeholders. Additionally, the Company has implemented business continuity plans and provided support to local communities through corporate giving and the Equitrans Midstream Foundation. The Company has been able to maintain a consistent level of effectiveness through the measures taken. 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.
The Company is unable to predict, in light of the ongoing and dynamic nature of the circumstances related to COVID-19 and continued growth in COVID-19 infections in the United States (including in certain of the Company’s areas of operation) and globally, any additional impact the outbreak may havefuture 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, the duration of the outbreak, spikes in infection rates (including in the Company's areas of operation) and related economic effects and after effects (including on the natural gas industry), and actions taken to contain COVID-19 or its impact, among others.position. For further information regarding the potential impact of COVID-19 on the Company, see "The outbreak of COVID-19 (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 Part II, "Item 1A. Risk Factors", in this Quarterlythe Company's Annual Report on Form 10-Q.10-K for the year ended December 31, 2020.
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 separation and other transaction costs and other unallocated corporate expenses. Other income, netNet interest expense, components of other income and income tax expense are managed on a consolidated basis. The Company has presented each segment's operating income, (loss),other income, equity income and various operational measures 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 of its segments. The Company has reconciled each segment's operating income (loss) to the Company's consolidated operating income (loss) and net income (loss) in Note 54 to the consolidated financial statements.
Gathering Results of Operations
| | | | Three Months Ended September 30, | | Nine Months Ended September 30, | | Three Months Ended September 30, | | Nine Months Ended September 30, |
| | 2020 | | 2019 | | %
Change | | 2020 | | 2019 | | %
Change | | 2021 | | 2020 | | %
Change | | 2021 | | 2020 | | %
Change |
| | (Thousands, except per day amounts) | | (Thousands, except per day amounts) |
| FINANCIAL DATA | FINANCIAL DATA | | | FINANCIAL DATA | | |
Firm reservation fee revenues (a) | Firm reservation fee revenues (a) | $ | 145,533 | | | $ | 154,791 | | | (6.0) | | | $ | 446,721 | | | $ | 431,520 | | | 3.5 | | Firm reservation fee revenues (a) | $ | 151,004 | | | $ | 145,533 | | | 3.8 | | | $ | 448,556 | | | $ | 446,721 | | | 0.4 | |
| | Volumetric-based fee revenues | Volumetric-based fee revenues | 87,118 | | | 144,700 | | | (39.8) | | | 317,508 | | | 415,518 | | | (23.6) | | Volumetric-based fee revenues | 92,812 | | | 87,118 | | | 6.5 | | | 285,288 | | | 317,508 | | | (10.1) | |
| Total operating revenues | Total operating revenues | 232,651 | | | 299,491 | | | (22.3) | | | 764,229 | | | 847,038 | | | (9.8) | | Total operating revenues | 243,816 | | | 232,651 | | | 4.8 | | | 733,844 | | | 764,229 | | | (4.0) | |
| Operating expenses: | Operating expenses: | | Operating expenses: | |
| Operating and maintenance | Operating and maintenance | 20,683 | | | 27,127 | | | (23.8) | | | 62,306 | | | 67,860 | | | (8.2) | | Operating and maintenance | 25,758 | | | 20,683 | | | 24.5 | | | 72,698 | | | 62,306 | | | 16.7 | |
| Selling, general and administrative | Selling, general and administrative | 21,930 | | | 18,462 | | | 18.8 | | | 67,686 | | | 60,365 | | | 12.1 | | Selling, general and administrative | 21,831 | | | 21,930 | | | (0.5) | | | 72,324 | | | 67,686 | | | 6.9 | |
| Separation and other transaction costs | — | | | 256 | | | (100.0) | | | 4,104 | | | 19,127 | | | (78.5) | | |
| Transaction costs | | Transaction costs | — | | | — | | | — | | | — | | | 4,104 | | | (100.0) | |
| Depreciation | Depreciation | 44,648 | | | 38,943 | | | 14.6 | | | 126,915 | | | 104,502 | | | 21.4 | | Depreciation | 47,441 | | | 44,648 | | | 6.3 | | | 140,899 | | | 126,915 | | | 11.0 | |
| Amortization of intangible assets | Amortization of intangible assets | 16,204 | | | 14,540 | | | 11.4 | | | 46,990 | | | 38,677 | | | 21.5 | | Amortization of intangible assets | 16,204 | | | 16,204 | | | — | | | 48,614 | | | 46,990 | | | 3.5 | |
| Impairments of long-lived assets | Impairments of long-lived assets | — | | | 298,652 | | | (100.0) | | | 55,581 | | | 378,787 | | | (85.3) | | Impairments of long-lived assets | — | | | — | | | — | | | — | | | 55,581 | | | (100.0) | |
| Total operating expenses | Total operating expenses | 103,465 | | | 397,980 | | | (74.0) | | | 363,582 | | | 669,318 | | | (45.7) | | Total operating expenses | 111,234 | | | 103,465 | | | 7.5 | | | 334,535 | | | 363,582 | | | (8.0) | |
| Operating income (loss) | $ | 129,186 | | | $ | (98,489) | | | 231.2 | | | $ | 400,647 | | | $ | 177,720 | | | 125.4 | | |
| Operating income | | Operating income | $ | 132,582 | | | $ | 129,186 | | | 2.6 | | | $ | 399,309 | | | $ | 400,647 | | | (0.3) | |
| Other income (b) | | Other income (b) | $ | 21,328 | | | $ | 21,005 | | | 1.5 | | | $ | 37,897 | | | $ | 37,729 | | | 0.4 | |
| | OPERATIONAL DATA | OPERATIONAL DATA | | | | | | | OPERATIONAL DATA | | | | | | |
| Gathered volumes (BBtu per day) | Gathered volumes (BBtu per day) | | Gathered volumes (BBtu per day) | |
Firm capacity reservation (b) | 5,111 | | | 3,824 | | | 33.7 | | | 4,493 | | | 3,321 | | | 35.3 | | |
Firm capacity (c) | | Firm capacity (c) | 5,110 | | | 5,111 | | | — | | | 5,211 | | | 4,493 | | | 16.0 | |
| Volumetric-based services | Volumetric-based services | 3,080 | | | 4,406 | | | (30.1) | | | 3,565 | | | 4,317 | | | (17.4) | | Volumetric-based services | 2,880 | | | 3,080 | | | (6.5) | | | 3,109 | | | 3,565 | | | (12.8) | |
| Total gathered volumes | Total gathered volumes | 8,191 | | | 8,230 | | | (0.5) | | | 8,058 | | | 7,638 | | | 5.5 | | Total gathered volumes | 7,990 | | | 8,191 | | | (2.5) | | | 8,320 | | | 8,058 | | | 3.3 | |
| Capital expenditures (c) | $ | 90,452 | | | $ | 271,860 | | | (66.7) | | | $ | 303,063 | | | $ | 686,178 | | | (55.8) | | |
Capital expenditures (d) | | Capital expenditures (d) | $ | 62,916 | | | $ | 90,452 | | | (30.4) | | | $ | 170,709 | | | $ | 303,063 | | | (43.7) | |
(a)For the three and nine months ended September 30, 2021, firm reservation fee revenues included approximately $5.5 million and $12.4 million, respectively, of MVC unbilled revenues. For the three and nine months ended September 30, 2020,, firm reservation fee revenues included approximately $2.6 million and $13.7 million, respectively, of MVC unbilled revenues.
(b)Other income includes the unrealized gains on derivative instruments associated with the Henry Hub cash bonus payment provision. See Note 9 to the consolidated financial statements for further information.
(c)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.
(c)(d)Includes approximately $4.8 million and $10.6 million of capital expenditures related to the noncontrolling interest in Eureka Midstream for the three and nine months ended September 30, 2021, respectively, and includes approximately $13.5 million and $37.1 million of capital expenditures related to the noncontrolling interest in Eureka Midstream for the three and nine months ended September 30, 2020, respectively, and approximately $6.7 million and $17.6 million of capital expenditures related to the noncontrolling interest in Eureka Midstream for the three and nine months ended September 30, 2019, respectively.
Three Months Ended September 30, 20202021 Compared to Three Months Ended September 30, 20192020
Gathering operating revenues decreasedincreased by $66.8$11.2 million for the three months ended September 30, 20202021 compared to the three months ended September 30, 2019.2020. Firm reservation fee revenues decreasedincreased by $9.3$5.5 million primarily due to $74.6 million of deferred revenue under the EQT Global GGA, partly offset by $65.1 million of increased MVC revenues underprimarily attributable to contractual agreements commencing in late 2020. Volumetric-based fee revenues increased by $5.7 million primarily due to higher compression fees.
Gathering operating expenses increased by $7.8 million for the EQT Global GGAthree months ended September 30, 2021 compared to the three months ended September 30, 2020 due to higher operating and maintenance and depreciation expenses. Operating and maintenance expense increased firm capacity by other producers.$5.1 million primarily as a result of an increase in repairs and maintenance expense. Depreciation expense increased by $2.8 million as a result of additional assets placed in-service.
Nine Months Ended September 30, 2021 Compared to Nine Months Ended September 30, 2020
Gathering operating revenues decreased by $30.4 million for the nine months ended September 30, 2021 compared to the nine months ended September 30, 2020. Volumetric-based fee revenues decreased by $57.6$32.2 million primarily due to increased MVC revenues attributable to volumes that previously were subject to volumetric-based fees prior to the EQT Global GGA. The volumetric-based fee revenue decrease was slightly offset by an increase in firm reservation fee revenues of $1.8 million primarily due to increased MVC revenues, partially offset by increased deferred revenue resulting from the EQT Global GGA. See Note 65 to the consolidated financial statements for a discussion of deferred revenues under the EQT Global GGA.
OperatingGathering operating expenses decreased by $294.5$29.0 million for the threenine months ended September 30, 2021 compared to the nine months ended September 30, 2020 compared to the three months ended September 30, 2019 primarily as a result of aggregatethe impairments of long-lived assets associated with goodwill(which consisted of gathering assets and customer-related intangible assets of $298.7totaling $55.6 million, during the third quarter of 2019 (as discussedas described in Note 43 to the consolidated financial statements) and a $6.4 million decreasetransaction costs associated with the EQM Merger and related transactions during the first quarter of 2020, partially offset by increases in operating and maintenance, selling, general and administrative and depreciation expenses in the first nine months of 2021 compared to the first nine months of 2020. Operating and maintenance expense increased by $10.4 million primarily associated withas a decreaseresult of an increase in repairs and maintenance expense. The decrease in such operating expenses was partly offset by selling,Selling, general and administrative expense which increased by $3.5$4.6 million primarily due to higherlegal fees associated with the Hammerhead pipeline arbitration and personnel costs and a $5.7costs. Depreciation expense increased by $14.0 million increase in depreciation expense as a result of additional assets placed in-service.
Nine Months Ended September 30, 2020 Compared to Nine Months Ended September 30, 2019
Gathering revenues decreased by $82.8 million for the nine months ended September 30, 2020 compared to the nine months ended September 30, 2019. Firm reservation fee revenues increased by $15.2 million primarily due to $129.2 million of increased MVC revenues under the EQT Global GGASee "Outlook" and increased firm capacity primarily generated by the operating entities acquired in the Bolt-on Acquisition, partly offset by $148.8 million of deferred revenue under the EQT Global GGA. Volumetric-based fee revenues decreased by $98.0 million primarily due to increased MVC revenues attributable to volumes that previously were subject to volumetric-based fees prior to the EQT Global GGA.
Operating expenses decreased by $305.7 million for the nine months ended September 30, 2020 compared to the nine months ended September 30, 2019 primarily as a result of a $323.2 million decrease in impairment charges (as discussed in Note 4 to the consolidated financial statements), a $15.0 million decrease in separation and other transaction costs related to the Bolt-on Acquisition that was completed in April 2019 and a $5.6 million decrease in operating and maintenance expense primarily associated with a decrease in repairs and maintenance expense. The decrease in such operating expenses was partly offset by a $22.4 million increase in depreciation expense as a result of additional assets placed in-service, as well as depreciation on assets acquired in the Bolt-on Acquisition, and an $8.3 million increase in amortization of intangible assets as a result of intangible assets acquired in the Bolt-on Acquisition and a corresponding adjustment to the useful lives of these intangibles (as discussed in Note 3 to the consolidated financial statements). Selling, general and administrative expense increased by $7.3 million primarily due to higher personnel costs.
statements for further discussion of the impairments of long-lived assets. See also “Outlook” and Part I, "Item 3. Quantitative and Qualitative Disclosures About Market Risk" of this Quarterly Report on Form 10-Q for discussions of certain customer production curtailments during the second and third quarters of 2020 and Note 65 to the consolidated financial statements for discussions of the EQT Global GGA and the transactions related thereto, including the potential cashgathering fee relief to EQT in connection withthereunder. As was the MVP in-service date. Thecase for the Gathering operating revenues during the first nine months of 2021, the 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 are also expected to contribute to an increase in the Company’s firm reservation fee revenues following achievement of the Hammerhead pipeline in-service. See also “Outlook” for discussions of the arbitration decision issued in the Hammerhead pipeline dispute with EQT.
Transmission Results of Operations
| | | | Three Months Ended September 30, | | Nine Months Ended September 30, | | Three Months Ended September 30, | | Nine Months Ended September 30, |
| | | 2020 | | 2019 | | %
Change | | 2020 | | 2019 | | %
Change | | 2021 | | 2020 | | %
Change | | 2021 | | 2020 | | %
Change |
| | (Thousands, except per day amounts) | | (Thousands, except per day amounts) |
| FINANCIAL DATA | FINANCIAL DATA | | | | | | FINANCIAL DATA | | | | | |
| Firm reservation fee revenues | Firm reservation fee revenues | $ | 84,612 | | | $ | 81,990 | | | 3.2 | | | $ | 267,973 | | | $ | 263,051 | | | 1.9 | | Firm reservation fee revenues | $ | 84,053 | | | $ | 84,612 | | | (0.7) | | | $ | 269,239 | | | $ | 267,973 | | | 0.5 | |
| | Volumetric-based fee revenues | Volumetric-based fee revenues | 8,717 | | | 5,309 | | | 64.2 | | | 20,896 | | | 26,875 | | | (22.2) | | Volumetric-based fee revenues | 6,833 | | | 8,717 | | | (21.6) | | | 25,964 | | | 20,896 | | | 24.3 | |
| Total operating revenues | Total operating revenues | 93,329 | | | 87,299 | | | 6.9 | | | 288,869 | | | 289,926 | | | (0.4) | | Total operating revenues | 90,886 | | | 93,329 | | | (2.6) | | | 295,203 | | | 288,869 | | | 2.2 | |
| Operating expenses: | Operating expenses: | | Operating expenses: | |
| Operating and maintenance | Operating and maintenance | 8,653 | | | 8,976 | | | (3.6) | | | 27,724 | | | 23,142 | | | 19.8 | | Operating and maintenance | 7,922 | | | 8,653 | | | (8.4) | | | 23,682 | | | 27,724 | | | (14.6) | |
| Selling, general and administrative | Selling, general and administrative | 7,557 | | | 5,286 | | | 43.0 | | | 18,644 | | | 20,626 | | | (9.6) | | Selling, general and administrative | 9,426 | | | 7,557 | | | 24.7 | | | 26,907 | | | 18,644 | | | 44.3 | |
| Depreciation | Depreciation | 13,659 | | | 13,347 | | | 2.3 | | | 40,787 | | | 38,474 | | | 6.0 | | Depreciation | 13,835 | | | 13,659 | | | 1.3 | | | 41,461 | | | 40,787 | | | 1.7 | |
| Total operating expenses | Total operating expenses | 29,869 | | | 27,609 | | | 8.2 | | | 87,155 | | | 82,242 | | | 6.0 | | Total operating expenses | 31,183 | | | 29,869 | | | 4.4 | | | 92,050 | | | 87,155 | | | 5.6 | |
| Operating income | Operating income | $ | 63,460 | | | $ | 59,690 | | | 6.3 | | | $ | 201,714 | | | $ | 207,684 | | | (2.9) | | Operating income | $ | 59,703 | | | $ | 63,460 | | | (5.9) | | | $ | 203,153 | | | $ | 201,714 | | | 0.7 | |
| | Equity income | Equity income | $ | 60,917 | | | $ | 44,448 | | | 37.1 | | | $ | 171,233 | | | $ | 112,293 | | | 52.5 | | Equity income | $ | 8,461 | | | $ | 60,917 | | | (86.1) | | | $ | 14,385 | | | $ | 171,233 | | | (91.6) | |
| | OPERATIONAL DATA | OPERATIONAL DATA | | | | | | | OPERATIONAL DATA | | | | | | |
| Transmission pipeline throughput (BBtu per day) | Transmission pipeline throughput (BBtu per day) | | Transmission pipeline throughput (BBtu per day) | |
| Firm capacity reservation | Firm capacity reservation | 2,950 | | | 2,786 | | | 5.9 | | | 2,897 | | | 2,796 | | | 3.6 | | Firm capacity reservation | 2,939 | | | 2,950 | | | (0.4) | | | 2,927 | | | 2,897 | | | 1.0 | |
| Volumetric-based services | Volumetric-based services | 29 | | | 29 | | | — | | | 17 | | | 115 | | | (85.2) | | Volumetric-based services | 7 | | | 29 | | | (75.9) | | | 9 | | | 17 | | | (47.1) | |
| Total transmission pipeline throughput | Total transmission pipeline throughput | 2,979 | | | 2,815 | | | 5.8 | | | 2,914 | | | 2,911 | | | 0.1 | | Total transmission pipeline throughput | 2,946 | | | 2,979 | | | (1.1) | | | 2,936 | | | 2,914 | | | 0.8 | |
| | Average contracted firm transmission reservation commitments (BBtu per day) | Average contracted firm transmission reservation commitments (BBtu per day) | 3,859 | | | 3,650 | | | 5.7 | | | 4,027 | | | 3,914 | | | 2.9 | | Average contracted firm transmission reservation commitments (BBtu per day) | 3,819 | | | 3,859 | | | (1.0) | | | 4,008 | | | 4,027 | | | (0.5) | |
| Capital expenditures (a) | Capital expenditures (a) | $ | 6,721 | | | $ | 16,296 | | | (58.8) | | | $ | 32,983 | | | $ | 46,287 | | | (28.7) | | Capital expenditures (a) | $ | 5,755 | | | $ | 6,721 | | | (14.4) | | | $ | 17,050 | | | $ | 32,983 | | | (48.3) | |
(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$94.3 million and $179.0 million for the three and nine months ended September 30, 2021, respectively, and $65.6 million and $211.7$144.3 million for the three and nine months ended September 30, 2020, respectively.
Three Months Ended September 30, 2021 Compared to Three Months Ended September 30, 2020
Transmission operating revenues decreased by $2.4 million for the three months ended September 30, 2020 and 2019, respectively, and $144.3 million and $512.9 million for2021 compared to the ninethree months ended September 30, 2020 and 2019, respectively.primarily as a result of decreased volumetric-based usage fee revenues.
Three Months Ended September 30, 2020 Compared to Three Months Ended September 30, 2019
Transmission and storage revenuesOperating expenses increased by $6.0$1.3 million for the three months ended September 30, 20202021 compared to the three months ended September 30, 2019. Firm reservation fee revenues increased by $2.6 million primarily due to customers contracting for additional firm transmission capacity and volumetric-based fee revenues increased by $3.4 million primarily due to lease bonus revenue and increased usage fees.
Operating expenses increased by $2.3 million for the three months ended September 30, 2020 compared to the three months ended September 30, 2019 primarily as a result of higher selling, general and administrative expense resulting primarily from increased professional service fees, partly offset by lower operating and maintenance expense primarily due to lower personnel costs.
The increase in equityEquity income of $16.5decreased by $52.5 million for the three months ended September 30, 20202021 compared to the three months ended September 30, 2019 was related2020 due to the increasedecrease in the MVP Joint Venture's AFUDC on the MVP.MVP project for the three months ended September 30, 2021.
Nine Months Ended September 30, 20202021 Compared to Nine Months Ended September 30, 20192020
Transmission and storageoperating revenues decreasedincreased by $1.1$6.3 million for the nine months ended September 30, 20202021 compared to the nine months ended September 30, 2019.2020. Firm reservation fee revenues increased by $4.9$1.3 million primarily due to customers contracting for additional firm transmission capacity, and volumetric-basedcapacity. Volumetric-based fee revenues decreasedincreased by $6.0$5.1 million due to lower throughput volumes primarily due to producer curtailments as a result of depressed natural gas prices.higher storage activities and increased usage fees.
Operating expenses increased by $4.9 million for the nine months ended September 30, 20202021 compared to the nine months ended September 30, 20192020 primarily as a result of increased operating and maintenance expense and increased depreciation expense as a result of additional assets placed in-service, partly offset by lowerhigher selling, general and administrative expense resulting from increased professional service fees and personnel costs, partly offset by lower personnel costs.operating and maintenance expense primarily due to operational efficiencies.
The increase in equityEquity income of $58.9decreased by $156.8 million for the nine months ended September 30, 20202021 compared to the nine months ended September 30, 2019 was related2020 due to the increasedecrease in the MVP Joint Venture's AFUDC on the MVP.MVP project for the nine months ended September 30, 2021.
In January 2021, the MVP Joint Venture temporarily suspended AFUDC on the MVP project due to a temporary reduction in growth construction activities. During the second quarter of 2021, the MVP Joint Venture resumed some AFUDC on the MVP project as certain growth construction activities resumed. Depending on the timing of the resumption of the remaining growth construction activities and associated AFUDC, the Company’s equity income could be negatively impacted in future periods, and such impact could be substantial.
Water Results of Operations
| | | Three Months Ended September 30, | | Nine Months Ended September 30, | | Three Months Ended September 30, | | Nine Months Ended September 30, |
| | 2020 | | 2019 | | %
Change | | 2020 | | 2019 | | %
Change | | 2021 | | 2020 | | %
Change | | 2021 | | 2020 | | %
Change |
| | (Thousands) | | (Thousands, except MMgal amounts) |
| FINANCIAL DATA | FINANCIAL DATA | | | FINANCIAL DATA | | |
Firm reservation fee revenues (a) | Firm reservation fee revenues (a) | $ | 9,005 | | | $ | 840 | | | 972.0 | | | $ | 32,788 | | | $ | 4,531 | | | 623.6 | | Firm reservation fee revenues (a) | $ | 1,061 | | | $ | 9,005 | | | (88.2) | | | $ | 3,834 | | | $ | 32,788 | | | (88.3) | |
| Volumetric-based fee revenues | Volumetric-based fee revenues | 15,015 | | | 20,804 | | | (27.8) | | | 57,817 | | | 62,888 | | | (8.1) | | Volumetric-based fee revenues | 6,311 | | | 15,015 | | | (58.0) | | | 37,484 | | | 57,817 | | | (35.2) | |
| Total operating revenues | Total operating revenues | 24,020 | | | 21,644 | | | 11.0 | | | 90,605 | | | 67,419 | | | 34.4 | | Total operating revenues | 7,372 | | | 24,020 | | | (69.3) | | | 41,318 | | | 90,605 | | | (54.4) | |
| Operating expenses: | Operating expenses: | | Operating expenses: | |
| Operating and maintenance | Operating and maintenance | 4,569 | | | 6,918 | | | (34.0) | | | 23,960 | | | 26,458 | | | (9.4) | | Operating and maintenance | 5,053 | | | 4,569 | | | 10.6 | | | 14,581 | | | 23,960 | | | (39.1) | |
| Selling, general and administrative | Selling, general and administrative | 1,228 | | | 97 | | | 1,166.0 | | | 3,752 | | | 2,180 | | | 72.1 | | Selling, general and administrative | 2,369 | | | 1,228 | | | 92.9 | | | 5,396 | | | 3,752 | | | 43.8 | |
| Depreciation | Depreciation | 8,105 | | | 6,907 | | | 17.3 | | | 22,720 | | | 19,801 | | | 14.7 | | Depreciation | 4,364 | | | 8,105 | | | (46.2) | | | 20,740 | | | 22,720 | | | (8.7) | |
| Impairments of long-lived assets | | Impairments of long-lived assets | — | | | — | | | 100.0 | | | 56,178 | | | — | | | 100.0 | |
| Total operating expenses | Total operating expenses | 13,902 | | | 13,922 | | | (0.1) | | | 50,432 | | | 48,439 | | | 4.1 | | Total operating expenses | 11,786 | | | 13,902 | | | (15.2) | | | 96,895 | | | 50,432 | | | 92.1 | |
| Operating income | $ | 10,118 | | | $ | 7,722 | | | 31.0 | | | $ | 40,173 | | | $ | 18,980 | | | 111.7 | | |
| Operating (loss) income | | Operating (loss) income | $ | (4,414) | | | $ | 10,118 | | | (143.6) | | | $ | (55,577) | | | $ | 40,173 | | | (238.3) | |
| | OPERATIONAL DATA | OPERATIONAL DATA | | OPERATIONAL DATA | |
| Water services volumes (MMgal) | Water services volumes (MMgal) | | Water services volumes (MMgal) | |
Firm capacity reservation (b) | Firm capacity reservation (b) | 126 | | | 42 | | | 200.0 | | | 487 | | | 160 | | | 204.4 | | Firm capacity reservation (b) | 16 | | | 126 | | | (87.3) | | | 70 | | | 487 | | | (85.6) | |
| Volumetric-based services | Volumetric-based services | 307 | | | 481 | | | (36.2) | | | 1,124 | | | 1,351 | | | (16.8) | | Volumetric-based services | 161 | | | 307 | | | (47.6) | | | 837 | | | 1,124 | | | (25.5) | |
| Total water volumes | Total water volumes | 433 | | | 523 | | | (17.2) | | | 1,611 | | | 1,511 | | | 6.6 | | Total water volumes | 177 | | | 433 | | | (59.1) | | | 907 | | | 1,611 | | | (43.7) | |
| | Capital expenditures | Capital expenditures | $ | 2,530 | | | $ | 13,466 | | | (81.2) | | | $ | 8,377 | | | $ | 31,490 | | | (73.4) | | Capital expenditures | $ | 10,803 | | | $ | 2,530 | | | 327.0 | | | $ | 20,430 | | | $ | 8,377 | | | 143.9 | |
(a) For the three and nine months ended September 30, 2021, firm reservation fee revenues included approximately $0.5 million and $1.5 million, respectively, of MVC unbilled revenues. For the three and nine months ended September 30, 2020, firm reservation fee revenues included approximately $1.9 million and $11.4 million, respectively, of MVC unbilled revenues.
(b) 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.
Three Months Ended September 30, 20202021 Compared to Three Months Ended September 30, 20192020
Water operating revenues increaseddecreased by $2.4$16.6 million for the three months ended September 30, 20202021 compared to the three months ended September 30, 2019.2020. Firm reservation fee revenues increaseddecreased by $8.2$7.9 million primarily as a result of increaseddecreased revenues generated under agreementsassociated with MVCs, including increased unbilled revenue associated withcontractually lower MVCs. Volumetric-based fee revenues decreased $5.8$8.7 million primarily due to a 36% decrease in fresh water distributionlower volumes associated with decreased customer activity, partly offset by increased realized rates on a per gallon basis. A majority of the fresh water delivery fees the Company charges per gallon of water are tiered and thus are lower on a per gallon basis once certain volumetric thresholds are met.
Selling, general and administrative expense was higher in the third quarter of 2020 relative to the third quarter of 2019 as a result of higher personnel costs. Depreciation expense increased as a result of additional assets placed in-service. The increase in such operating expenses was partly offset by lower operating and maintenance expense associated with the timing of costs related to customer activities on drilling pads.
Nine Months Ended September 30, 2020 Compared to Nine Months Ended September 30, 2019decreased producer activity.
Water operating revenues increasedexpenses decreased by $23.2$2.1 million for the ninethree months ended September 30, 2021 compared to the three months ended September 30, 2020 compared to the nine months ended September 30, 2019. Firm reservation fee revenues increased by $28.3 million primarily as a result of increased revenues generated under agreements with MVCs, including increased unbilled revenue associated with MVCs. Volumetric-decreased depreciation expense due to the impairments of long-lived
basedassets (as described in Note 3 to the consolidated financial statements) during the second quarter of 2021, partially offset by higher selling, general and administrative expense resulting primarily from increased professional service fees.
Nine Months Ended September 30, 2021 Compared to Nine Months Ended September 30, 2020
Water operating revenues decreased by $49.3 million for the nine months ended September 30, 2021 compared to the nine months ended September 30, 2020. Firm reservation fee revenues decreased $5.1by $29.0 million primarily as a result of decreased revenues associated with contractually lower MVCs. Volumetric-based fee revenues decreased $20.3 million primarily due to lower volumes as a 17% decrease in fresh water distribution volumes associated withresult of decreased customerproducer activity partly offset by increasedand decreased realized rates on a per gallon basis.
Water operating expenses increased by $2.0$46.5 million for the nine months ended September 30, 20202021 compared to the nine months ended September 30, 20192020 primarily as a result of higher selling, general and administrative expense primarily duethe impairments of long-lived assets totaling $56.2 million (as described in Note 3 to higher personnel costs. Depreciation expense increased as a result of additional assets placed in-service. The increase in operating expenses wasthe consolidated financial statements), partly offset by lower operating and maintenance expense associated with the timing of costs relatedprimarily due to overall lower customer activities on drilling pads.activity resulting in lower fresh water and produced water costs.
The Company’s water services are directly associated with producers’ well completion activities and fresh and produced water needs (which are partially driven by horizontal lateral lengths and the number of completion stages per well), which will vary from quarter to quarter.. Therefore, the Water operating results traditionally fluctuate from year-to-year in response to producers’ well completion activities and water operating results for the interim periods are not necessarily indicative of the results for any year, including the year ending December 31, 2020.2021.
Other Income Statement Items
Other Income
Other income increased $21.8 millionwas relatively flat for the three and nine months ended September 30, 20202021 compared to the three and nine months ended September 30, 2019 primarily as2020.
See also "Outlook" for a resultdiscussion of a $21.0 million unrealized gain onfactors affecting the estimated fair value of the derivative instruments associated withasset attributable to the Henry Hub cash bonus payment provision entered intothat is recognized in other income on the first quarterCompany's statements of 2020. Other incomeconsolidated comprehensive income.
Loss on Extinguishment of Debt
Loss on extinguishment of debt increased $36.4$16.2 million for the nine months ended September 30, 20202021 compared to the nine months ended September 30, 2019 primarily as a result of a $37.7 million unrealized gain on derivative instruments associated with the Henry Hub cash bonus payment provision entered into in the first quarter of 2020 and a $2.9 million increase in the net settlement of incentive compensation, partially offset by a $4.3 million decrease in AFUDC - equity.
Loss on Early Extinguishment of Debt
2020. The Company incurred a loss on the early extinguishment of debt of $24.9$41.0 million during the nine months ended September 30, 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 nine months ended September 30, 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 onprimarily related to the prepayment and termination of the ETRN Term Loan Credit Agreement and the Equitrans Midstream Credit Facility in the first quarter of 2020.Agreement. See Note 98 to the consolidated financial statements.statements for additional discussion.
Net Interest Expense
Net interest expense increased by $20.8$7.7 million for the three months ended September 30, 20202021 compared to the three months ended September 30, 20192020 primarily due to higher interest expense of $26.0$22.1 million associated with the 2021 Senior Notes, partially offset by lower interest expense of $14.9 million primarily associated with the termination of the Amended 2019 EQM Term Loan Agreement, decreased borrowings under the Amended EQM Credit Facility and lower interest on the 2023 Notes as a result of the Tender Offers.
Net interest expense increased $64.9 million for the nine months ended September 30, 2021 compared to the nine months ended September 30, 2020 primarily due to higher interest expense of $65.8 million and $48.2 million associated with the 2021 Senior Notes and the 2020 Senior Notes, respectively, and decreased capitalized interest and AFUDC - debt of $6.7 million,partially offset by lower interest expense on the Amended EQM Credit Facility and ETRN Term Loans.
Net interest expense increased by $31.7 million for the nine months ended September 30, 2020 compared to the nine months ended September 30, 2019 primarily due to $29.7 million in higher interest expense associated with the 2020 Senior Notes and higher interest expense on the EQM Term Loans and decreased capitalized interest and AFUDC - debt of $4.2$13.9 million, partially offset by lower interest expense onof $64.2 million primarily associated with the termination of the Amended 2019 EQM Term Loan Agreement and the ETRN Term Loan Credit Agreement, decreased borrowings under the Amended EQM Credit Facility and lower interest on the ETRN Term Loans.2023 Notes as a result of the Tender Offers.
As a result of the issuance of the 2021 Senior Notes, and after taking into account the use of those proceeds to pay off other outstanding debt, the Company expects interest expense for the periods after the issuance of the 2021 Senior Notes to continue to be higher than comparable prior year periods.
See also Note 98 to the consolidated financial statements for a discussion of certain of the Company's outstanding debt.
Income Taxes
See Note 1211 to the consolidated financial statements for an explanation of the increasechanges in income taxes for the three and nine months ended September 30, 20202021 compared to the three and nine months ended September 30, 2019.2020.
The Company files a consolidated income tax return for federal income taxes and uses the asset and liability method to account for income taxes. EQM is and for the period prior to the EQGP Buyout, EQGP was, a limited partnership for U.S. federal and state income tax purposes. Eureka Midstream is a limited liability company for such purposes. EQM EQGP, 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, and for the period prior to the EQGP Buyout, all of EQGP's income was, included in the Company’sCompany's pre-tax income; however, the Company does not record income 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 portionportions of its income attributable to the noncontrolling limited partners of EQM and EQGP for the periods prior to the closingsclosing of the EQM Merger and the EQGP Buyout, respectively.Merger. This reduces the Company's effective tax rate in periods when the Company has consolidated pre-tax income. The Company expects itsCompany's effective tax rate for periods following the EQM Merger tohas been, and the Company expects its effective tax rate for future periods will be, generally be higher than the pre-EQM Merger periods due to the
decrease in net income attributable to noncontrolling interests as a result of the Company's acquisition of the outstanding EQM Common Units not held by the Company and its subsidiariesMerger and related restructuring of the EQM Series A Preferred Units in connection with the closing of the EQM Merger.Restructuring.
Net Income Attributable to Noncontrolling Interests
Net income attributable to noncontrolling interests decreasedwas relatively flat for the three months ended September 30, 20202021 compared to the three months ended September 30, 2019. For the three months ended September 30, 2020, the Company's noncontrolling interest included the third-party ownership interest in Eureka Midstream. For the three months ended September 30, 2019, the Company's noncontrolling interest included the third-party ownership interests in EQM, the EQM Series A Preferred Unit interests in EQM's net income and the third-party ownership interest in Eureka Midstream.
2020. Net income attributable to noncontrolling interest increasedinterests decreased for the nine months ended September 30, 20202021 compared to the nine months ended September 30, 20192020 primarily as a result of higher net income attributable to the reduction in noncontrolling interest in Eureka Midstream, partly offset by lower net income attributable to the noncontrolling interest in EQM primarily due to the impact ofconnection with the EQM Merger.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.
Capital Expenditures
See "Investing Activities" and "Capital Requirements" under "Capital Resources and Liquidity" for discussion of capital expenditures.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, is one ofwas the largest natural gas producersproducer in the U.S. based on average daily sales volumes.volumes as of September 30, 2021. The Company maintains a stable cash flow profile, with approximately 65%67% of its revenue for the nine months ended September 30, 20202021 generated by firm reservation fees. Further, the percentage of the Company's 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 that became effective on February 26, 2020 of 3.0 Bcf per day that became effective on April 1, 2020 and gradually steps up to 4.0 Bcf per day for several years following the full in-service date of the MVP project. This contract structure enhances the stability of the Company's cash flows and limits its direct exposure to commodity price risk.
The Company's principal strategy is to achieve thegreater scale and scope and enhance the durability of a top-tier midstream companyits financial strength, 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), focusing on ESG and sustainability initiatives, and, where appropriate, seeking and executing on strategically-aligned acquisition and joint venture opportunities and other strategic transactions, while strengthening its balance sheet through (i) through:
•highly predictable cash flows backed by firm reservation fees, (ii) fees;
•actions to deleverde-lever its balance sheet, (iii) sheet;
•disciplined capital spending, (iv) spending;
•operating cost controlcontrol; and (v)
•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 or MVC commitments. Additionally, the Company is targeting growth from volumetric gathering and transmission services opportunities and from its water services business. The Company believes that this approach will enable the Company to achieve its strategic goals.
The Company expects that the MVP project, together with the Hammerhead pipeline and Equitrans, L.P. expansion project,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 water services expansions.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., Con Edison, AltaGas Ltd. and RGC Resources, Inc. As of September 30, 2020,2021, the Company owned an approximate 45.9%46.6% interest in the MVP project and will operate the MVP. The MVP is an estimated 300 mile,300-mile, 42-inch diameter natural gas interstate pipeline with a targeted capacity of 2.0 Bcf per day that will 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. 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. As discussed under "The regulatory approval processFollowing 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 requests an Individual Permit from the Army Corps to effect approximately 300 water crossings utilizing open cut techniques (the Army Corps Individual Permit) and (ii) an application to amend the Certificate that seeks FERC authority to utilize alternative trenchless construction methods to effect approximately 120 water crossings. 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). Both the WVDEP and VADEQ submitted requests to the Army Corps for additional time to address the constructionapplications, and, in late June 2021, the Army Corps granted the WVDEP and the VADEQ additional review time through November 29, 2021 and December 31, 2021, respectively. In early June 2021, the FERC issued a notice of new midstream assets is challenging, and recent decisions by regulatory and judicial authorities in pending proceedings could impact our orschedule for the MVP Joint Venture's ability to obtain all approvalsCertificate amendment application and authorizations necessary to complete certain projects on the projected time frame or at all or our ability to achieveFERC issued an Environmental Assessment in mid-August 2021. Given that the expected investment returns onpermitting timelines for both the projects." included in "Item 1A. Risk Factors" in Part II of this Quarterly Report on Form 10-Q, there are pending legal and regulatory challenges to or otherwise affecting certain aspects of the MVP project that must be resolved before the MVP project can be completed,FERC and the MVP Joint Venture is working to resolve these challenges. Based primarily on unanticipated delays duringArmy Corps remain in-line with the prime summer and fall 2020 construction seasons resulting from the MVP Joint Venture’s inability to complete MVP project work under Nationwide Permit 12 authority (which was received in September 2020 and subsequently temporarily stayed in October 2020 by the Fourth Circuit Court of Appeals) and the continued need for authorization from the FERC to complete construction work in approximately 25 miles of the project route,Company's expectations, the Company is targetingcontinues to target a full in-service date for the MVP project during the second half of 2021in summer 2022 at a total project cost of $5.8 billion to $6.0approximately $6.2 billion (excluding AFUDC). Completion of
In order to complete the project in accordance with the targeted full in-service date and cost, will require,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, as necessary, certain other state-level approvals), and timely receive authorization from the FERC to amend the Certificate to utilize alternative trenchless construction methods for certain stream and wetland crossings. 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 modifying its prior stop work orders and extending the MVP Joint Venture’s prescribed time to complete the MVP project; (iii) 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, timely reinstatement of the MVP Joint Venture’s Nationwide Permit 12 permits or utilization of alternative permitting authority and/or construction methodsorder; and (iv) continue to cross streams and wetlands in a manner not requiring a Nationwide Permit 12, as well as resolution of challengesbe authorized to work under the Biological Opinion and Incidental Take Statement issued by the FWSUnited States Department of the Interior’s Fish and Wildlife Service (FWS) for the MVP project and receipt ofproject. In each case, any such foregoing or other authorizations from the Bureau of Land Management and U.S. Forest Service. See the discussion of themust remain in effect notwithstanding any pending or future challenge thereto. For further information regarding litigation and regulatory-relatedregulatory related delays affecting the completion of the MVP set forth inproject, see Part II, "Item 1. Legal Proceedings". Due to of this Quarterly Report on Form 10-Q. See also "The regulatory approval process for the uncertainty regarding the timingconstruction of permittingnew midstream assets is very challenging, and the outcome of any legal challenges, on August 25, 2020,decisions by regulatory and judicial authorities in pending or potential proceedings could impact our or the MVP Joint Venture filed a request with the FERC forVenture's ability to obtain or maintain in effect all approvals and on October 9, 2020, the FERC granted, an extension of timeauthorizations necessary to complete certain projects on the MVP projecttargeted 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 anthe year ended December 31, 2020 for additional two years through October 13, 2022.discussion of risks in respect of the targeted in-service date and cost discussed above.
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, 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 members' respective interests in the MVP project and decrease Con Edison's interest in the MVP project. As a result, based on the midpoint of theMVP project's $5.8 billion to $6.0approximate $6.2 billion (excluding AFUDC) targeted cost, the Company's ownership interest in the MVP project willis expected to progressively increase from approximately 45.9%46.6% to approximately 47.6%47.8%.
Through September 30, 2020,2021, based on the midpoint of the MVP project's targeted cost, the Company had funded approximately $2.1$2.4 billion of its estimated total capital contributions of approximately $2.9$3.1 billion (inclusive of additional contributions required due to the Con Edison cap described above), including approximately $140 million to $150$160 million in excess of the Company's ownership interest. For 2020,2021, the Company expects to make total capital contributions of $265$275 million to $275$295 million to the MVP Joint Venture for purposes of the MVP project, depending on the timing of construction of the project, of which approximately $142$175.8 million hashad been contributed to the MVP Joint Venture.Venture as of September 30, 2021.
•Wellhead Gathering Expansion Projects and Hammerhead Pipeline. During the nine months ended September 30, 2020,2021, the Company invested approximately $303$170.7 million in gathering projects (inclusive of capital expenditures related to the noncontrolling interest in Eureka Midstream). For 2020,2021, the Company expects to invest approximately $370$235 million to $390$260 million in gathering projects (inclusive of expected capital expenditures 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, including the Hammerhead pipeline. producers.
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 believesFor more information, including regarding in-service for the Hammerhead pipeline, was placed in-service effective August 1, 2020. For more information, see "Hammerhead Pipeline" below.
•Transmission Projects. During the nine months ended September 30, 2020,2021, the Company invested approximately $33$17.1 million in transmission projects. For 2020,2021, the Company expects to invest approximately $45$30 million to
$50 million in transmission projects, primarily attributable to the Allegheny Valley Connector, the Equitrans, L.P. Expansion project (EEP), whichThe EEP is designed to provide north-to-south capacity on the mainline Equitrans, L.P. system, including primarily for deliveries to the MVP, and power plant projects.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.
•MVP Southgate Project. In April 2018, the MVP Joint Venture announced the MVP Southgate project, a proposed 75-mile interstate pipeline that will 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. As designed, the MVP Southgate project has 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, which is expected to be spent primarily in 2021 and 2022. The Company expects to fund approximately $225 million of the overall project cost. During the nine months ended September 30, 2020, $2.72021, the Company made approximately $3.2 million of capital contributions were made by the Company to the MVP Joint Venture for the MVP Southgate project. For 2020,2021, the Company expects to make capital contributions of approximately $5 million to $10 million to the MVP Joint Venture for the MVP Southgate project. The Company will operate the MVP Southgate pipeline and, as of September 30, 2020,2021, owned a 47.2% interest in
the MVP Southgate project. 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 not 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 regulatorsDepartment 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, which denial was appealedproject. 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 on September 10, 2020. Thethe targeted full in-service date for the MVP and expectations regarding MVP Southgate permit approval timing, the Company is targeting commencing construction on the MVP Southgate in 2022 and placing the MVP Southgate in-service during the spring of 2023. See the discussion of litigation and regulatory related delays affecting the completion of the MVP Southgate project is targeted to be placed in-serviceset forth in 2022, which such targeted in-service is based on, among other things, favorable and timely resolutionPart II, "Item 1. Legal Proceedings" of this and other regulatory decisions and processes.Quarterly Report on Form 10-Q.
•Water Operations. During the nine months ended September 30, 2020,2021, the Company invested approximately $8$20.4 million in its fresh water delivery infrastructure. For 2020,2021, the Company expects to invest approximately $15$35 million in the operations of its fresh water delivery infrastructure in Pennsylvania and Ohio.Pennsylvania.
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 years following the full in-service date of the MVP project) 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 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). 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 $75 million during the fourth quarter of 2021 and by approximately $137 million during 2022. During the third quarter of 2021, the estimated deferral to the contract liability for 2022 increased by approximately $70 million due to a refinement of the full in-service date assumed within the summer 2022 in-service target for MVP. 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 before the MVP project can be completed which could have 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.
Based on the Henry Hub natural gas forward strip prices as of October 29, 2021 and the terms of the Henry Hub cash bonus payment provision, any further delays in the in-service date for the MVP project, including beyond the most recent targeted full in-service date of summer 2022, 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. For 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 be recognized in other income on the Company’s statements of consolidated comprehensive income.
For a discussion of the Company's commercial relationship with EQT and related considerations, including risk factors, see 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. 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" 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 arisesarose 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 maycould 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 will proceedparticipated in an arbitration hearing from June 28, 2021 to arbitration. The Company will vigorously defend against EQT’s claims and litigate the Company’s rights, including the assertion of appropriate counterclaims.
EQT Global GGA. On February 27, 2020, the Company announced the EQT Global GGA with EQT, 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 years following the in-service date of the MVP project) and the dedication of a substantial majority of EQT’s core acreage in Pennsylvania and West Virginia to the Company. Under the EQT Global GGA, EQT will receive certain gathering fee relief over a period of three years following the in-service date of the MVP (as further described in Note 6 to the consolidated financial statements). The EQT Global GGA replaced 14 previous gathering agreements between affiliates of each of EQT and the Company.
UnderOn October 25, 2021, the EQT Global GGA,three-member panel appointed to arbitrate the performance obligation is to provide daily MVC capacity and as such the total consideration is allocated proportionally to the daily MVC over the lifedispute issued a binding arbitration decision in favor of the contract. In periodsCompany. The arbitration panel unanimously determined 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 the second half of 2021 for the MVP, the deferral to the contract liability is expected to increase by approximately $76 million for the remainder of 2020 and by approximately $225 million and $14 million, respectively, during 2021 and 2022. While 3.0 Bcf per day MVC capacity became effective with the entry into the EQT Global GGA, additional daily MVC capacity and the associated gathering MVC fees payable by EQT (or its affiliates) to the Company as set forth in the EQT Global GGA are conditioned upon the in-service date of the MVP. There are ongoing legal and regulatory matters that must be resolved favorably before the MVP project can be completed which could have a material effect on the performance obligation and the allocation of the total consideration over the life of the contract and the gathering MVC fees payable by EQT under the contract.
Based on the current Henry Hub natural gas forward strip prices and the terms of the Henry Hub cash bonus payment provision, any delays inHammerhead gathering agreement, although the in-service date for the MVP project, including the most recent targeted full in-service of the second half of 2021, may decrease the estimated fair value of the derivative assetHammerhead pipeline was delayed beyond October 1, 2020, such delay was caused by or attributable to force majeure and, accordingly, that EQT has no early termination right under the Henry Hub cash bonus payment provision, and such decrease may be substantial. Such changes in estimated fair value, if any, would be recognized in other income on the Company’s statements of consolidated comprehensive income.
For a discussion of the Company's commercial relationship with EQT and related considerations, including risk factors, see the Company's Annual Report on Form 10-K for the year ended December 31, 2019, as updated by this Quarterly Report on Form 10-Q. See also Note 6Hammerhead gathering agreement relating to the consolidated financial statements for additional information regardingtiming of Hammerhead pipeline in-service or related right to purchase the EQT Global GGA,Hammerhead gathering pipeline and associated facilities. Given the transactions related thereto.
EQM Merger. On June 17, 2020,arbitration panel’s determinations, the Company EQM, EQM LP, Merger Subwill not be entitled to charge EQT monthly firm capacity reservation fees under the Hammerhead gathering agreement unless and the EQM General Partner completed the EQM Merger, pursuant to which,until Hammerhead pipeline in-service is achieved (which the Company acquired all of the issued and outstanding EQM Common Units (other than EQM Common Units held by the Company and its subsidiaries)expects in conjunction with MVP in-service). As a result of the EQM Merger, EQM is an indirect, wholly owned subsidiary of the Company and is no longer a publicly traded entity. See Notes 1 and 2 to the consolidated financial statements for additional information regarding the EQM Merger.
CommodityLocal Market Natural Gas 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 natural gas liquids haveNGLs, including regional basis differentials, may adversely affectedaffect 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. See “COVID-19 Update” under “Executive Overview” above for a discussion of the impact the COVID-19 outbreak has had on oil, natural gas liquids andbusiness that is directly associated with producers’ well completion activities.
While natural gas prices andhave surged from 2020 lows as of the positive impact lower oil prices are expected to havefiling of this Quarterly Report on Form 10-Q, low or discounted natural gas prices in the near-Appalachian region have affected, and medium-term, primarily as a resultcould in the future affect, Company producer customers’ determinations in respect of the expected corresponding declinesamount and location of future rig and completion activity, timing of turning wells in the production of associated gas in the United States which the market expects will more than offset reduced demand for natural gas as a result of the COVID-19 outbreak.
Henry Hub spotline and local spot natural gas prices, which were under pressure priorwhether to the COVID-19 outbreak due primarily to a warmer than normal 2019 and 2020 winter heating season, a temperate spring 2020 season and an oversupply of natural gas (caused in part by the significant increase in production of associated gas from the Permian Basin and similar basins in recent years), have been further pressured by a reduction in global demand for natural gas during the first nine months of 2020 (for which the COVID-19 outbreak has been a contributing factor), lack of available natural gas storage and the continued significant supplies of natural gas being produced, particularly from the Appalachian Basin. The Henry Hub natural gas price ranged from $1.33 per MMbtu to $2.52 per MMbtu between January 1, 2020 and September 30, 2020, with some prices reflecting the lowest natural gas prices in more than 20 years. Further, 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 the first nine months of 2020. While the Company expects natural gas prices to recover beginning in the fourth quarter of 2020, as reflected by the current natural gas forward price strip, primarily due to the decrease in associated gas production from the Permian Basin and increased demand for natural gas during the colder winter months, the length and extent of that price recovery (if any) 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 global demand for natural gas, the pace of the reduction of natural gas production (primarily from the expected decrease in supplies of associated gas from the Permian Basin resulting from the dramatic decrease in oil prices during the first half of 2020), and the length and severity of the COVID-19 outbreak, during which a record number of shipments of liquified natural gas have been cancelled. There is no assurance that the elevated natural gas prices indicated by the forward natural gas price strip will be realized or that any positive impact from the decline in oil prices will offset reduced demand for natural gas as a result of the COVID-19 outbreak or other factors.
Lower natural gas prices have caused certain producers, including customers of the Company, to determine to reduce their rig count (and thereby delay production), temporarily shut in portions of their production or otherwise take actions to slow
production growth and/or reduce production which when effectedduring periods of low and discounted local natural gas prices. For additional information regarding impacts of commodity prices on the Company and related risks, including regarding past production curtailments by the Company's producer customers reduces the demand for, and usage of, the Company’s services. For instance, in May 2020 and September 2020, EQT, the Company's largest customer, publicly disclosed that it had made the strategic decision to temporarily curtail significant portions of its production, and certain other Company customers, also curtailed portions of their production during the second and/or third quarters of 2020. Substantially all of the curtailed production has returned to the Company’s gathering and/or transmission systems as of the filing datesee Part I, “Item 3. Quantitative and Qualitative Disclosures About Market Risk” of this Quarterly Report on Form 10-Q. The recent production curtailments caused a decrease in the Company's volumetric-based fee revenues for the second and third quarters of 2020, and an extended period of low natural gas prices and/or a slow recovery of natural gas prices in the fourth quarter of 2020 and in 2021 could cause EQT or other producers to take similar actions in the future, which could have a significant negative effect on the demand for the Company's services and therefore its results of operation.
The Company’s customers, including EQT, Range Resources and Gulfport Energy Corporation (Gulfport), previously announced reductions in their capital spending forecasts for 2020 and may continue to lower capital spending in the future based on commodity prices, access to capital, investor expectations for positive free cash flow, a desire to reduce or refinance leverage (including the perceived ability to do so), or other factors. On January 13, 2020, EQT publicly announced a 2020 capital expenditure forecast of $1.25 billion to $1.35 billion, compared to 2019 capital expenditures of $1.85 billion to $1.95 billion, which represented an approximate 30% decrease in capital expenditures compared to EQT’s projected 2019 capital expenditures. On March 16, 2020, EQT announced a further reduction in its 2020 capital expenditure forecast to $1.075 billion to $1.175 billion. Finally, on October 22, 2020, EQT announced a reduction in its 2020 capital expenditure forecast to $1.05 billion to $1.10 billion. In addition, longer-term price declines and sustained periods of low natural gas and natural gas liquids prices could continue to 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 activity levels and, accordingly, volumetric-based fees, which could affect the Company’s results of operations, liquidity or financial position. Each of S&P, Moody's and Fitch took negative ratings actions on a number of Appalachian exploration and production companies during 2020, including EQT, Range Resources and Gulfport, citing, among other things, lower natural gas price assumptions and current and future financing needs (although Fitch revised its ratings outlook for EQT to positive from negative in June 2020, citing EQT's efforts to reduce outstanding debt and improvements in natural gas fundamentals, S&P updated its ratings outlook for EQT from negative to stable in August 2020, Moody's updated its ratings outlook for EQT from negative to positive in October 2020, and S&P upgraded EQT's rating from from BB- with a stable outlook to BB with a stable outlook in October 2020). On August 7, 2020, Gulfport announced that its management has substantial doubt about Gulfport's ability to continue10-Q, as a going concern, citing, among other things, decreased demand for natural gaswell as a result of the COVID-19 pandemic and accompanying decrease in commodity prices significantly impairing Gulfport’s ability to access capital markets and refinance existing indebtedness. In October 2020, Gulfport elected to defer making interest payments with respect to certain of its outstanding indebtedness and entered into a forbearance agreement with certain of its lenders to temporarily waive any defaults in connection with the interest payment deferrals until the earlier of November 13, 2020 or another event that would trigger the end of the forbearance period. Many of the Company’s customers, including EQT, have entered into long-term firm reservation transmission and gathering contracts or contracts with MVCs on the Company's systems. However, approximately 35% of the Company’s operating revenues for the first nine months of 2020 were volumetric-based fee revenues. For more information, see "Decreases in production of natural gas in EQM'sour areas of operation have adversely affected, and future decreases could further adversely affect, itsour business and operating results and reduce itsour cash available to make distributionspay cash dividends to its unitholders, including us.our shareholders." included in Item "1A. Risk Factors - Risks Related to EQM's Business"Factors" of the Company’s Annual Report on Form 10-K for the year ended December 31, 2019.2020.
Potential Future Impairments. During the second quarter of 2021, the Company recognized impairments of approximately $56.2 million related to the Ohio Water long-lived assets. During the first quarter of 2020, the Company recognized an impairmentimpairments 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 associated with the Eureka/Hornet reporting unit.assets. See Note 43 to the consolidated financial statements for additional information. As of the filing of this Quarterly Report on Form 10-Q, the Company cannot predict the likelihood or magnitude of any future impairment.
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. For the Company’sSimilarly, cash flow estimates utilized for purposes of evaluating long-lived assets and equity method investments (such as in the MVP Joint Venture, management must evaluateVenture) require the Company’sCompany to make projections and assumptions for many years into the future for pricing, demand, competition, operating 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 equity method investments, that such investments have suffered other-than-temporary declines in fair value under ASC 323.323). The Company believes the estimates and assumptions used in estimating its reporting units’, its long-lived assets' and its equity investments’investment's fair values are reasonable and appropriate;appropriate as of September 30, 2021; 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, of goodwill and equity investments, which could materially affect the Company’s results of operations and financial position. Additionally, actual results could differ from these estimates.estimates and assumptions may not be realized. The Company also continues to evaluate and monitor the ongoing legal and regulatory matters related to the MVP and MVP Southgate projects that affect project that must be resolved favorably (and timely) before the project can be completed,completion, as further described in Part II, “Item 1. Legal Proceedings” of this Quarterly Report on Form 10-Q. Adverse or delayed developments with respect to such matters or other adverse developments 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 impairment of that investment. See also Note 43 to the consolidated financial statements, andas well as “Reviews of
our goodwill, and intangible and other long-lived assets have resulted in significant impairment charges and reviews of our goodwill, intangible and other long-lived assets (including equity method investments) could result in future significant impairment charges.charges, including with respect to our investment in the MVP Joint Venture.” included in Part II, “Item 1A. Risk Factors,"Factors" in the Company's Annual Report on Form 10-K for the year ended December 31, 2020 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 Operations" in the Company's Annual Report on Form 10-K for the year ended December 31, 2020.
As of the filing of this Quarterly Report on Form 10-Q.10-Q, the Company cannot predict the likelihood or magnitude of any future impairment.
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, capital and other markets (including refinancing existing credit facilities as they mature).markets. 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 and other financial and business factors including the current COVID-19 outbreak,(including market forces causing shifts in investor and lender sentiment away from fossil fuels and credit allocations to industries and companies perceived as being more sustainable, having better growth opportunities and/or having stronger ESG metrics and practices), 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 by the Company.securities. As of September 30, 2020,2021, pursuant to the terms of the Amended EQM Credit Facility, and Amended 2019 EQM Term Loan Agreement, EQM would have been able to borrow approximately $2.0$1.0 billion under the Amended EQM Credit Facility. Pursuant to the Tax Matters Agreement,The amount the Company is subjectable to certain restrictions related to certain corporate actions, including restrictions related to the issuance of Company securities beyond certain thresholds as set forth in the Tax Matters Agreement for a two-year period following the Separation and Distribution. See "We may determine to forgo or be required to forgo certain transactions in order to avoid the risk of incurring material tax-related liabilities or indemnification obligations under the tax matters agreement." included in "Item 1A. Risk Factors – Risks Related to the Separation," in the Company’s Annual Report on Form 10-K for the year ended December 31, 2019. The Company is not forecasting any public equity issuance for currently anticipated organic growth projects.
In February 2020, S&P and Fitch downgraded EQM's credit ratings from investment grade to non-investment grade. In addition, in April 2020, Moody's further downgraded EQM's credit rating from Ba2 (with a negative outlook) to Ba3 (with a negative outlook), and S&P further downgraded EQM's credit rating from BB (with a stable outlook) to BB- (with a negative outlook, which subsequently was revised by S&P in September 2020 to stable). The non-investment grade ratings from Moody's, S&P and Fitch have caused the Company to incur higher borrowing costsborrow under the Amended EQM Credit Facility andis bounded by a maximum consolidated leverage ratio. See Note 8 to the consolidated financial statements included in this Quarterly Report on Form 10-Q for further information regarding the Amended 2019 EQM Term Loan Agreement.Credit Facility.
See “Security Ratings” below for a discussion of EQM’s credit ratings as of September 30, 2021. As a result of thedowngrades of EQM's credit ratings to non-investment grade in February 2020, downgrades, EQM was also obligated to deliver additional 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 midpoint of the targeted cost for the project), would beis in the amount of approximately $231.2$219.7 million and is, in the case of the MVP Southgate, $14.2 million, in each case as of the filing date of this Quarterly Report on Form 10-Q. 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's credit ratings, including in connection with the MVP project or changes in thecustomer credit ratings of EQT,changes, including EQT's, which are determined by independent third parties, could impact EQM'sour liquidity, access to capital, and costs of doing business." included in "Item 1A. Risk Factors – Risks Related to EQM's Business,"Factors" in the Company’s Annual Report on Form 10-K for the year ended December 31, 2019.2020.
Operating Activities
Net cash flows provided by operating activities were $822.0 million for the nine months ended September 30, 2021 compared to $824.2 million for the nine months ended September 30, 2020 compared to $690.5 million for the nine months ended September 30, 2019.2020. The increasedecrease was primarily driven by the timing of working capital receipts and payments.
Investing Activities
Net cash flows used in investing activities were $386.1 million for the nine months ended September 30, 2021 compared to $518.1 million for the nine months ended September 30, 2020 compared to $2,116.52020. Investing activities decreased by approximately $166.5 million for the nine months ended September 30, 2019. The decrease2021, as compared to the nine months ended September 30, 2020, primarily due to decreased capital expenditure spending on Eureka projects, the Hammerhead pipeline and various wellhead gathering and transmission projects, which was attributable to cash used for the Bolt-on Acquisitionpartially offset by an increase in 2019, decreased capital contributions to the MVP Joint Venture in 2020 consistent with a lower leveltiming of the resumption of certain growth construction activities foron the MVP project and decreasedproject. See “Capital Requirements” below for a discussion of forecasted 2021 capital expenditures during 2020 as further described in "Capital Requirements."and capital contributions to the MVP Joint Venture.
Financing Activities
Net cash flows used in financing activities were $449.7 million for the nine months ended September 30, 2021 compared to $211.9 million for the nine months ended September 30, 2020 compared to net cash flows provided by financing activities of $1,285.7 million for2020. For the nine months ended September 30, 2019.2021, the primary uses of financing cash flows were the payment for retirement of the EQM Term Loans and termination of the Amended 2019 EQM Term Loan Agreement, net repayments on borrowings under the revolving credit facilities, 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 source of financing cash flows was the issuance of the 2021 Senior Notes. For the nine months ended September 30, 2020, the primary source of financing cash flows was net proceeds from the 2020 Senior Notes issuance, while the primary uses of financing cash flows were the redemption of the EQM Series A Preferred Units, payment for the retirement of the ETRN Term Loans, the payments of dividends and distributions to shareholders and unitholders (including distributions paid to EQM Series A Preferred unitholders) and net payments of borrowings on the First Amended EQM Credit Facility. The net proceeds from the 2020 Senior Notes were primarily used to repay borrowings on the Amended EQM Credit Facility. For the nine months ended September 30, 2019, the primary sources of financing cash flows were borrowings on the Amended EQM Credit Facility, proceeds from the issuance of the term loans under the Amended 2019 EQM Term Loan Agreement, which were used to pay down borrowings under the Amended EQM Credit Facility, and the issuance of the EQM Series A Preferred Units, while the primary use of financing cash flows were the net payments on EQM's credit facility borrowings, the payment of dividends and distributions to shareholders and unitholders and the purchase of EQGP Common Units.
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. The Company accrues capital expenditures when the capital work has been completed but the associated bills have not been paid. Accrued capital expenditures are excluded from the statements of consolidated cash flows until they are paid. See Note 5 to the consolidated financial statements.
Capital expenditures decreased by approximately $202.5 million for the three months ended September 30, 2020, as compared to the three months ended September 30, 2019, primarily due to decreased spending on the Hammerhead pipeline and various wellhead gathering projects. Capital expenditures decreased by approximately $423.1 million for the nine months ended September 30, 2020, as compared to the nine months ended September 30, 2019, primarily due to decreased spending on the Hammerhead pipeline and various wellhead gathering projects, partly offset by increased spending on the Eureka Midstream gathering system in 2020 compared to 2019.
For 2020,2021, capital contributions to the MVP Joint Venture are expected to be approximately $265$275 million to $275$295 million related to the MVP project and approximately $5 million to $10 million related to the MVP Southgate project, and capital expenditures are expected to be $430$300 million to $455$330 million (including approximately $45$15 million to $20 million attributable to the noncontrolling interest in Eureka Midstream). The Company's future 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 future capital expenditures and capital contributions primarily through cash on hand, cash generated from operations and borrowings under its subsidiaries' credit facilities.
Credit Facility Borrowings
See Note 98 to the consolidated financial statements for discussion of the Amended EQM Credit Facility, the Amended 2019 EQM Term Loan Agreement (prior to its termination), the Former Eureka Credit Facility (prior to its termination) and the 2021 Eureka Credit Facility.
Security Ratings
The table below sets forth the credit ratings for EQM's debt instruments at September 30, 2020.2021.
| | | | | | | | | | | | | | | | | | | |
| | | EQM | | |
| | | Senior Notes | | |
| Rating Service | | | | | Rating | | Outlook | | | | |
| Moody's | | | | | Ba3 | | Negative | | | | |
| S&P | | | | | BB- | | Stable | | | | |
| Fitch | | | | | BB | | Negative | | | | |
On February 4, 2020, S&P downgraded EQM's credit to a BB+ rating, with a negative outlook, from a BBB- rating following S&P's downgrade of EQT. On February 27, 2020, S&P further downgraded EQM's credit to a BB rating, with a stable outlook. On February 18, 2020, Fitch downgraded EQM to a BB rating, with a negative outlook, from a BBB- rating, citing a downgrade of EQT’s credit rating from BBB- to BB, with a negative outlook, on February 14, 2020, as well as uncertainty around the MVP project, as the principal reasons for the ratings action. On February 27, 2020, Moody's downgraded EQM's credit from Ba1, with a negative outlook, to Ba2, with a negative outlook, citing EQT's weakening credit profile, risks to completion of the MVP project and the increase to EQM's financial leverage resulting from actions in connection with the EQM Merger and the Share Purchases. On April 2, 2020, Moody's further downgraded EQM's credit rating from Ba2, with a negative outlook, to Ba3, with a negative outlook, following Moody's downgrade of EQT's credit rating. On April 7, 2020, S&P further downgraded EQM's credit rating from BB, with a stable outlook, to BB-, with a negative outlook, following S&P's further downgrade of EQT's credit rating. In June 2020,January 2021, each of Moody's, S&P, and Fitch affirmed EQM's credit ratings in connection with the issuance of the 20202021 Senior Notes. On September 2, 2020, S&P, following its upgrade of EQT's outlook from negativeThere were no changes to stable (based on EQT's reduced debt and improved leverage and maturity profile), lifted EQM's outlook from negative to stable, citing primarily the change in EQT's outlook. The ETRN Term Loans were paid off on March 3, 2020 with proceeds from the EQM Credit Facility and the ETRN Term Loan Credit Agreement was terminated; therefore, the Company no longer has any credit ratings assigned to its debt.
during the nine months ended September 30, 2021. EQM's credit ratings are subject to further 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.customers. As of September 30, 2020,2021, EQT's public debt had credit ratings of BB- (subsequently updated to BB in October 2020)BB+ from S&P (with a stablepositive outlook), Ba3Ba1 from Moody's (with a negative outlook, which was subsequently changed to positive in October 2020)stable outlook) and BBBB+ from Fitch (with a positivestable outlook). As of December 31, 2019, EQT's credit ratings with each of S&P, Moody's and Fitch were considered investment grade. If any credit rating agency further 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 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, EQMthe 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, if applicable, construction contracts, 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. Anything below these ratings, including allAll 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, and recent decisions by regulatory and judicial authorities in pending or potential proceedings could 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 projectedtargeted time frame or at all or our ability to achieve the expected investment returnreturns on the projects." under "Item 1A. Risk Factors" in this Quarterlythe Company's Annual Report on Form 10-Q
10-K for the year ended December 31, 2020 and Part II, "Item 1. Legal Proceedings" of this Quarterly Report on Form 10-Q for discussion of certain litigation and regulatory proceedings, including related to the MVP project.and MVP Southgate projects.
See Note 1416 to the annual consolidated financial statements included in the Company's Annual Report on Form 10-K for the year ended December 31, 20192020 for further discussion of the Company's commitments and contingencies.
Dividends
On October 16, 2020,18, 2021, the Company's Board of Directors declared cash dividends for the third quarter of 20202021 of $0.15 per common share and $0.4873 per Equitrans Midstream Preferred Share, in each case, payable on November 13, 202012, 2021 to shareholders of record at the close of business on November 3, 2020.2, 2021.
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, 2019 as filed with the SEC on February 27, 2020. Any new accounting policies or updates to existing accounting policies as a result of new accounting
pronouncements have been included in the notes to the Company's consolidated financial statements in Part I, Item 1"Item 1. Financial Statements" of this Quarterly Report on Form 10-Q for the period ended September 30, 2020.10-Q. The application of the Company's critical accounting policies may require management to make judgments and estimates about the amounts reflected in the consolidated financial statements. Management uses historical experience and all available information to make these estimates and judgments. Different amounts could be reported using different assumptions 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 and term loans, as applicable.facilities. The Amended 2019 EQM Term Loan Agreement, 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 2019 EQM Term Loan Agreement and 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. Such 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 March 30, 2020, EQM executed amendments to the EQM Credit Facility and the 2019 EQM Term Loan Agreement, which, among other things, increased the interest rates applicable to the borrowings under such facilities. 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 98 and 109 to the consolidated financial statements for discussions of borrowings and fair value measurements, respectively. EQM and Eureka may from time to time hedge the interest on portions of borrowings under the revolving credit facilities, and Amended 2019 EQM Term Loan Agreement, 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 more recent 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, such as EQT, including EQT, its largest customer. Asas a result of changes in customer credit ratings, liquidity and access to capital markets. For example, as of September 30, 2020,2021, EQT had $0.8$0.6 billion of letters of credit outstanding to third parties under its revolving credit facility (inclusive of anfacility. In August 2021, EQT's $83.6 million letter of credit issued to the MVP Joint Venture).Venture was cancelled as a result of EQT's improved credit ratings. At September 30, 2020,2021, EQT's public senior debt had 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 discussion ofinformation regarding EQT's credit ratings.
In connection with the execution of the EQT Global GGA andSee Note 6 for information regarding the Credit Letter Agreement the Company agreed to, amongst other things, relieve certain credit posting requirements forand associated EQT in an amount of up to approximately $250 million, under its commercial agreements with the Company, subject to EQT maintaining a minimum credit rating from two of three rating agencies of (i) Ba3 with Moody’s, (ii) BB- with S&P and (iii) BB- with Fitch.requirements. 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 1315 to the annual consolidated financial statements included in the Company's Annual Report on Form 10-K for the year ended December 31, 20192020 for further discussion of the Company's exposure to credit risk.
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 natural gas liquids,NGLs, including those resulting from regional basis differentials, which have been significant during portions of the second and third quarters of 2020, have resulted in certain customers temporarily curtailing natural gas production during portions of 2020 and couldmay adversely affect timing of development of additional reserves and production that is accessible by the Company'sCompany’s pipeline and storage assets, or resultwhich also negatively affects the Company’s water services business, and may affect the creditworthiness of the Company’s customers.
Natural gas and NGL prices, particularly lower prices, affect capital spending levels of the Company's customers, which in lower drilling activity or additional curtailments, which would decreaseturn affect production levels and, accordingly, demand for the Company's services. services and therefore its results of operations.
Additionally, although natural gas prices have surged from 2020 lows as of the filing date of this Quarterly Report on Form 10-Q, higher natural gas prices have not caused the Company's largest customers to significantly increase their capital spending forecasts given factors such as, in the Company's view, corporate capital allocation strategies. Even if natural gas prices remain elevated, the Company's customers may announce lower, flat or modest increases to capital spending in the future based on various factors, including regional takeaway capacity limitations, access to capital, investor expectations regarding free cash flow, a desire to reduce or refinance leverage or other factors.
Lower regional natural gas prices, corporate capital allocation strategies or regional takeaway constraints during periods of high natural gas prices, could also 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. TheAdditionally, lower natural gas prices, particularly in the Appalachian region, have 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 customers resulted in a decrease in the Company's volumetric-based fee revenues for portions of 2020. An extended period of low natural gas prices and/or instability in natural gas prices in future periods, especially in the Appalachian region, could cause EQT or other producers to take similar actions in the future, which could have a significant negative effect on the demand for the Company's services and therefore its results of operations. Many of the Company’s customers, including EQT, Range Resourceshave entered into long-term firm reservation transmission and Gulfport, have announced reductionsgathering contracts or contracts with MVCs on the Company's systems and approximately 67% of the Company’s operating revenue for the nine months ended September 30, 2021 was generated by firm reservation fees. As a result, the Company believes that the effect of temporary declines in their capital spending andvolumes of gas gathered, transported or stored on its systems may announce lower capital spendingbe 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 future basedCompany's areas of operations would adversely affect the Company's results of operations, financial condition and liquidity as approximately 33% of the Company’s operating revenues for the nine months ended September 30, 2021 was generated by volumetric-based fee revenues).
Price declines and sustained periods of low natural gas and NGL prices could have an adverse effect on commodity prices, access to capital, investor expectations regarding free cash flow, a desire to reduce or refinance leverage (including the perceivedcreditworthiness of the Company's customers and related ability to do so) 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 factors. things, lower natural gas price assumptions and 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). 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, under service arrangementsgathered or provided on its transmission and storage system, the volumes gathered on its gathering systems or the volumes of water provided by its water services business will be dependent on receiving consistent or increasing commitments and production from its existing customers.customers, which may be impacted by commodity prices, including regional commodity 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.economical above the amount to fulfill its required MVCs or otherwise strategically determine to curtail volumes on the Company's systems. For example, in May 2020 and September 2020, EQT publicly disclosed that it had made the strategic decision to temporarily curtail significant portions of its its production, and certain other Company customers also curtailed portions of their production during the second and/or third quarters of 2020. See "Commodity Prices" under "Outlook" for additional discussion. 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 65 to the consolidated financial statements for a discussion of the EQT Global GGA and the 2021 Water Services Letter Agreement with EQT.
The Company's cash flow profile is underpinned by both firm reservation fee revenues and volumetric-based fees, with approximately 65% of its revenue for the nine months ended September 30, 2020 generated by firm reservation fee revenues, including revenues from MVCs. Accordingly, the Company believes that the effect of short- and medium-term 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. See "EQM's exposure to direct commodity price risk may increase in the future." under "Item 1A. Risk Factors - Risks Related to EQM's Business" in the Company's Annual Report on Form 10-K for the year ended December 31, 2019. Sustained periods of low commodity prices could however have a further adverse effect on customer creditworthiness and related ability to pay firm reservation fees under long-term contracts and/or affect activity levels and accordingly volumetric-based fees, all of which could affect the Company's results of operations, liquidity or financial position. 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.Agreement.
The fair value of the Company’s derivative instruments is largely 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 $15.6$10.7 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 $18.7$12.9 million. This fair value change assumes volatility based on prevailing market parameters at September 30, 2020.2021. See Notes 65 and 109 to the consolidated financial statements for a discussion of the Henry Hub cash bonus payment provision.
For further discussion of commodity prices and related risks, see "Local Market Natural Gas 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 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", each under "Item 1A. Risk Factors" in the Company's Annual Report on Form 10-K for the year ended December 31, 2020.
Other Market Risks. The Amended EQM Credit Facility isand the 2021 Eureka Credit Facility are underwritten by a syndicatesyndicates of 21 and 16 financial institutions, respectively, each of which 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 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 9 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" for additional information on the Eureka Credit Facility.
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. During 2020, the Company completed the implementation of the initial phase of an enterprise resource planning (ERP) system, and revised and updated the related controls. These changes did not materially affect the Company's internal control over financial reporting. As the Company implements the remaining functionality under this ERP system through the first six months of 2021, it will continue to assess the impact on its 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 third quarter of 20202021 that have materially affected, or are reasonably likely to materially affect, the Company's internal control over financial reporting.
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
Eureka System Environmental Remediation. On April 10, 2019, EQM acquired a 60% equity interest in Eureka Midstream. Eureka Midstream received one notice of violation (NOV) in April 2019 and two NOVs in June 2019 from the Ohio Environmental Protection Agency associated with legacy slips. The Company cannot predict with certainty whether any facts or circumstances will result in a state environmental agency issuing additional NOVs. If penalties are imposed, an individual penalty or the aggregate of these penalties could result in monetary sanctions in excess of $100,000. However, the Company does not believe that the penalties, if imposed on Eureka Midstream, will result in obligations to the Company that will have a material impact on the financial condition, results of operations or liquidity of the Company.
Appalachian Pipeline North. On February 20, 2019, the Company notified the Pennsylvania Department of Environmental Protection (PADEP) that the erosion and sediment control general permit (ESG Permit) for Appalachian Pipeline North was not terminated or renewed prior to its expiration. The Company is working with the PADEP to obtain a minor modification for unpermitted features on the project that are functioning appropriately, partially terminate areas of the project that are adequately restored and re-permit areas that need to be addressed to achieve compliance with the ESG Permit requirements. In September 2020, the Company received a draft consent order and agreement from the PADEP and agreed to a civil penalty below $100,000 that the Company expects to pay in the fourth quarter of 2020.
Bowser Road Gas Explosion/Pratt Storage Field. On October 31, 2018, a gas explosion occurred in Morgan Township, Greene County, Pennsylvania (the Incident). Following the explosion, the PADEP, the Pennsylvania Public Utilities Commission and the Federal Pipeline and Hazardous Materials Safety Administration have been investigating the Incident. In January 2020, the PADEP notified the Company that it was required to submit an investigation report pursuant to the state’s gas migration regulations due to the Incident's proximity to the Company's Pratt Storage Field assets. The Company, while disputing the applicability of the regulations, submitted a report to the PADEP in March 2020. In September 2020, the PADEP responded to the Company’s investigation report with a request for additional information. The Company is reviewing the additional information requests but cannot predict whether any action will ultimately be brought by the PADEP or what the outcome of such an action would be. If a penalty is imposed, it could result in monetary sanctions in excess of $100,000. However, the Company does not believe that the penalty, if imposed, will have a material impact on the financial condition, results of operations or liquidity of the Company.
Pennsylvania DEP Consent Agreement I/M/O Swarts Storage Field – Stipulated Penalty Assessment. On September 2, 2020, the PADEP notified the Company that it was assessing a stipulated penalty in the amount of $490,000 due to the alleged failure of the Company to submit information required pursuant to an October 29, 2019 Consent Order and Agreement. 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 arising from the alleged violation referenced in the September 2, 2020 letter, but 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 $100,000. However, the Company does not believe that the penalties, if imposed, would have a material impact on the financial condition, results of operations or 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 favorably before the project can be completed, including the following:
•Sierra Club, et al. v. U.S. Army Corps of Engineers, et al., consolidated under Case No. 18-1173,Eng'rs (Huntington District) Fourth Circuit Court of Appeals (Fourth Circuit)., Case No. 20-2039 and Sierra Club, et al. v. U.S. Army Corps of Eng'rs (Norfolk District), Fourth Circuit Court of Appeals, Case No. 20-2042. In February 2018, the Sierra Club filed a lawsuit in the Fourth Circuit against the Army Corps in Sierra Club, et al. v. U.S. Army Corps of Engineers, (the U.S. Army Corps)et al., consolidated under Case No. 18-1173. The lawsuit challenged the verification by the Huntington District of the U.S. Army Corps that Nationwide Permit 12, which generally authorizes discharges of dredge or fill material into waters of the United States and the construction of pipelines across such waters under Section 404 of the Clean Water Act, could be utilized in the Huntington District (which covers all but the northernmost area of West Virginia) for the MVP project. The crux of Sierra Club's position was that the MVP Joint Venture, pursuant 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 iswas subject to Nationwide Permit 12. Following the issuance of the court's preliminary order, the U.S. Army Corps' Pittsburgh District (which had also verified use of Nationwide Permit 12 by the MVP Joint Venture) suspended its verification that allowed the MVP Joint Venture to use Nationwide Permit 12 for stream and wetlands crossings in northern West Virginia. On November 27, 2018, the Fourth Circuit panel issued its final decision vacating the Huntington District's verification of the use of Nationwide Permit 12 in West Virginia. In August 2018, the West Virginia Department of Environmental Protection (WVDEP)WVDEP initiated an administrative process to revise its 401 Water Quality Certification for the U.S. 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). In June 2018, the Sierra Club filed a second petition in the Fourth Circuit against the U.S. Army Corps, seeking review and a stay of the U.S. Army Corps Norfolk District's decision to verify the MVP Joint Venture's use of Nationwide Permit 12 for stream crossings in Virginia. The Fourth Circuit denied the Sierra Club's request for a stay on August 28, 2018. On October 5, 2018, the U.S. Army Corps' Norfolk District suspended its verification under Nationwide Permit 12 for stream crossings in Virginia pendingPending the resolution of the WVDEP 401 Rulemaking Proceedings. On December 10, 2018,Proceedings, the U.S. Army Corps filed a motionCorps' 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 place the caseuse Nationwide Permit 12 for stream and wetlands crossings in abeyance which the court granted on January 9, 2019.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 United States Environmental Protection Agency (the EPA)EPA for approval, (since the WVDEP was also required to obtain the EPA's agreement to the modified 401 certification) and provided notice to the U.S. Army Corps. The EPA's agreement to the WVDEP's modification of its 401 Water Quality Certificationwhich approval was received in August 2019 and the U.S.2019. The Army Corps approved the WVDEP's modification on January 24, 2020. Following U.S. Army Corps approval,2020, and the MVP Joint Venture submitted a new permit application to the U.S Army Corps on January 28, 2020. On September 25, 2020, the Huntington and Pittsburgh districts approved the 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 U.S. Army Corps' verifications to the MVP Joint Venture's Nationwide Permit 12. On October 16,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. Following resolution of administrative issues unrelated to the MVP project on September 13, 2021, the parties moved to dismiss the case, which the Fourth Circuit granted a temporary administrative stay to permit further time for the Court to consider the motion to stay, which temporary administrative stay is to remain in effect until the Court has ruled on the motion to stay. On October 30, 2020, the Fourth Circuit scheduled oral arguments on the motion to stay for November 9, 2020. If the administrative stay is ultimately granted, or if the Court determines that the U.S. Army Corps’ reverification was not proper, then the Company expects that either there will be further delays in obtaining approval of the MVP Joint Venture’s Nationwide Permit 12 or that the MVP Joint Venture will need to utilize alternative permitting authority and/or construction methods to cross streams and wetlands in a manner not requiring authorization under Nationwide Permit 12.September 23, 2021.
•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.Appeals In a different Fourth Circuit appeal, 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 USFS' analysis of erosion and sedimentation effects and the BLM's analysis of the practicality of alternate routes. 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 SEIS 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 was completed. Oral argument occurred on October 29, 2021 and the parties are awaiting a decision.
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 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"). 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). Briefing in Sierra Club, et al. v. FERC, Case No. 20-1512 (consolidated with No. 21-1040), D.C. Circuit Court of Appeals is to be completed in January 2022. If any of the challenges to the Record of Decision, the JNF Right-of-Way or whether the FERC's October 9, 2020 actions or any future action would be subject to challenge. The USFS published a draft Supplemental Environmental Impact Statement (SEIS) to the 2017 FERC Final Environmental Impact Statement for MVPand December 17, 2020 orders are successful, it could result in the Federal Register on September 25, 2020. The USFS is seeking public comments onRecord of Decision, the SEIS until November 9, 2020. The Company anticipates receivingJNF Right-of-Way or the final permit authorization duringFERC's orders, as applicable, being vacated and/or additional agency proceedings (the outcome of which the fourth quarter of 2020. The Company cannot guaranteepredict) and cause a delay in the timeliness oftargeted in-service date for the agency's actions or when a revised authorization will be finalized, or whether it would be further challenged.MVP project (and consequent impacts relating to such delay).
•Challenges to FERC Certificate, Court of Appeals for the District of Columbia Circuit (DC Circuit).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 Act 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. 17-1271.17-1271. 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. 17-1822.17-1822. 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. 18-5322.18-5322. 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, 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 is scheduled for December 15, 2021. 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), is to be completed in January 2022. If this challengeany of these challenges were successful, it could result in the MVP Joint Venture'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 delay in the targeted in-service date for the MVP project (and consequent impacts related to such delay).
•Greenbrier River Watershed Ass’n v. WVDEP, Circuit Court of Summers County, West Virginia, Case No. 18-AA-1.In August 2017, the Greenbrier River Watershed Association appealed MVP's Natural Stream Preservation Act Permit (NSPA Permit) obtained from the West Virginia Environmental Quality Board (WVEQB) for the Greenbrier River crossing. The NSPA Permit allowed the MVP Joint Venture to install the pipeline using an open-cut surface crossing technique in the Greenbrier River. Petitioners alleged that the issuance of the NSPA Permit failed to comply with West Virginia's Water Quality Standards for turbidity and sedimentation. The WVEQB dismissed the appeal in June 2018. In July 2018, the Greenbrier River Watershed Association appealed to the Circuit Court of Summers County, asking the Court to remand the NSPA Permit with instructions to impose state-designated construction windows and pre- and post-construction monitoring requirements as well as a reversal of the WVEQB's decision that the NSPA Permit was lawful. On September 18, 2018, the Court granted a stay. A hearing on the merits was held on October 23, 2018. The MVP Joint Venture has since changed its method of pipeline installation to a technique that will not disturb the river bottom or affect the free-flowing characteristics of the river. Accordingly, due to the change in crossing method, the MVP Joint Venture believes it is no longer required to obtain the NSPA Permit. On July 22, 2020, the MVP Joint Venture sent correspondence to the WVDEP voluntarily relinquishing the NSPA Permit. As a result, the MVP Joint Venture filed a motion to dismiss on July 24, 2020. On September 11, 2020, the Circuit Court granted the MVP Joint Venture’s motion to dismiss and the order was filed on September 14, 2020.
•Sierra ClubAppalachian Voices, et al. v. U.S. Dep’t of Interior, et al., Case No. 18-1082, Fourth Circuit Court of Appeals, Case No. 20-2159. . OnIn August 6, 2018,2019, Wild Virginia and certain other petitioners filed a petition in the Fourth Circuit held that the National Park Service (NPS) acted arbitrarily and capriciously in granting the ACP a right-of-way permit across the Blue Ridge Parkway. Specifically, the Fourth Circuit found that the permit cited the wrong source of legal authority and the NPS failed to make a “threshold determination that granting the right-of-
way is ‘not inconsistent with the use of such lands for parkway purposes’ and the overall National Park System to which it belongs.” Even though the MVP Joint Venture was not named in the ACP litigation, the MVP route crosses the Blue Ridge Parkway and implicates some of the same deficiencies addressed by the court. The MVP Joint Venture elected to request that the NPS temporarily suspend its Blue Ridge Parkway permit to reevaluate certain legal components of the MVP permit. As the portion of the MVP that crosses the Blue Ridge Parkway is completely constructed, the NPS granted the MVP Joint Venture the ability to continue final restoration efforts during the course of the suspended permit. The NPS issued a new right of way permit for the MVP project on September 25, 2020. There is no further litigation regarding the ACP's Blue Ridge Parkway permit and no current challenge to the MVP Joint Venture's Blue Ridge Parkway permit.
•Wild Virginia et al. v. United States Department of the Interior; Case No. 19-1866, Fourth Circuit Court of Appeals. Petitioners filed a petition in the Fourth Circuit to challenge MVP’sthe MVP Joint Venture’s Biological Opinion and Incidental Take Statement issued by FWS which was approved in November 2017 (BiOp)(the Original BiOp). Petitioners also requested a stay of the application of MVP’s BiOp during the pendency of the court case. On August 15, 2019, the MVP Joint Venture submitted a project-wide voluntary suspension of construction activities that pose a risk of incidental take, based on the 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 pending re-consultation between FWS and the FERC regarding FWS’s review of the BiOp. In response to the Fourth Circuit's order,2020. On October 15, 2019, the FERC issued an order on October 15, 2019 requiring the MVP Joint Venture to cease all forward-construction progress. Subsequently,progress (the FERC modified this order on October 9, 2020 and December 17, 2020, which the FERC authorized certain limited construction activitiesSierra Club has appealed to resume.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 BiOpBiological Opinion and Incidental Take Statement (the New BiOp) for the MVP project. On October 1, 2020,project and the Fourth Circuit subsequently dismissed the litigation regarding the originalOriginal BiOp. On October 27, 2020, the Sierra ClubAppalachian Voices et al. filed a petition with the Fourth Circuit challenging the newNew BiOp and filed a request for an administrative stay of the New BiOp with FWS, which FWS subsequently denied. On November 2, 2020, the Sierra Clubpetitioners filed a motion to stay the newNew 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, 2021. Oral argument occurred on October 29, 2021 and the parties are awaiting a decision. If this challenge were successful, it could result in the New BiOp being vacated and/or additional proceedings (the outcome of which the Company cannot predict) and cause a delay in the targeted in-service date for the MVP project (and consequent impacts relating to such delay).
Other Proceedings Relevant to the MVP Project
Grand Jury Subpoena.
FERC Rulemaking on Construction Commencement. On January 7, 2019, the MVP Joint Venture received a letter from the U.S. Attorney's Office for the Western District of Virginia stating that it and the EPA are investigating potential criminal and/or civil violations of the Clean Water Act and other federal statutes as they relate 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 is complying witha party to a FERC rulemaking proceeding that may potentially affect when the letterMVP Joint Venture is permitted to commence the crossings of streams and subpoena but cannot predict whether any action will ultimately be brought bywetlands utilizing trenchless construction methods following the U.S. Attorney's Office or whatFERC’s issuance of its amended Certificate for the outcomeMVP project, as described in “Outlook” under Part I, “Item 2. Management’s Discussion and Analysis of suchFinancial Condition and Results of Operation.” On May 4, 2021, the FERC issued Order No. 871-B. Order No. 871-B and its predecessors relate to an action would be.industry-wide rulemaking
regarding construction commencement while a rehearing request is pending before the FERC. The MVP Joint Venture beganfiled a rolling productionrequest for clarification or rehearing of documents responsivethe certificate amendment aspects of Order No. 871-B with the FERC on June 3, 2021. The FERC issued Order No. 871-C on August 2, 2021. The Company cannot predict the impact of Order No. 871 and its progeny on the MVP project, if any.
MVP Southgate Matters
The MVP Joint Venture is currently challenging or defending certain agency actions and judicial challenges to the subpoena afterMVP Southgate project that must be resolved before the U.S. Attorney’s office narrowed its subpoena inquiryproject can be completed, 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 five farms in Virginia containing twenty streams or wetlands.
For additional informationissue 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 legal proceedings, see also "Item 3. Legal Proceedings"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 has been fully briefed and is awaiting oral arguments. If this challenge were successful, it could result in the Company's Annual Report on Form 10-KMVP 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, and cause a delay in the targeted in-service date for the year ended December 31, 2019.MVP Southgate project (and consequent impacts relating to such delay).
•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" under "Outlook" in Part I, "Item 2. Management's Discussion and Analysis of Financial Condition and Results of Operations" for additional information. The Company is evaluating next steps, including the submission 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 a new application, if submitted, will ultimately be approved or, if approved, whether conditions may be included as part of such approval or whether the application would then be further challenged.
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, 2019,2020, other than the risks described below.
The outbreak
Risks Related to Our Operations
Increasing scrutiny and changing stakeholder expectations in respect of COVID-19 (or any future pandemic),ESG and related declines in economic output and demand for natural gas, could harmsustainability 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, proxy advisory firms, certain institutional investors and lenders, 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 and loans. Stakeholders’ increased focus and activism related to ESG and sustainability matters may potentially adversely affect our business, financial condition, results of operations, and financial condition.liquidity, as well as our stock price, and expose us to new or additional risks, including as described below.
In December 2019, COVID-19 was reported
Increased focus on ESG and sustainability matters, particularly in China,respect of climate change and in January 2020, the World Health Organization declared it a Public Health Emergency of International Concern. COVID-19 subsequently spread to additional countries including the United States, causing and continuing to cause significant business, employment and economic disruptions. Measures adopted by governments to help reduce the spread of the virus have adversely affected the economic and financial markets in the United States and many other countries, resulting in a recession of unknown duration and severity.
The COVID-19 outbreak and resulting economic downturn has resulted in a decrease in globalrelated demand for natural gas, causing,renewable and alternative energy, may, among other things, 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 record number of shipments of liquified natural gas to be cancelled, which has contributed to an oversupply of natural gas and, as a result of such oversupply, significantly depressed natural gas prices during the second and third quarters of 2020, including in the Appalachian Basin. While as of June 30, 2020 the Henry Hub natural gas forward price strip indicated a significant recovery for natural gas prices beginning in the fourth quarter of 2020, low natural gas prices resulted in production curtailments by certain of our customers, including EQT, in the second and third quarters of 2020, and a slower recovery in natural gas prices has and may continue to adverselynegative impact on the demand for our services.
Given the ongoing and dynamic nature of the circumstances, it is difficult to predict the further impact of the COVID-19 outbreak (or any other outbreak) on the domestic economy, the natural gas industry, or us; however, our business, results of operations and financial condition could be negatively affected in numerous ways, including, without limitation, that:
•our customers and suppliers may be adversely affected due to the economic downturn and recession resulting from the outbreak and may be adversely affected if the outbreak causes further or long-duration declines in the price of, demand for and production of natural gas or prevents such customers (particularly our largest customer) from conducting, or curtails their ability to conduct, field operations and continue natural gas production, which could reduce demand for our services, negatively affect throughput on our systems or heighten our exposure to risk of loss resulting from the nonpayment and/or nonperformance of our customers;
•our operations may be disrupted or become less efficient if a significant portion of our employees or contractors are unavailable due to illness or if our field operations, including in respect of projects in development, were to be suspended or temporarily shut down or restricted due to outbreak control measures;
•legal and regulatory processes relating to our projects in development, including the MVP and MVP Southgate projects, may be disrupted or slowed, such as if relevant governmental authorities suffer reduced workforce availability due to the virus; and
•resultant disruption to, and instability in, financial and credit markets may adversely affect our access to capital, leverage and liquidity levels and credit ratings, as well as our counterparties’ access to capital, business continuity, financial stability, leverage and liquidity levels and credit ratings (which could heighten counterparty credit risk to which we are exposed in the ordinary course of our business).
Although we believe that we are following best practices under COVID-19 guidance and intend to continue to refine our practices as additional guidance is released, there is no guarantee that efforts by us or any other entity or authority to mitigate potential adverse impacts of the COVID-19 outbreak, whether on a local, state or national level, will be effective.
We also may incur additional costs to further attempt to mitigate potential impacts caused by COVID-19 related disruptions, which could adversely affect our financial condition and results of operations. Further, the COVID-19 outbreak (including federal, state and local governmental responses, broad economic impacts and market disruptions) have heightened and may further heighten many of the other risks set forth in “Itemresults.” under "Item 1A. Risk Factors”Factors" in ourthe Company's Annual Report on Form 10-K for the year ended December 31, 2019. 2020. Additionally, pipeline infrastructure companies and projects, such as our MVP project, face increased legal scrutiny and risk, including litigation risk and enhanced and lengthier regulatory reviews by federal, state and/or environmental regulators, due to an increased focus on climate change policies and the fossil fuel industry.
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 have incurred and 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, even if our actions are compliant with applicable laws and regulations, our business could suffer reputational or other damage and, additionally, potential negative public perception regarding us or our industry may lead to increased regulatory scrutiny or other adverse developments. Activist shareholders may submit proposals to promote an ESG-related position. Proxy contests and other actions by activist shareholders can, among other things, cause reputational harm, and responding to such actions could be costly and time-consuming, disrupting our operations and diverting the attention of our Board and senior management from the pursuit of business strategies.
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. Such ratings and reports are used by some investors to inform their investment and voting decisions. Unfavorable ESG ratings or perceptions of us or our industry as a result of such ratings or our ESG and sustainability practices may lead to increased negative investor and other stakeholder sentiment toward us or our customers, and to the allocation of investment capital to other industries and companies, which could negatively affect our stock price and access to and costs of capital.
The extentoccurrence of any of the impactforegoing may adversely affect our business, financial condition, results of COVID-19 onoperations, liquidity and/or our stock price.
Terrorist or cyberattacks aimed at us will depend on future developments, which are highly uncertainor third parties, as well as any noncompliance by us with applicable laws and cannot be predicted, including new information which may emerge concerning the severity of COVID-19, duration of the outbreak and related economic effects and aftereffects (including on the natural gas industry), and actions taken to contain COVID-19 or its impact, among others.
We may further reduce the amount of the cash dividend that we pay on our common stock or may not pay any cash dividends at all to our shareholders. Our ability to declare and pay cash dividends to our shareholders, if any, in the future will depend on various factors, many of which are beyond our control.regulations governing data privacy, could materially adversely affect us.
We are nothave 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. Our increasing reliance on digital technologies puts us at greater risk for system failures, disruptions, incidents, and cyberattacks, which could significantly impair our ability to conduct our business. For instance, energy industry participants, including midstream companies, have been the victims of high-profile ransomware attacks, and we expect to continue to be targeted by cyberattacks, as a critical infrastructure company.
The U.S. government has continued to issue public warnings that indicate that energy assets might be specific targets of cyberattacks, and in May and July 2021, the U.S. Department of Homeland Security's Transportation Safety Administration (the “TSA”) issued security directives applicable to midstream companies requiring such companies to comply with mandatory reporting measures, undertake a number of specific cybersecurity enhancements for both information technology (“IT”) and operational technology (“OT”) systems, and provide extensive information to the TSA. We have been required and may further be required to declare and pay dividends to our common shareholders. In addition, as described below, we are prohibited from paying any dividends to our shareholders until we pay dividends on the Equitrans Midstream Preferred Shares. On April 27, 2020, our Board of Directors declared a first quarter 2020 dividend that was 67% lower than our fourth quarter 2019 quarterly dividend and maintained this dividend level for the second and third quarters of 2020. Our Board of Directors may further reduce the amount of the cash dividend that we pay on our common stock or may decide not to declare any dividends in the future. Any payment of future dividends will be at the sole discretion of our Board of Directors and will depend upon many factors, including the financial condition, earnings, liquidity and capital requirements of our operating subsidiaries, covenants associated with certain debt obligations, legal requirements, our leverage, regulatory constraints and other factors deemed relevant by our Board of Directors.
Our shareholders may experience dilutionexpend additional resources as a result of future issuances of common stockcurrent or new laws, regulations, directives or other equity securities.
Inrequirements related to critical infrastructure cybersecurity. Any failure to remain in compliance with laws or regulations governing critical infrastructure cybersecurity, including the future weTSA security directives, may issue common stockresult in penalties, fines, enforcement actions, or other equity to raise cash formandated changes in our projects, operations, acquisitions or other purposes andpractices, which may also acquire interests in other companies by usinghave a combination of cash and our equity or just our equity.
Any of these events may dilute your ownership interests in us, reduce our earnings per share and have anmaterial adverse effect on the price of our common stock. The issuance of these new sharesbusiness and the sale of additional shares from time to time could have the effect of depressing the market value for our common stock. The increase in the number of shares of our common stock outstanding or the issuance of other equity of us, and any resulting dilution, may cause holders to sell shares of our common stock or may create the perception that such sales may occur, either of which may adversely affect the market for, and the market value of, our common stock.
As part of the EQM Merger and the related Restructuring, we issued Equitrans Midstream Preferred Shares in exchange for a portion of the then-outstanding EQM Series A Preferred Units, which Equitrans Midstream Preferred Sharesby virtue of their terms and preferencespresent a number of risks to current and future holders of our common stock.
At the effective time of the EQM Merger, we created and issued new Equitrans Midstream Preferred Shares in exchange for a portion of the then-outstanding EQM Series A Preferred Units.
The Equitrans Midstream Preferred Shares have the following rights and preferences:
•The Equitrans Midstream Preferred Shares are a new class of security that ranks pari passu with any other outstanding class or series of our preferred stock and senior to all shares of our common stock with respect to dividend rights and rights upon liquidation.
•The Equitrans Midstream Preferred Shares vote on an as-converted basis with our common stock and have certain other class voting rights with respect to any amendment to our Certificate of Designations relating to the Equitrans Midstream Preferred Shares or our Amended and Restated Articles of Incorporation 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.
•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 Certificate of Designations) 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%.
•We are not entitled to pay any dividends on any junior securities, including any shares of our common stock, prior to paying the quarterly dividends payable to the holders of 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 our 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 us), 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 our 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 our Board of Directors.
•So long as the holders of Equitrans Midstream Preferred Shares have not elected to convert all of their Equitrans Midstream Preferred Shares into our common stock, we may elect to convert all of the Equitrans Midstream Preferred
Shares intoWhile we and our common stock, atthird-party service providers commit resources to the then-applicable conversion rate, at any time after April 10, 2021 if (i) our common stock is listed for, or admitted to, trading on a national securities exchange, (ii) the closing price per sharedesign, implementation and monitoring of our common stockIT and OT systems, there is no guarantee that our cybersecurity measures will provide absolute security. Despite these measures, we may not be able to anticipate, detect or prevent all cyberattacks or incidents, particularly because the methodologies used by attackers change frequently or may not be recognized until launched, and because attackers are increasingly using tactics, techniques, and procedures designed to circumvent controls and avoid detection. As a result, our IT and OT systems (or those of third parties with whom we are connected) that are designed to protect against cyber risks may not be sufficient, and deliberate attacks on, or unintentional events or incidents affecting, our systems or infrastructure or the systems or infrastructure of third parties could, depending on the national securities exchange on whichextent or duration of the sharesevent, materially adversely affect us, including by leading to corruption, misappropriation or loss of our common stock are listedproprietary and sensitive data, delays (which could be significant) in the performance of services for or admittedour customers, difficulty in completing and settling transactions, challenges in maintaining our books and records, communication interruptions, environmental damage, regulatory scrutiny, personal injury, property damage and other operational disruptions, as well as damage to trading exceeds $27.99 forour reputation, financial condition and cash flows and potential legal claims and liabilities. Like other companies in the 20 consecutive trading days immediately preceding noticenatural gas industry, we have identified and expect to continue to identify cyberattacks and incidents on our systems, but none of the conversion, (iii) the average daily trading volume of our common stock on the national securities exchange on which our common stock is listed for, or admitted to, trading exceeds 1,000,000 shares of our common stock (subject to certain adjustments) for the 20 consecutive trading days immediately preceding notice of the conversion, (iv)cyberattacks and incidents we have an effective registration statementidentified to date has had a material impact on file with the SEC covering resales of our common stock to be received by such holders upon any such conversion and (v) we have paid all prior accumulated and unpaid dividends in cash in full to the holders of Equitrans Midstream Preferred Shares.
•Upon certain events involving a Change of Control (as defined in the Certificate of Designations) in which more than 90% of the consideration payable to us,business or to the holders of our common stock, is payable in cash, the Equitrans Midstream Preferred Shares will automatically convert into our common stock at a conversion ratio equal to the greater of (i) the quotient of (a) the sum of (x) the Equitrans Midstream Preferred Share Issue 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 our 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 our common stock at the then-applicable conversion rate, (ii) if we are not the surviving entity (or if we are the surviving entity, but our common stock will cease to be listed), require us 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 we are 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 we are the surviving entity, continue to hold the Equitrans Midstream Preferred Shares or (iv) require us 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, our common stock or a combination thereof at the election of our Board of Directors (and, if payable in our common stock, such common stock will be issued at 95% of the volume weighted average price of our 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 us 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, we 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 any 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 our common stock at the then-applicable conversion ratio and we liquidated immediately thereafter.
•Pursuant to the terms of the Restructuring Agreement, in connection with the closing of the Restructuring, we entered into the Registration Rights Agreement pursuant to which, among other things, we gave the Investors certain rights to require us to file and maintain one or more registration statements with respect to the resale of the Equitrans Midstream Preferred Shares and the shares of our common stock that are issuable upon conversion of the Equitrans Midstream Preferred Shares, and which, upon request by certain Investors party to the Registration Rights Agreement, will require us to initiate underwritten offerings for the Equitrans Midstream Preferred Shares and the shares of our common stock that are issuable upon conversion of the Equitrans Midstream Preferred Shares and use our best efforts
Further, as cyberattacks continue to evolve and increase in sophistication and volume, we have expended, and expect to continue to expend, additional resources relating to cybersecurity, including as applicable, to continue to modify or enhance our preventive and protective measures and/or to investigate and remediate potential vulnerabilities to or consequences of cyberattacks and incidents. There can be no assurance that any preventive, protective, or remedial measures are or will be adequate to address threats that arise.
The regulatory landscape with regard to cause the Equitrans Midstream Preferred Sharesdata privacy continues to be listed on the securities exchange on which the sharesdevelop. New laws and regulations governing data privacy, as well as any unauthorized disclosure of personal information, may potentially increase our compliance costs. Any failure by us, a company that we acquire, or one of our common stock are then listed.technology service providers, to comply with these laws and regulations, where applicable, could adversely affect us, including by resulting in reputational harm, penalties, regulatory scrutiny, liabilities, and/or mandated changes in our business practices.
The creation
Our subsidiaries’ significant indebtedness, and issuance of the Equitrans Midstream Preferred Shares present a number of risks to current andany future holders of our common stock, including a preference in favor of holders of Equitrans Midstream Preferred Shares in the payment of dividends on our common stock, the risk of dilution occurring as a result of the conversion of the Equitrans Midstream Preferred Shares into our common stock and the ability of the holders of the Equitrans Midstream Preferred Shares to vote with the holders of our common stock on most matters,indebtedness, as well as the risk that the holders of the Equitrans Midstream Preferred Shares will have certain other class voting rights with respect to any amendment torestrictions under our organizational documents 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.
Reviews of our goodwill and intangible and other long-lived assets have resulted in significant impairment charges, and reviews of goodwill, intangible and other long-lived assets (including equity method investments) could result in future significant impairment charges.
GAAP requires us to perform an assessment of goodwill at the reporting unit level for impairment at least annually and whenever events or changes in circumstance indicate that the fair value of a reporting unit is more likely than not less than its carrying amount.
We may perform either a qualitative or quantitative assessment of potential impairment. Our qualitative assessment of potential impairment may result in the determination that a quantitative impairment analysis is not necessary. Under this elective process, we assess qualitative factors to determine whether the existence of events or circumstances leads us to determine that it is more likely than not that the fair value of a reporting unit is less than its carrying amount. If after assessing the totality of events or circumstances, we determine that it is more likely than not that the fair value of a reporting unit is greater than its carrying amount, then performing a quantitative analysis is not required. However, if we conclude otherwise, then we perform a quantitative impairment analysis. If we choose not to perform a qualitative assessment, or if we choose to perform a qualitative assessment but are unable to qualitatively conclude that no impairment has occurred, then we will perform a quantitative assessment. In the case of a quantitative assessment, we estimate the fair value of the reporting unit with which the goodwill is associated and compare it to the carrying value. If the estimated fair value of a reporting unit is less than its carrying value, an impairment charge is recognized for the excess of the reporting unit's carrying value over its fair value.
Assessing the recoverability of goodwill requires significant judgments and estimates by management. Fair values of reporting units to which goodwill is recorded are primarily estimated using the 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. All of our goodwill as of September 30, 2020 relates to businesses that were acquired and valued by EQT's management in the November 2017 acquisition by EQT of Rice Energy Inc. The reporting unit to which goodwill is recorded as of September 30, 2020 is the EQM Opco reporting unit, which is a reporting unit associated with the gas gathering and compression activities of EQM Gathering Opco, LLC, an indirect wholly owned subsidiary of EQM, and which includes, as a result of the EQT Global GGA, the assets under, and operations associated with, the RMP PA Gas Gathering reporting unit. The RMP PA Gas Gathering reporting unit reflected the Pennsylvania gathering assets acquired in connection with EQM's merger with Rice Midstream Partners LP in July 2018 (RMP PA Gas Gathering) and was, effective on the EQT Global GGA Effective Date, merged with and into the EQM Opco reporting unit, with the EQM Opco reporting unit surviving.
During 2019, we recognized impairments to goodwill in the third quarter of $168.9 million and $99.2 million on RMP PA Gas Gathering and the Ohio and West Virginia gathering assets acquired in the Bolt-on Acquisition, respectively. Additionally, for the fourth quarter of 2019, we recognized impairments of goodwill of $433.2 million and $150.5 million on RMP PA Gas Gathering and the Ohio gathering assets acquired by EQM through its indirect acquisition in May 2018 of all the outstanding limited liability company interests in each of EQM West Virginia, EQM Olympus and Strike Force Holdings.
We evaluate long-lived assets, including related intangibles 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 (or, in the case of equity method investments, that such investments have suffered other-than-temporary declines in value). Asset recoverability is measured by comparing the carrying value of the asset or asset group (or equity method investment) with its expected future pre-tax undiscounted cash flows. These cash flow estimates require us to make projections and assumptions for many years into the future for pricing, demand, competition, operating cost, commencement of operations, resolution of relevant legal and regulatory matters, and other factors. If the carrying amount exceeds the expected future undiscounted cash flows, we recognize an impairment equal to the excess of net book value over fair value as determined by quoted market prices in active markets or present value techniques if quotes are unavailable. The determination of the fair value using present value
techniques requires us to make projections and assumptions regarding the probability of a range of outcomes and the rates of interest used in the present value calculations. Any changes we make to these projections and assumptions could result in significant revisions to evaluations of recoverability or whether declines in value are other-than-temporary and the recognition of additional impairments.
As of March 31, 2020, we performed a recoverability test of the 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 (consisting of gathering assets and customer-related intangible assets) was not recoverable, 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.
If the operations or projected operating results of our businesses decline significantly, we could incur additional goodwill impairment charges. Further, if we determine that the carrying value of long-lived assets is not recoverable or values associated with equity method investments, such as investments in the MVP Joint Venture, have suffered other-than-temporary declines, we could incur additional impairment charges. Future impairment charges could be significant and could have a material adverse impact on our financial condition and results of operations for the period in which the impairment is recorded. As of September 30, 2020, we had approximately $486.7 million of goodwill (all associated with the EQM Opco reporting unit) and $11.3 billion of long-lived assets, including intangibles and equity method investments, which will be monitored for future impairment. Management will continue to monitor and evaluate the factors underlying the fair market value of acquired businesses and assets and equity method investments to determine if any assessments are necessary and will take any additional impairment charges required.
The regulatory approval process for the construction of new midstream assets is challenging, and recent decisions by regulatory and judicial authorities in pending proceedings could impact our or the MVP Joint Venture's ability to obtain all approvals and authorizations necessary to complete certain projects on the projected time frame or at all or our ability to achieve the expected investment returns on the projects.
Certain of our internal growth projects require regulatory approval from federal, state and/or local authorities prior to construction, including any extensions from or additions to our transmission and storage system. The approval process for certain projects has become increasingly challenging, due in part to state and local concerns related to exploration and production, transmission and gathering activities in production areas, including the Marcellus and Utica Shales, and negative public perception regarding the oil and gas industry, including major pipeline projects like the MVP and MVP Southgate. Such authorization may not be granted or, if granted, such authorization may include burdensome or expensive conditions.
In addition, significant delays in the regulatory approval process for growth projects, including the MVP and MVP Southgate projects, have increased costs and negatively impacted the targeted in-service dates for the projects, and further delays may cause similar adverse effects, including to the MVP project’s targeted full in-service date in the second half of 2021 and the MVP Southgate project's target in-service date in 2022. Significant delays and cost increases in turnsubsidiaries’ debt agreements, could adversely affect our ability, and, in the case of the MVP and MVP Southgate projects, the ability for the MVP Joint Venture and its owners, including us, to achieve the expected investment returns. The MVP project in particular is subject to several agency actions and judicial challenges (and may become subject to further actions and challenges) that must be resolved before the MVP and MVP Southgate projects can be completed, as described in more detail in Part II, "Item 1. Legal Proceedings."
Although the MVP Joint Venture is actively defending the relevant agency actions and judicial challenges to the project (and would actively defend future such matters), and is in active dialogue with all of the affected agencies to resolve these issues and restore or obtain the affected permits and other authorizations, there is no guarantee as to how long any agency proceedings and judicial challenges will take to resolve, or whether the MVP Joint Venture will ultimately succeed in restoring or obtaining the necessary permits and other authorizations (or be able to utilize alternative permitting authorities and/or construction methods) or do so within the MVP Joint Venture's targeted time frame for placing the project in service. Additionally, as the MVP project nears completion and in light of the abandonment by third parties of certain other similar pipeline projects, we have experienced and may further experience increased opposition from activists in the form of lawsuits, intervention in regulatory proceedings and otherwise, which has been and/or may be focused on the few remaining portions of the project. Such focused opposition may make it increasingly difficult to complete the project and place it in service within the targeted time frame or at all. We also expect that as pre-construction activity in respect of the MVP Southgate project increases, the MVP Southgate project may be subject to similar heightened opposition. These and other challenges could adversely affect ouroperating flexibility, business, financial condition, results of operations, liquidity and ability to pay dividends.dividends to our shareholders.
Following the MVP in-service date, the gathering fees payable by EQT
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, us (or our affiliates) set forth in the EQT Global GGA are subject to potential reductions foramong other things:
•incur or guarantee additional debt;
•make distributions on or redeem or repurchase units;
•incur or permit liens on assets;
•enter into certain contract years set forth in the EQT Global GGA, conditioned upon the in-service datetypes of the MVP, which provide for estimated aggregate fee relief of $270 million in the first year after the in-servicetransactions with affiliates;
•enter into burdensome agreements, subject to certain specified exceptions;
date
•enter into certain mergers or acquisitions; and
•dispose of the MVP, $230 million in the second year after the in-service dateall or substantially all of the MVP and $35 million in the third year after the in-service date of the MVP. In addition, if the MVP in-service date has not occurred by January 1, 2022, EQT has an option, exercisable for a period of twelve months, to forgo $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 us (through EQM) to EQT in the amount of approximately $196 million. Any further delay in the MVP in-service date may prevent us from achieving the anticipated benefits associated with the execution of the EQT Global GGA. their respective assets.
See "EQT Global GGA" in Note 68 to the consolidated financial statements for a discussion of the Amended EQM Credit Facility and the 2021 Eureka Credit Facility. 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, with the then-applicable ratio being tested as of the end of each fiscal quarter (which in limited circumstances may be increased for certain measurement periods following the consummation of certain acquisitions). Under the 2021 Eureka Credit Facility, Eureka is required to maintain a consolidated leverage ratio of not more than 4.75 to 1.00 (or not more than 5.25 to 1.00 for certain measurement periods following the consummation of certain acquisitions). If Eureka has issued senior notes of $200 million or more in the aggregate as of the end of any fiscal quarter, then for such fiscal quarter and for each fiscal quarter thereafter, Eureka is required to maintain a consolidated leverage ratio of not more than 5.25 to 1.00 and will not permit the ratio of senior indebtedness to four-quarter Consolidated EBITDA (as defined in the 2021 Eureka Credit Facility) as of the end of any such quarter to exceed 3.50 to 1.00. Additionally, as of the end of any fiscal quarter, Eureka may not permit the ratio of Consolidated EBITDA (as defined in the 2021 Eureka Credit Facility) for the four fiscal quarters then ending to consolidated interest charges 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 and the 2021 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 EQM Credit Facility and the 2021 Eureka Credit Facility each contain a cross default provision that applies to any other indebtedness the applicable borrower may have with an aggregate principal amount in excess of $25 million as to EQM, and $10 million as to Eureka.
We and our subsidiaries may in the future incur additional information.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 Hammerhead gathering agreementability to service our subsidiaries’ current, or our or our subsidiaries’ future, respective debts, will depend upon, among other things, our future financial and pipeline are the subject of a dispute with EQT and we mayoperating performance, which will be affected adversely by the pendencyprevailing 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 dispute and/as reducing dividends, reducing or if the dispute is resolved in a manner adversedelaying our business activities, acquisitions, investments or capital expenditures, selling assets or seeking additional equity capital. We may not be able to us.effect any of these actions on satisfactory terms or at all.
On September 23, 2020, EQTOur subsidiaries’ current substantial indebtedness and certain of its affiliates instituted arbitration proceedings against us relatingthe additional debt we and/or our subsidiaries will incur in the future for, among other things, working capital, capital expenditures, capital contributions to the Hammerhead gathering agreement, pursuant to which we agreed to construct the Hammerhead pipeline and related facilities and gather gas for EQT. See “Hammerhead Pipeline” under “Outlook” in “Item 2. Management’s Discussion and Analysis of Financial Condition and Results of Operations” for additional information. The dispute, during its pendency, couldMVP Joint Venture, acquisitions or operating activities may adversely affect our businessliquidity and operating results, including by causing ustherefore our ability to incur expenses in arbitration or additional proceedings in excesspay dividends to our shareholders.
In addition, if the dispute is resolved in a manner adverse to us, such resolutionour subsidiaries’ significant indebtedness may be viewed negatively by credit rating agencies, which could result in EQT’s acquisitionincreased costs for us to access the capital markets. Any future additional downgrade of Hammerhead assets in exchange for a reimbursement paymentthe debt issued by EQM could significantly increase our capital costs or otherwiseadversely affect or negate our ability to recognize revenue and generate operating cash flowsraise capital in the future from such assets.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 September 30, 2020:2021:
| | | | | | | | | | | | | | | | | | | | | | | | | | |
| Period | | Total number of shares purchased (a) | | Average price paid per share | | Total number of shares purchased as part of publicly announced plans or programs | | Approximate dollar value of shares that may yet be purchased under plans or programs |
| July 2020 (July 1 - July 31) | | 682 | | | $ | 8.28 | | | — | | | $ | — | |
| August 2020 (August 1 - August 31) | | — | | | — | | | — | | | — | |
| September 2020 (September 1 - September 30) | | — | | | — | | | — | | | — | |
| Total | | 682 | | | $ | 8.28 | | | — | | | $ | — | |
| | | | | | | | | | | | | | | | | | | | | | | | | | |
| Period | | Total number of shares purchased (a) | | Average price paid per share | | Total number of shares purchased as part of publicly announced plans or programs | | Approximate dollar value of shares that may yet be purchased under the plans or programs |
| July 2021 (July 1 - July 31) | | 65 | | | $ | 7.99 | | | — | | | $ | — | |
| August 2021 (August 1 - August 31) | | 26,771 | | | 8.35 | | | — | | | — | |
| September 2021 (September 1 - September 30) | | — | | | — | | | — | | | — | |
| Total | | 26,836 | | | $ | 8.35 | | | — | | | $ | — | |
(a)Reflects shares withheld by the Company to pay taxes upon vesting of restricted stock.
Item 6. Exhibits
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| Exhibit No. | | Document Description | | Method of Filing |
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| | First Amendment to Gas Gathering and CompressionLetter Agreement, dated as of August 26, 2020,July 10, 2021, by and among EQM Gathering Opco, LLC, EQT Corporation, EQT Production Company, Rice Drilling B LLC, and EQT Energy, LLC and EQM Gathering Opco, LLC. | | Filed herewith as Exhibit 10.1. |
| | Letter Agreement, dated as of August 25, 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 10.2. |
| | Letter Agreement, dated as of September 13, 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 10.3. |
| | Rule 13(a)-14(a) Certification of Principal Executive Officer. | | Filed herewith as Exhibit 31.1. |
| | Rule 13(a)-14(a) Certification of Principal Financial Officer. | | Filed herewith as Exhibit 31.2. |
| | Section 1350 Certification of Principal Executive Officer and Principal Financial Officer. | | Furnished herewith as Exhibit 32. |
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| 101 | | Inline Interactive Data File. | | Filed herewith as Exhibit 101. |
| 104 | | Cover Page Interactive Data File (formatted as Inline XBRL and contained in Exhibit 101). | | Filed herewith as Exhibit 104. |
# Certain portions of the exhibit that are not material and would be competitively harmful if publicly disclosed have been redacted pursuant to Item 601(b)(10)(iv) of Regulation S-K. A copy of the unredacted exhibit will be furnished to the SEC upon request. Omissions are designated with brackets containing asterisks.
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.
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| | Equitrans Midstream Corporation |
| | (Registrant) |
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| | By: | /s/ Kirk R. Oliver |
| | | Kirk R. Oliver |
| | | Senior Vice President and Chief Financial Officer |
Date: November 3, 20202, 2021