10-Q 1 eqt930201810q.htm 10-Q
Table of Contents
UNITED STATES
SECURITIES AND EXCHANGE COMMISSION
Washington, D.C. 20549
FORM 10-Q
(Mark One)

x | QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934
FOR THE QUARTERLY PERIOD ENDED SEPTEMBER 30, 2018

or

¨ | TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934
| FOR THE TRANSITION PERIOD FROM TO
| COMMISSION FILE NUMBER 001-03551

EQT CORPORATION
(Exact name of registrant as specified in its charter)

PENNSYLVANIA |  | 25-0464690
(State or other jurisdiction of incorporation or organization) |  | (IRS Employer Identification No.)
625 Liberty Avenue, Suite 1700, Pittsburgh, Pennsylvania |  | 15222
(Address of principal executive offices) |  | (Zip code)

(412) 553-5700
(Registrant’s telephone number, including area code)
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 x 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 x No ¨
Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer, a smaller reporting company, or an emerging growth company. See the definitions of “large accelerated filer,” “accelerated filer,” “smaller reporting company” and "emerging growth company" in Rule 12b-2 of the Exchange Act.

Large Accelerated Filer x |  |  | 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 x
As of September 30, 2018, 254,426 (in thousands) shares of common stock, no par value, of the registrant were outstanding.

Table of Contents
EQT CORPORATION AND SUBSIDIARIES
Index

|  | Page No.
Part I. Financial Information: |
Item 1. | Financial Statements (Unaudited): |
| Statements of Consolidated Operations for the Three and Nine Months Ended September 30, 2018 and 2017 | 3
| Statements of Consolidated Comprehensive Income for the Three and Nine Months Ended September 30, 2018 and 2017 | 4
| Statements of Condensed Consolidated Cash Flows for the Nine Months Ended September 30, 2018 and 2017 | 5
| Condensed Consolidated Balance Sheets as of September 30, 2018 and December 31, 2017 | 6
| Statements of Condensed Consolidated Equity for the Nine Months Ended September 30, 2018 and 2017 | 8
| Notes to the Condensed Consolidated Financial Statements | 9
Item 2. | Management’s Discussion and Analysis of Financial Condition and Results of Operations | 29
Item 3. | Quantitative and Qualitative Disclosures About Market Risk | 49
Item 4. | Controls and Procedures | 51
Part II. Other Information: |
Item 1. | Legal Proceedings | 52
Item 1A. | Risk Factors | 53
Item 2. | Unregistered Sales of Equity Securities and Use of Proceeds | 56
Item 6. | Exhibits | 57
Signature | 58

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PART I. FINANCIAL INFORMATION
Item 1. Financial Statements
EQT CORPORATION AND SUBSIDIARIES
Statements of Consolidated Operations (Unaudited)

| Three Months Ended September 30, |  | Nine Months Ended September 30,
| 2018 |  | 2017 |  | 2018 |  | 2017
| (Thousands, except per share amounts)
Revenues: |  |  |  |  |  |  |
Sales of natural gas, oil and NGLs | $ | 1,046,989 |  |  | $ | 552,953 |  |  | $ | 3,264,728 |  |  | $ | 1,803,132 |
Pipeline, water and net marketing services | 114,956 |  |  | 70,835 |  |  | 376,776 |  |  | 216,499 |
(Loss) gain on derivatives not designated as hedges | (3,075 | ) |  | 35,625 |  |  | 5,620 |  |  | 222,693 |
Total operating revenues | 1,158,870 |  |  | 659,413 |  |  | 3,647,124 |  |  | 2,242,324 |
Operating expenses: |  |  |  |  |  |  |  |  |  |  |
Transportation and processing | 186,407 |  |  | 136,219 |  |  | 576,597 |  |  | 404,743 |
Operation and maintenance | 29,892 |  |  | 19,589 |  |  | 82,218 |  |  | 54,721 |
Production | 42,751 |  |  | 39,513 |  |  | 149,471 |  |  | 129,461 |
Exploration | 15,772 |  |  | 2,436 |  |  | 42,058 |  |  | 9,039 |
Selling, general and administrative | 65,400 |  |  | 66,263 |  |  | 195,828 |  |  | 190,891 |
Depreciation and depletion | 435,311 |  |  | 246,560 |  |  | 1,290,876 |  |  | 719,295 |
Impairment/loss on sale of long-lived assets | 259,279 |  |  | — |  |  | 2,706,438 |  |  | — |
Transaction costs | 31,506 |  |  | 10,806 |  |  | 93,176 |  |  | 15,044 |
Amortization of intangible assets | 20,728 |  |  | — |  |  | 62,185 |  |  | — |
Total operating expenses | 1,087,046 |  |  | 521,386 |  |  | 5,198,847 |  |  | 1,523,194 |
Operating income (loss) | 71,824 |  |  | 138,027 |  |  | (1,551,723 | ) |  | 719,130 |
Other income | 21,755 |  |  | 6,526 |  |  | 43,092 |  |  | 15,880 |
Interest expense | 93,042 |  |  | 50,377 |  |  | 240,059 |  |  | 137,110 |
Income (loss) before income taxes | 537 |  |  | 94,176 |  |  | (1,748,690 | ) |  | 597,900 |
Income tax (benefit) expense | (62,911 | ) |  | (11,281 | ) |  | (503,505 | ) |  | 119,093 |
Net income (loss) | 63,448 |  |  | 105,457 |  |  | (1,245,185 | ) |  | 478,807 |
Less: Net income attributable to noncontrolling interests | 103,141 |  |  | 82,117 |  |  | 362,696 |  |  | 250,349 |
Net (loss) income attributable to EQT Corporation | $ | (39,693 | ) |  | $ | 23,340 |  |  | $ | (1,607,881 | ) |  | $ | 228,458 |
Earnings per share of common stock attributable to EQT Corporation: |  |  |  |  |  |  |  |  |  |  |
Basic: |  |  |  |  |  |  |  |  |  |  |
Weighted average common stock outstanding | 259,560 |  |  | 173,476 |  |  | 262,816 |  |  | 173,368 |
Net (loss) income | $ | (0.15 | ) |  | $ | 0.13 |  |  | $ | (6.12 | ) |  | $ | 1.32 |
Diluted: |  |  |  |  |  |  |  |  |  |  |
Weighted average common stock outstanding | 259,560 |  |  | 173,675 |  |  | 262,816 |  |  | 173,572 |
Net (loss) income | $ | (0.15 | ) |  | $ | 0.13 |  |  | $ | (6.12 | ) |  | $ | 1.32 |
Dividends declared per common share | $ | 0.03 |  |  | $ | 0.03 |  |  | $ | 0.09 |  |  | $ | 0.09 |

The accompanying notes are an integral part of these Condensed Consolidated Financial Statements.
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EQT CORPORATION AND SUBSIDIARIES
Statements of Consolidated Comprehensive (Loss) Income (Unaudited)

| Three Months Ended September 30, |  | Nine Months Ended September 30,
| 2018 |  | 2017 |  | 2018 |  | 2017
| (Thousands)
Net income (loss) | $ | 63,448 |  |  | $ | 105,457 |  |  | $ | (1,245,185 | ) |  | $ | 478,807 |
Other comprehensive income (loss), net of tax: |  |  |  |  |  |  |  |  |  |  |
Net change in cash flow hedges: |  |  |  |  |  |  |  |  |  |  |
Natural gas, net of tax benefit of $(150), $(955), $(413), and $(2,640) | (430 | ) |  | (1,451 | ) |  | (1,183 | ) |  | (4,011 | )
Interest rate, net of tax expense of $10, $26, $54, and $78 | 52 |  |  | 36 |  |  | 132 |  |  | 108 |
Other post-retirement benefits liability adjustment, net of tax expense of $29, $49, $89, and $148 | 86 |  |  | 77 |  |  | 258 |  |  | 230 |
Other comprehensive loss | (292 | ) |  | (1,338 | ) |  | (793 | ) |  | (3,673 | )
Comprehensive income (loss) | 63,156 |  |  | 104,119 |  |  | (1,245,978 | ) |  | 475,134 |
Less: Comprehensive income attributable to noncontrolling interests | 103,141 |  |  | 82,117 |  |  | 362,696 |  |  | 250,349 |
Comprehensive (loss) income attributable to EQT Corporation | $ | (39,985 | ) |  | $ | 22,002 |  |  | $ | (1,608,674 | ) |  | $ | 224,785 |

The accompanying notes are an integral part of these Condensed Consolidated Financial Statements.
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EQT CORPORATION AND SUBSIDIARIES
Statements of Condensed Consolidated Cash Flows (Unaudited)

| Nine Months Ended September 30,
| 2018 |  | 2017
| (Thousands)
Cash flows from operating activities: |
Net (loss) income | $ | (1,245,185 | ) |  | $ | 478,807 |
Adjustments to reconcile net (loss) income to net cash provided by operating activities: |  |  |  |  |
Deferred income taxes | (502,853 | ) |  | 121,704 |
Depreciation and depletion | 1,290,876 |  |  | 719,295 |
Amortization of intangibles | 62,185 |  |  | — |
Amortization of financing costs | 9,591 |  |  | — |
Asset and lease impairments | 2,742,022 |  |  | 5,053 |
Provision for (recoveries of) losses on accounts receivable | 9 |  |  | (1,230 | )
Other income | (43,092 | ) |  | (15,880 | )
Stock-based compensation expense | 23,137 |  |  | 27,894 |
Gain on derivatives not designated as hedges | (5,620 | ) |  | (222,693 | )
Cash settlements paid on derivatives not designated as hedges | (27,401 | ) |  | (6,837 | )
Changes in other assets and liabilities: |  |  |  |  |
Accounts receivable | (7,713 | ) |  | 64,057 |
Accounts payable | 205,360 |  |  | (15,446 | )
Other items, net | (55,926 | ) |  | 56,648 |
Net cash provided by operating activities | 2,445,390 |  |  | 1,211,372 |
Cash flows from investing activities: |  |  |  |  |
Capital expenditures | (2,854,670 | ) |  | (1,152,865 | )
Capital expenditures for acquisitions | — |  |  | (818,957 | )
Proceeds from Huron Divestiture (see Note Q) | 523,595 |  |  | — |
Sales of investments in trading securities | — |  |  | 283,758 |
Capital contributions to Mountain Valley Pipeline, LLC | (446,049 | ) |  | (103,448 | )
Proceeds from sale of Permian Basin assets | 57,664 |  |  | — |
Net cash used in investing activities | (2,719,460 | ) |  | (1,791,512 | )
Cash flows from financing activities: |  |  |  |  |
Proceeds from issuance of EQM Midstream Partners, LP (formerly known as EQT Midstream Partners, LP) Senior Notes | 2,500,000 |  |  | — |
Increase in borrowings on credit facilities | 6,219,500 |  |  | 334,000 |
Repayment of borrowings on credit facilities | (7,508,500 | ) |  | (229,000 | )
Dividends paid | (23,736 | ) |  | (15,620 | )
Distributions to noncontrolling interests | (279,539 | ) |  | (172,498 | )
Repayments and retirements of Senior Notes | (7,999 | ) |  | — |
Proceeds from awards under employee compensation plans | 1,946 |  |  | — |
Cash paid for taxes related to net settlement of share-based incentive awards | (21,910 | ) |  | (18,030 | )
Debt discount and issuance costs and revolving credit facility origination fees | (34,249 | ) |  | (13,679 | )
Acquisition of 25% of Strike Force Midstream LLC | (175,000 | ) |  | — |
Repurchase and retirement of common stock | (538,876 | ) |  | — |
Repurchase of common stock | (27 | ) |  | (15 | )
Net cash provided by (used in) financing activities | 131,610 |  |  | (114,842 | )
Net change in cash, cash equivalents and restricted cash | (142,460 | ) |  | (694,982 | )
Cash, cash equivalents and restricted cash at beginning of period | 147,315 |  |  | 1,178,540 |
Cash and cash equivalents at end of period | $ | 4,855 |  |  | $ | 483,558 |
Cash paid during the period for: |  |  |  |  |
Interest, net of amount capitalized | $ | 163,688 |  |  | $ | 113,618 |
Income taxes, net | $ | 193 |  |  | $ | 9,702 |

The accompanying notes are an integral part of these Condensed Consolidated Financial Statements.
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EQT CORPORATION AND SUBSIDIARIES
Condensed Consolidated Balance Sheets (Unaudited)

| September 30, 2018 |  | December 31, 2017
| (Thousands)
Assets |  |  |  |  |
Current assets: |  |  |  |  |
Cash and cash equivalents | $ | 4,855 |  |  | $ | 147,315 |
Accounts receivable (less accumulated provision for doubtful accounts: $8,235 at September 30, 2018 and $8,226 at December 31, 2017) | 882,386 |  |  | 725,236 |
Derivative instruments, at fair value | 315,564 |  |  | 241,952 |
Prepaid expenses and other | 31,853 |  |  | 48,552 |
Total current assets | 1,234,658 |  |  | 1,163,055 |
Property, plant and equipment | 28,022,769 |  |  | 30,990,309 |
Less: accumulated depreciation and depletion | 4,892,875 |  |  | 6,105,294 |
Net property, plant and equipment | 23,129,894 |  |  | 24,885,015 |
Intangible assets, net | 674,175 |  |  | 736,360 |
Goodwill | 1,998,726 |  |  | 1,998,726 |
Investment in nonconsolidated entity | 1,300,430 |  |  | 460,546 |
Other assets | 323,446 |  |  | 278,902 |
Total assets | $ | 28,661,329 |  |  | $ | 29,522,604 |

The accompanying notes are an integral part of these Condensed Consolidated Financial Statements.
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EQT CORPORATION AND SUBSIDIARIES
Condensed Consolidated Balance Sheets (Unaudited)

| September 30, 2018 |  | December 31, 2017
| (Thousands)
Liabilities and Shareholders’ Equity |  |  |  |  |
Current liabilities: |  |  |  |  |
Current portion of Senior Notes | $ | 699,527 |  |  | $ | 7,999 |
Accounts payable | 978,757 |  |  | 654,624 |
Derivative instruments, at fair value | 183,677 |  |  | 139,089 |
Other current liabilities | 784,115 |  |  | 430,525 |
Total current liabilities | 2,646,076 |  |  | 1,232,237 |
Credit facility borrowings | 472,000 |  |  | 1,761,000 |
Senior Notes | 7,336,570 |  |  | 5,562,555 |
Deferred income taxes | 1,212,867 |  |  | 1,768,900 |
Other liabilities and credits | 776,424 |  |  | 783,299 |
Total liabilities | 12,443,937 |  |  | 11,107,991 |
Equity: |  |  |  |  |
Shareholders’ equity: |  |  |  |  |
Common stock, no par value, authorized 320,000 shares, shares issued: 257,225 at September 30, 2018 and 267,871 at December 31, 2017 | 8,684,169 |  |  | 9,388,903 |
Treasury stock, shares at cost: 2,799 at September 30, 2018 (including 299 held in rabbi trust) and 3,551 at December 31, 2017 (including 253 held in rabbi trust) | (50,014 | ) |  | (63,602 | )
Retained earnings | 2,369,271 |  |  | 3,996,775 |
Accumulated other comprehensive loss | (3,251 | ) |  | (2,458 | )
Total common shareholders’ equity | 11,000,175 |  |  | 13,319,618 |
Noncontrolling interests in consolidated subsidiaries | 5,217,217 |  |  | 5,094,995 |
Total equity | 16,217,392 |  |  | 18,414,613 |
Total liabilities and equity | $ | 28,661,329 |  |  | $ | 29,522,604 |

The accompanying notes are an integral part of these Condensed Consolidated Financial Statements.
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EQT CORPORATION AND SUBSIDIARIES
Statements of Condensed Consolidated Equity (Unaudited)

| Common Stock |  |  |  | Accumulated Other Comprehensive Income (Loss) |  | Noncontrolling Interests in Consolidated Subsidiaries |  |
| Shares Outstanding |  | No Par Value |  | Retained Earnings |  |  |  | Total Equity
| (Thousands)
Balance, January 1, 2017 | 172,827 |  |  | $ | 3,349,166 |  |  | $ | 2,509,073 |  |  | $ | 2,042 |  |  | $ | 3,258,966 |  |  | $ | 9,119,247 |
Comprehensive income (net of tax): |  |  |  |  |  |  |  |  |  |  |
Net income |  |  |  |  |  |  | 228,458 |  |  |  |  |  | 250,349 |  |  | 478,807 |
Net change in cash flow hedges: |  |  |  |  |  |  |  |  |  |  |  |  |  |  |
Natural gas, net of tax benefit of $(2,640) |  |  |  |  |  |  | (4,011 | ) |  |  |  | (4,011 | )
Interest rate, net of tax expense of $78 |  |  |  |  |  |  | 108 |  |  |  |  | 108 |
Other post-retirement benefits liability adjustment, net of tax expense of $148 |  |  |  |  |  |  | 230 |  |  |  |  | 230 |
Dividends ($0.09 per share) |  |  |  |  |  |  | (15,620 | ) |  |  |  |  |  |  |  | (15,620 | )
Stock-based compensation plans, net | 516 |  |  | 18,224 |  |  |  |  |  |  |  |  | 190 |  |  | 18,414 |
Distributions to noncontrolling interests ($2.675 and $0.578 per common unit from EQM Midstream Partners, LP and EQGP Holdings, LP (formerly known as EQT GP Holdings, LP), respectively) |  |  |  |  |  |  |  |  |  |  |  |  | (172,498 | ) |  | (172,498 | )
Balance, September 30, 2017 | 173,343 |  |  | $ | 3,367,390 |  |  | $ | 2,721,911 |  |  | $ | (1,631 | ) |  | $ | 3,337,007 |  |  | $ | 9,424,677 |
Balance, January 1, 2018 | 264,320 |  |  | $ | 9,325,301 |  |  | $ | 3,996,775 |  |  | $ | (2,458 | ) |  | $ | 5,094,995 |  |  | $ | 18,414,613 |
Comprehensive income (net of tax): |  |  |  |  |  |  |  |  |  |  |
Net (loss) income |  |  |  |  |  |  | (1,607,881 | ) |  |  |  |  | 362,696 |  |  | (1,245,185 | )
Net change in cash flow hedges: |  |  |  |  |  |  |  |  |  |  |  |  |  |  |
Natural gas, net of tax benefit of $(413) |  |  |  |  |  |  | (1,183 | ) |  |  |  | (1,183 | )
Interest rate, net of tax expense of $54 |  |  |  |  |  |  | 132 |  |  |  |  | 132 |
Other post-retirement benefit liability adjustment, net of tax expense of $89 |  |  |  |  |  |  | 258 |  |  |  |  | 258 |
Dividends ($0.09 per share) |  |  |  |  |  |  | (23,736 | ) |  |  |  |  |  |  |  | (23,736 | )
Stock-based compensation plans, net | 752 |  |  | 4,472 |  |  |  |  |  |  |  |  | 953 |  |  | 5,425 |
Distributions to noncontrolling interests ($3.18, $0.808 and $0.5966 per common unit from EQM Midstream Partners, LP, EQGP Holdings, LP, and RM Partners LP (formerly known as Rice Midstream Partners LP), respectively) |  |  |  |  |  |  |  |  |  |  |  |  | (279,539 | ) |  | (279,539 | )
Change in accounting principle (a) |  |  |  |  | 4,113 |  |  |  |  |  |  | 4,113 |
Repurchase and retirement of common stock | (10,646 | ) |  | (538,876 | ) |  |  |  |  |  |  |  | (538,876 | )
Purchase of Strike Force Midstream LLC noncontrolling interests |  |  | 1,818 |  |  |  |  |  |  | (176,818 | ) |  | (175,000 | )
Change in ownership of consolidated subsidiaries |  |  | (158,560 | ) |  |  |  |  |  | 214,930 |  |  | 56,370 |
Balance, September 30, 2018 | 254,426 |  |  | $ | 8,634,155 |  |  | $ | 2,369,271 |  |  | $ | (3,251 | ) |  | $ | 5,217,217 |  |  | $ | 16,217,392 |

The accompanying notes are an integral part of these Condensed Consolidated Financial Statements.
(a) Related to adoption of ASU No. 2016-01. See Notes K and S for additional information.
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EQT Corporation and Subsidiaries
Notes to the Condensed Consolidated Financial Statements (Unaudited)
A. Financial Statements
The accompanying unaudited Condensed Consolidated Financial Statements have been prepared in accordance with United States generally accepted accounting principles (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 United States GAAP for complete financial statements. In the opinion of management, these statements include all adjustments (consisting of only normal recurring accruals, unless otherwise disclosed in this Quarterly Report on Form 10-Q) necessary for a fair presentation of the financial position of EQT Corporation and subsidiaries as of September 30, 2018 and December 31, 2017, the results of its operations for the three and nine month periods ended September 30, 2018 and 2017 and its cash flows and equity for the nine month periods ended September 30, 2018 and 2017. Certain previously reported amounts have been reclassified to conform to the current year presentation. In this Quarterly Report on Form 10-Q, references to “we,” “us,” “our,” “EQT,” “EQT Corporation,” and the “Company” refer collectively to EQT Corporation and its consolidated subsidiaries.
The balance sheet at December 31, 2017 has been derived from the audited financial statements at that date but does not include all of the information and footnotes required by GAAP for complete financial statements.
For further information, refer to the consolidated financial statements and related footnotes as well as “Management’s Discussion and Analysis of Financial Condition and Results of Operations” included in the Company’s Annual Report on Form 10-K for the year ended December 31, 2017.
During the third quarter of 2018, the Company repurchased 9,946,382 shares at an average price of $50.29 pursuant to the Company's previously announced $500 million share repurchase program. This exhausted the Company's share repurchase authorization under such program.
On November 13, 2017, the Company completed its previously announced acquisition of Rice Energy Inc. (Rice) pursuant to the Agreement and Plan of Merger, dated June 19, 2017 (as amended, the Rice Merger Agreement), by and among the Company, Rice and a wholly owned indirect subsidiary of the Company (RE Merger Sub). Pursuant to the terms of the Rice Merger Agreement, on November 13, 2017, RE Merger Sub merged with and into Rice (the Rice Merger) with Rice continuing as the surviving corporation and a wholly owned indirect subsidiary of the Company. Immediately thereafter, Rice merged with and into another wholly owned indirect subsidiary of the Company. As a result of the Rice Merger, the Company also acquired Rice's interests in RM Partners LP (formerly known as Rice Midstream Partners LP) (RMP). See Note E. The purchase price allocation for the Rice Merger remains preliminary as of September 30, 2018.
Unaudited Pro Forma Information
The following unaudited pro forma combined financial information presents the Company’s results as though the Rice Merger had been completed at January 1, 2017. The pro forma combined financial information has been included for comparative purposes and is not necessarily indicative of the results that might have actually occurred had the Rice Merger taken place on January 1, 2017; furthermore, the financial information is not intended to be a projection of future results.

(in thousands, except per share data) (unaudited) | Three Months Ended September 30, 2017 |  | Nine Months Ended September 30, 2017
Pro forma operating revenues | $ | 1,042,363 |  |  | $ | 3,491,790 |
Pro forma net income | $ | 120,301 |  |  | $ | 602,684 |
Pro forma net income attributable to noncontrolling interests | $ | (118,353 | ) |  | $ | (338,546 | )
Pro forma net income attributable to EQT | $ | 1,948 |  |  | $ | 264,138 |
Pro forma income per share (basic) | $ | 0.01 |  |  | $ | 1.00 |
Pro forma income per share (diluted) | $ | — |  |  | $ | 0.99 |

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EQT Corporation and Subsidiaries
Notes to Condensed Consolidated Financial Statements (Unaudited)
B. Midstream Streamlining Transactions and Financing
In February 2018, the Company's Board of Directors unanimously approved a plan to separate its upstream and midstream businesses, creating a standalone publicly traded corporation, Equitrans Midstream Corporation (Equitrans Midstream), which will focus on midstream operations (the Separation). Equitrans Midstream will own the midstream interests held by EQT. The Separation is intended to qualify as tax-free to EQT shareholders for U.S. federal income tax purposes. Under the Separation plan, EQT shareholders will retain their shares of the Company's stock and receive a pro-rata distribution of 80.1% of the outstanding shares of Equitrans Midstream common stock. In connection with announcing the planned Separation, the Company also announced its plans to pursue (i) a sale of Rice retained midstream assets acquired by EQT in connection with the Rice Merger to EQM Midstream Partners, LP (formerly known as EQT Midstream Partners, LP) (EQM) (NYSE: EQM), (ii) a merger of EQM and RMP, and (iii) a sale of RMP’s incentive distribution rights (RMP IDRs) to EQGP Holdings, LP (formerly known as EQT GP Holdings, LP) (EQGP) (NYSE: EQGP)((i), (ii) and (iii) collectively, the Midstream Streamlining Transactions).
On April 25, 2018, EQT, Rice Midstream Holdings LLC (Rice Midstream), a wholly owned subsidiary of the Company, EQM and EQM Gathering Holdings, LLC (EQM Gathering), a wholly owned subsidiary of EQM, entered into a contribution and sale agreement pursuant to which EQM Gathering agreed to acquire all the outstanding limited liability company interests in each of (i) EQM West Virginia Midstream Holdings LLC (formerly known as Rice West Virginia Midstream LLC) (Rice West Virginia), (ii) EQM Olympus Midstream LLC (formerly known as Rice Olympus Midstream LLC) (Rice Olympus) and (iii) Strike Force Midstream Holdings LLC (Strike Force Holdings), which owns a 75% limited liability company interest in Strike Force Midstream LLC (Strike Force Midstream), in exchange for an aggregate of 5,889,282 EQM common units and cash consideration of $1.15 billion, plus working capital adjustments (the Drop-Down Transaction). The Drop-Down Transaction was completed on May 22, 2018 with an effective date of May 1, 2018. In connection with the Drop-Down Transaction, the Company recorded a $15.5 million gain to additional paid-in-capital, a decrease in noncontrolling interest in consolidated subsidiary of $20.3 million and an increase to deferred tax liability of $4.8 million.
On May 1, 2018, pursuant to the Purchase and Sale Agreement dated April 25, 2018, by and among EQM, EQM Gathering, Gulfport Energy Corporation (Gulfport) and an affiliate of Gulfport, EQM Gathering acquired the remaining 25% limited liability company interest in Strike Force Midstream not owned by Strike Force Holdings for $175 million (the Gulfport Transaction). As a result, EQM has owned 100% of Strike Force Midstream since May 1, 2018.
On May 22, 2018, pursuant to an Incentive Distribution Rights Purchase and Sale Agreement dated April 25, 2018, by and among the Company, Rice Midstream GP Holdings LP (Rice Midstream GP Holdings), a wholly owned subsidiary of the Company that owned the RMP IDRs, and EQGP, EQGP acquired all of the issued and outstanding RMP IDRs in exchange for 36,293,766 EQGP common units (the RMP IDR Purchase). As a result of the RMP IDR Purchase, EQT's percentage ownership of the outstanding EQGP common units increased from approximately 90.1% to approximately 91.3%. In connection with the RMP IDR Purchase, the Company recorded a $35.1 million loss to additional paid-in-capital, an increase in noncontrolling interest in consolidated subsidiary of $46.1 million and a decrease to deferred tax liability of $11.0 million.
On April 25, 2018, EQM entered into an Agreement and Plan of Merger (the Midstream Merger Agreement) with RMP, EQM Midstream Management LLC (formerly known as Rice Midstream Management LLC), the general partner of RMP (the RMP General Partner), EQM Midstream Services, LLC (formerly known as EQT Midstream Services, LLC), the general partner of EQM (the EQM General Partner), EQM Acquisition Sub, LLC, a wholly owned subsidiary of EQM (Merger Sub), EQM GP Acquisition Sub, LLC, a wholly owned subsidiary of EQM (GP Merger Sub), and, solely for certain limited purposes set forth therein, the Company. Pursuant to the Midstream Merger Agreement, on July 23, 2018, Merger Sub and GP Merger Sub merged with and into RMP and the RMP General Partner, respectively, with RMP and the RMP General Partner surviving as wholly owned subsidiaries of EQM (the Midstream Mergers). Pursuant to the Midstream Merger Agreement, each of the RMP common units issued and outstanding immediately prior to the effective time of the Midstream Mergers was converted into the right to receive 0.3319 EQM common units (the Midstream Mergers Consideration), the issued and outstanding RMP IDRs were canceled and each outstanding award of phantom units in respect of RMP common units fully vested and converted into the right to receive the Midstream Mergers Consideration, less applicable tax withholding, in respect of each RMP common unit subject thereto. The aggregate Midstream Mergers Consideration consisted of approximately 34 million EQM common units. Following completion of the Midstream Mergers, RMP's common units ceased to be publicly traded. An indirect wholly owned subsidiary of the Company received 9,554,530 EQM common units as Midstream Mergers Consideration. In connection with the Midstream Mergers, the Company recorded a $138.8 million loss to additional paid-in capital, an increase in noncontrolling interest in consolidated subsidiary of $189.1 million and a decrease to deferred tax liability of approximately $50.3 million.
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Notes to Condensed Consolidated Financial Statements (Unaudited)
Also in connection with the completion of the Midstream Mergers, on July 23, 2018, EQM repaid approximately $260 million of borrowings outstanding under the Credit Agreement, dated as of December 22, 2014, by and among RMP, as parent guarantor, RM Operating LLC (formerly known as Rice Midstream OpCo LLC), a wholly owned subsidiary of RMP (RMP OpCo), as borrower, Wells Fargo Bank, N.A., as administrative agent, and the lenders and other parties from time to time party thereto (the RMP Credit Agreement), and the RMP Credit Agreement was terminated.
On April 25, 2018, EQM entered a $2.5 billion unsecured multi-draw 364-day term loan facility with a syndicate of lenders (the EQM Term Loan Facility). The EQM Term Loan Facility was used to fund the cash consideration for the Drop-Down Transaction, to repay borrowings under EQM’s $1 billion credit facility, and for other general partnership purposes. During the second quarter of 2018, the balance outstanding under the EQM Term Loan Facility was repaid, and the EQM Term Loan Facility was terminated on June 25, 2018 in connection with EQM's issuance of the EQM 2018 Senior Notes (described in the following section).
During the second quarter of 2018, EQM issued 4.75% senior notes due July 15, 2023 in the aggregate principal amount of $1.1 billion, 5.50% senior notes due July 15, 2028 in the aggregate principal amount of $850 million and 6.50% senior notes due July 15, 2048 in the aggregate principal amount of $550 million (collectively, the EQM 2018 Senior Notes). The offering of the EQM 2018 Senior Notes resulted in net proceeds of approximately $2,465.8 million, inclusive of a discount of $11.8 million and estimated debt issuance costs of $22.4 million. The net proceeds were used to repay the balance outstanding under the EQM Term Loan Facility and the RMP Credit Agreement and the remainder is expected to be used for general partnership purposes. The EQM 2018 Senior Notes were issued pursuant to new supplemental indentures to EQM's existing indenture dated August 1, 2014. The EQM 2018 Senior Notes contain 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 substantially all of EQM's assets.
C. EQGP Holdings, LP
In January 2015, the Company formed EQGP to own the Company's partnership interests in EQM. As of September 30, 2018, EQT owns 276,008,766 EQGP common units, which represent a 91.3% limited partner interest, and the entire non-economic general partner interest in EQGP. EQGP owned the following EQM partnership interests as of September 30, 2018, which represent EQGP’s only cash-generating assets: 21,811,643 EQM common units, representing a 17.9% limited partner interest in EQM; 1,443,015 EQM general partner units, representing a 1.2% general partner interest in EQM; and all of EQM’s incentive distribution rights (IDRs), which entitle EQGP to receive up to 48.0% of all incremental cash distributed in a quarter after $0.5250 has been distributed in respect of each common unit and general partner unit of EQM for that quarter. Through EQGP's general partner interest, limited partner interest and IDRs in EQM, EQGP has a controlling financial interest in EQM; therefore, EQGP consolidates EQM. The Company is the ultimate parent company of EQGP and EQM.
On October 23, 2018, the Board of Directors of EQGP's general partner declared a cash distribution to EQGP’s unitholders for the third quarter of 2018 of $0.315 per common unit, or approximately $95.3 million. The distribution will be paid on November 14, 2018 to unitholders of record, including the Company, at the close of business on November 2, 2018. Based on the EQGP common units outstanding on October 25, 2018, the cash distributions by EQGP to EQT for the third quarter 2018 will be approximately $87.0 million.
D. EQM Midstream Partners, LP
In January 2012, the Company formed EQM to own, operate, acquire and develop midstream assets in the Appalachian Basin. EQM provides midstream services to the Company and third parties. EQM is consolidated in the Company’s financial statements. The Company records the noncontrolling interest of the EQM public limited partners in its financial statements.
In addition to the EQM common units owned by EQGP, as of September 30, 2018, EQT owned 5,889,282 EQM common units representing an additional 6.7% limited partner interest in EQM.
On October 23, 2018, the Board of Directors of EQM's general partner declared a cash distribution to EQM’s unitholders for the third quarter of 2018 of $1.115 per common unit. The cash distribution will be paid on November 14, 2018 to unitholders of record, including EQGP, as of the close of business on November 2, 2018. Based on the EQM common units outstanding on October 25, 2018, the cash distributions by EQM to EQGP for the third quarter 2018 will be approximately $97.8 million consisting of: $24.3 million in respect of its limited partner interest, $2.5 million in respect of its general partner interest and $71.0 million in respect of its IDRs. The distribution amounts to EQGP related to its general partner interest and IDRs in EQM are subject to change if EQM issues additional common units on or prior to the record date for the third quarter 2018 distribution. Based on the EQM
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Notes to the Condensed Consolidated Financial Statements (Unaudited)
common units outstanding on October 25, 2018, the cash distributions by EQM to EQT for the third quarter 2018 will be approximately $17.2 million.
E. RM Partners LP
In connection with the Rice Merger, the Company acquired a 28.1% limited partner interest, all of the IDRs and the entire non-economic general partner interest in RMP. RMP's common units ceased to be publicly traded as a result of the Midstream Mergers. See the discussion of the RMP IDR Purchase and Midstream Mergers in Note B.
F. Revenue from Contracts with Customers
As discussed in Note S, the Company adopted Accounting Standard Update (ASU) No. 2014-09, Revenue from Contracts with Customers (Topic 606), on January 1, 2018 using the modified retrospective method of adoption. Adoption of the ASU did not require an adjustment to the opening balance of equity and did not materially change the Company's amount and timing of revenues. The Company applied the ASU only to contracts that were not completed as of January 1, 2018. The Company has elected to exclude all taxes from the measurement of transaction price.
For the sale of natural gas, oil and natural gas liquids (NGLs), the Company generally considers the delivery of each unit (MMBtu or Bbl) to be a separate performance obligation that is satisfied upon delivery. These contracts typically require payment within 25 days of the end of the calendar month in which the gas is delivered. A significant number of these contracts contain variable consideration because the payment terms refer to market prices at future delivery dates. In these situations, the Company has not identified a standalone selling price because the terms of the variable payments relate specifically to the Company’s efforts to satisfy the performance obligations. Other contracts contain fixed consideration (i.e. fixed price contracts or contracts with a fixed differential to New York Mercantile Exchange (NYMEX) or index prices). The fixed consideration is allocated to each performance obligation on a relative standalone selling price basis, which requires judgment from management. For these contracts, the Company generally concludes that the fixed price or fixed differentials in the contracts are representative of the standalone selling price.
Based on management’s judgment, the performance obligations for the sale of natural gas, oil and NGLs are satisfied at a point in time because the customer obtains control and legal title of the asset when the natural gas, oil or NGL is delivered to the designated sales point.
The sales of natural gas, oil and NGLs as presented on the Statements of Consolidated Operations represent the Company’s share of revenues net of royalties and excluding revenue interests owned by others. When selling natural gas, oil and NGLs on behalf of royalty owners or working interest owners, the Company is acting as an agent and thus reports the revenue on a net basis.
The Company provides gathering, transmission and storage services in two manners: firm service and interruptible service. Firm service contracts are typically long term and include firm reservation fees, which are fixed, monthly charges for the guaranteed reservation of pipeline or storage capacity. Volumetric based fees under firm contracts include usage fees and charges for actual volumes transported, gathered or stored in excess of firm contracted volume. Interruptible service contracts include volumetric based fees, which are charges for the volume of gas actually gathered, transported or stored and do not guarantee access to the pipeline or storage facility. These contracts can be short or long term. Firm and interruptible contracts are billed at the end of each calendar month, with payment typically due within 21 days.
Based on total projected contractual revenues and including contracts associated with expected future capacity from expansion projects that are not yet fully constructed but for which EQM has entered into firm contracts, EQM's firm gathering contracts and firm transmission and storage contracts had weighted average remaining terms of approximately 8 and 15 years, respectively, as of December 31, 2017.
Under a firm contract, the Company has a stand-ready obligation to provide the service over the life of the contract. The performance obligation for firm reservation fee revenue is satisfied over time as the pipeline capacity is made available to the customer. As such, the Company recognizes firm reservation fee revenue evenly over the contract period, using a time-elapsed output method to measure progress. The performance obligation for volumetric based fees under firm and interruptible contracts is generally satisfied upon the Company's monthly billing to the customer for actual volumes gathered, transported or stored during the month. The amount billed corresponds directly to the value of the Company’s performance to date as the customer obtains value as each volume is gathered, transported or stored.
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Notes to Condensed Consolidated Financial Statements (Unaudited)
Certain of EQM's gas gathering agreements are structured with minimum volume commitments (MVC), which specify minimum quantities for which a customer will be charged regardless of actual quantities gathered under the contract. Revenue is recognized for MVCs when the performance obligation has been met, which is the earlier of when the gas is gathered or when it is remote that the producer will be able to meet its MVC.
Water services revenues primarily represent fees charged by EQM for the delivery of fresh water to a customer at a specified delivery point. All of EQM’s water services revenues are generated pursuant to variable price per volume contracts with customers in the Appalachian Basin. For water services contracts, the only performance obligation in each contract is for EQM to provide water (usually a minimum daily volume) to the customer at any designated delivery point. This performance obligation is generally satisfied upon EQM’s monthly billing to the customer for the volume of water provided during the month. For water services arrangements, the customer is typically invoiced on a monthly basis with payment due 21 days after the receipt of the invoice.
Because the Company's performance obligations have been satisfied and an unconditional right to consideration exists as of the balance sheet date, the Company has recognized amounts due from contracts with customers of $488.7 million as accounts receivable within the Condensed Consolidated Balance Sheet.
The table below provides disaggregated information regarding the Company’s revenues, presented consistently with the Company’s segment reporting. Certain contracts that provide for the release of capacity that is not used to transport the Company’s produced volumes were deemed to be outside the scope of Revenue from Contracts with Customers. The cost of, and recoveries on, that capacity are reported within pipeline and net marketing services at EQT Production. Derivative contracts are also outside the scope of Revenue from Contracts with Customers.

Three Months Ended September 30, 2018 |  | Revenues from contracts with customers |  | Other sources of revenue |  | Total
|  | (Thousands)
Natural gas sales |  | $ | 931,976 |  |  | $ | — |  |  | $ | 931,976 |
NGLs sales |  | 106,621 |  |  | — |  |  | 106,621 |
Oil sales |  | 8,392 |  |  | — |  |  | 8,392 |
Sales of natural gas, oil and NGLs |  | $ | 1,046,989 |  |  | $ | — |  |  | $ | 1,046,989 |
Pipeline and net marketing services at EQT Production |  | $ | 2,605 |  |  | $ | 3,527 |  |  | $ | 6,132 |
EQM Gathering: |  |  |  |  |  |
Firm reservation fee revenues |  | 112,598 |  |  | — |  |  | 112,598 |
Volumetric based fee revenues: |  |  |  |  |  |
Usage fees under firm contracts |  | 8,661 |  |  | — |  |  | 8,661 |
Usage fees under interruptible contracts |  | 131,602 |  |  | — |  |  | 131,602 |
EQM Transmission: |  |  |  |  |  |
Firm reservation fee revenues |  | 82,669 |  |  | — |  |  | 82,669 |
Volumetric based fee revenues: |  |  |  |  |  |
Usage fees under firm contracts |  | 5,331 |  |  | — |  |  | 5,331 |
Usage fees under interruptible contracts |  | 1,350 |  |  | — |  |  | 1,350 |
Water services at EQM Water |  | 22,373 |  |  | — |  |  | 22,373 |
Intersegment eliminations |  | (255,760 | ) |  | — |  |  | (255,760 | )
Pipeline, water and net marketing services |  | $ | 111,429 |  |  | $ | 3,527 |  |  | $ | 114,956 |
Loss on derivatives not designated as hedges |  | $ | — |  |  | $ | (3,075 | ) |  | $ | (3,075 | )
Total operating revenues |  | $ | 1,158,418 |  |  | $ | 452 |  |  | $ | 1,158,870 |

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Notes to Condensed Consolidated Financial Statements (Unaudited)

Nine Months Ended September 30, 2018 |  | Revenues from contracts with customers |  | Other sources of revenue |  | Total
|  | (Thousands)
Natural gas sales |  | $ | 2,877,660 |  |  | $ | — |  |  | $ | 2,877,660 |
NGLs sales |  | 357,746 |  |  | — |  |  | 357,746 |
Oil sales |  | 29,322 |  |  | — |  |  | 29,322 |
Sales of natural gas, oil and NGLs |  | $ | 3,264,728 |  |  | $ | — |  |  | $ | 3,264,728 |
Pipeline and net marketing services at EQT Production |  | $ | 14,273 |  |  | $ | 28,109 |  |  | $ | 42,382 |
EQM Gathering: |  |  |  |  |  |
Firm reservation fee revenues |  | 334,233 |  |  | — |  |  | 334,233 |
Volumetric based fee revenues: |  |  |  |  |  |
Usage fees under firm contracts |  | 30,725 |  |  | — |  |  | 30,725 |
Usage fees under interruptible contracts |  | 366,482 |  |  | — |  |  | 366,482 |
EQM Transmission: |  |  |  |  |  |
Firm reservation fee revenues |  | 262,666 |  |  | — |  |  | 262,666 |
Volumetric based fee revenues: |  |  |  |  |  |
Usage fees under firm contracts |  | 13,981 |  |  | — |  |  | 13,981 |
Usage fees under interruptible contracts |  | 8,782 |  |  | — |  |  | 8,782 |
Water services at EQM Water |  | 93,438 |  |  | — |  |  | 93,438 |
Intersegment eliminations |  | (775,913 | ) |  | — |  |  | (775,913 | )
Pipeline, water and net marketing services |  | $ | 348,667 |  |  | $ | 28,109 |  |  | $ | 376,776 |
Gain on derivatives not designated as hedges |  | $ | — |  |  | $ | 5,620 |  |  | $ | 5,620 |
Total operating revenues |  | $ | 3,613,395 |  |  | $ | 33,729 |  |  | $ | 3,647,124 |

The following table includes the transaction price allocated to the Company's remaining performance obligations on all contracts with fixed consideration. The table excludes all contracts that qualified for the exception to the relative standalone selling price method. Gathering firm reservation fees and transmission and storage firm reservation fees include amounts related to affiliate contracts.

| 2018 (a) | 2019 | 2020 | 2021 | 2022 | Thereafter | Total
| (Thousands)
Natural gas sales | $ | 20,173 |  | $ | 32,322 |  | $ | 1,237 |  | $ | — |  | $ | — |  | $ | — |  | $ | 53,732 |
Gathering firm reservation fees | $ | 114,771 |  | $ | 481,425 |  | $ | 557,352 |  | $ | 567,351 |  | $ | 566,062 |  | $ | 2,834,111 |  | $ | 5,121,072 |
Gathering revenues supported by MVCs | $ | — |  | $ | 65,700 |  | $ | 71,370 |  | $ | 71,175 |  | $ | 71,175 |  | $ | 136,875 |  | $ | 416,295 |
Transmission and storage firm reservation fees | $ | 94,077 |  | $ | 346,893 |  | $ | 344,328 |  | $ | 339,588 |  | $ | 334,522 |  | $ | 2,477,808 |  | $ | 3,937,216 |

(a) October 1 through December 31.
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Notes to Condensed Consolidated Financial Statements (Unaudited)
G. Investment in Nonconsolidated Entity
The Mountain Valley Pipeline, LLC (MVP Joint Venture) is constructing the Mountain Valley Pipeline (MVP), an estimated 300-mile natural gas interstate pipeline spanning from northern West Virginia to southern Virginia. EQM is the operator of the MVP and owned a 45.5% interest in the MVP Joint Venture as of September 30, 2018. 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. EQM is not the primary beneficiary because it does not have the power to direct the activities of the MVP Joint Venture that most significantly impact its economic performance. Certain business decisions require the approval of owners holding more than a 66 2/3% interest in the MVP Joint Venture and no one member owns more than a 66 2/3% interest. The MVP Joint Venture is an equity method investment for accounting purposes as EQM has the ability to exercise significant influence over operating and financial policies of the MVP Joint Venture. As currently designed, the MVP is estimated to cost a total of approximately $4.6 billion, excluding Allowance for Funds Used During Construction (AFUDC), with EQM funding approximately $2.2 billion through capital contributions made to the MVP Joint Venture, which includes approximately $65 million in excess of EQM's ownership interest. In 2018, EQM expects to provide capital contributions of $0.8 billion to $1.0 billion to the MVP Joint Venture.
In September 2018, the MVP Joint Venture issued a capital call notice to MVP Holdco, LLC (MVP Holdco), a direct wholly owned subsidiary of EQM, for $456.0 million, of which $175.2 million was paid as of October 2018, and $280.8 million is expected to be paid in the fourth quarter of 2018. In addition, in September 2018, the MVP Joint Venture issued a capital call notice to MVP Holdco for $7.7 million for funding of the MVP Southgate project that is expected to be paid in the fourth quarter of 2018. The capital contribution payables have been reflected on the Condensed Consolidated Balance Sheet as of September 30, 2018 with corresponding increases to the Company's investment in the MVP Joint Venture.
Equity income is EQM's portion of the MVP Joint Venture's AFUDC on construction of the MVP.
As of September 30, 2018, EQM had issued a $91 million performance guarantee in favor of the MVP Joint Venture. The guarantee provides performance assurances of MVP Holdco's obligations to fund its proportionate share of the MVP construction budget. As of September 30, 2018, EQM's maximum financial statement exposure related to the MVP Joint Venture was approximately $1,391 million, which consists of the investment in nonconsolidated entity balance on the Condensed Consolidated Balance Sheet as of September 30, 2018 and amounts that could have become due under EQM's performance guarantee as of that date. Following the completion of the Separation, EQM expects the MVP Joint Venture guarantee will be approximately $345 million based on MVP Holdco's share of the estimated remaining MVP construction budget and terms of the agreement.
In April 2018, the MVP Joint Venture announced the MVP Southgate project, a proposed 70-mile interstate pipeline that will extend from the MVP at Pittsylvania County, Virginia to new delivery points in Rockingham and Alamance Counties, North Carolina. This MVP Southgate project is anchored by a firm capacity commitment from PSNC Energy. The preliminary MVP Southgate project cost estimate is $350 million to $500 million, which is expected to be spent in 2019 and 2020. As of September 30, 2018, EQM had a 32.7% ownership interest in the MVP Southgate project and will operate the pipeline. Subject to approval by the FERC, the MVP Southgate project has a targeted in-service date of the fourth quarter 2020.
H. Consolidated Variable Interest Entities
As of September 30, 2018, the Company determined EQGP and EQM to be variable interest entities. In addition, as of December 31, 2017, RMP was also a variable interest entity. As discussed in Note B, on July 23, 2018, pursuant to the Midstream Merger Agreement, RMP and RMP's general partner were acquired by EQM and became wholly owned subsidiaries of EQM. Through EQT's ownership and control of EQGP's general partner, EQM's general partner and RMP's general partner, EQT has or had the power to direct the activities that most significantly impact the economic performance of EQGP, EQM and RMP. In addition, through EQT's limited partner interest in EQGP and EQGP's general partner interest, limited partner interest and IDRs in EQM, EQT has the obligation to absorb the losses of EQGP and EQM and the right to receive benefits from EQGP and EQM, in accordance with such interests. Furthermore, through EQT's limited partner interest and IDRs in RMP, EQT had the obligation to absorb the losses of RMP and the right to receive benefits from RMP, in accordance with such interests. As EQT has or had a controlling financial interest in, and is the primary beneficiary of, EQGP, EQM and RMP, EQT consolidates EQGP, EQM and did consolidate RMP. See Note 13 to the Consolidated Financial Statements in the Company’s Annual Report on Form 10-K for the year ended December 31, 2017 for additional information related to the consolidated variable interest entities.
The risks associated with the operations of EQGP, EQM and RMP are discussed in their respective Annual Reports on Form 10-K for the year ended December 31, 2017, as updated by any Quarterly Reports on Form 10-Q. See further discussion of the impact that EQT's ownership and control of EQGP, EQM and RMP have or had on EQT's financial position, results of operations and
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Notes to Condensed Consolidated Financial Statements (Unaudited)
cash flows included in EQT's Annual Report on Form 10-K for the year ended December 31, 2017, including in the section captioned "Management's Discussion and Analysis of Financial Condition and Results of Operations." See Notes C, D and E for further discussion of EQGP, EQM and RMP, respectively.
The following table presents amounts included in the Company's Condensed Consolidated Balance Sheets that were for the use or obligation of EQGP or EQM as of September 30, 2018 and December 31, 2017.

Classification |  | September 30, 2018 |  | December 31, 2017
|  | (Thousands)
Assets: |  |  |  |  |  |
Cash and cash equivalents |  | $ | 6,062 |  |  | $ | 2,857 |
Accounts receivable |  | 58,358 |  |  | 28,804 |
Prepaid expenses and other |  | 4,798 |  |  | 8,470 |
Property, plant and equipment, net |  | 5,608,358 |  |  | 2,804,059 |
Goodwill |  | 1,384,872 |  |  | — |
Intangible assets, net |  | 586,500 |  |  | — |
Investment in nonconsolidated entity |  | 1,300,430 |  |  | 460,546 |
Other assets |  | 23,599 |  |  | 22,458 |
Liabilities: |  |  |  |
Accounts payable |  | $ | 134,027 |  |  | $ | 47,042 |
Other current liabilities |  | 526,299 |  |  | 133,531 |
Credit facility borrowings |  | 22,000 |  |  | 180,000 |
Senior Notes |  | 3,455,296 |  |  | 987,352 |
Other liabilities and credits |  | 31,010 |  |  | 20,273 |

The following table summarizes EQGP's Statements of Consolidated Operations and Cash Flows for the three and nine months ended September 30, 2018 and 2017.

|  | Three Months Ended September 30, |  | Nine Months Ended September 30,
|  | 2018 |  | 2017 |  | 2018 |  | 2017
|  | (Thousands)
Operating revenues |  | $ | 364,584 |  |  | $ | 207,193 |  |  | $ | 1,110,307 |  |  | $ | 609,585 |
Operating expenses |  | 133,665 |  |  | 62,230 |  |  | 370,880 |  |  | 180,218 |
Other expenses |  | 23,534 |  |  | 2,556 |  |  | 37,632 |  |  | 6,418 |
Net income |  | $ | 207,385 |  |  | $ | 142,407 |  |  | $ | 701,795 |  |  | $ | 422,949 |
Net cash provided by operating activities |  | $ | 422,938 |  |  | $ | 159,911 |  |  | $ | 863,009 |  |  | $ | 479,566 |
Net cash used in investing activities |  | (575,624 | ) |  | (117,637 | ) |  | (2,252,293 | ) |  | (324,936 | )
Net cash (used in) provided by financing activities |  | (536,246 | ) |  | (48,128 | ) |  | 1,340,446 |  |  | (208,150 | )

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Notes to Condensed Consolidated Financial Statements (Unaudited)
The following table presents amounts included in the Company’s Condensed Consolidated Balance Sheet that is for the use or obligation of RMP as of December 31, 2017.

Classification |  | December 31, 2017
|  | (Thousands)
Assets: |  |  |
Cash and cash equivalents |  | $ | 10,538 |
Accounts receivable |  | 12,246 |
Prepaid expenses and other |  | 1,327 |
Property, plant and equipment, net |  | 1,431,802 |
Goodwill |  | 1,346,918 |
Liabilities: |  |
Accounts payable |  | $ | 24,634 |
Other current liabilities |  | 4,200 |
Credit facility borrowings |  | 286,000 |
Other liabilities and credits |  | 9,360 |

I. Financial Information by Business Segment
Prior to the Rice Merger, the Company reported its results of operations through three business segments: EQT Production, EQT Gathering and EQT Transmission. These reporting segments reflected the Company's lines of business and were reported in the same manner in which the Company evaluated its operating performance through September 30, 2017. Following the Rice Merger, the Company adjusted its internal reporting structure to incorporate the newly acquired assets. The Company conducted its business through five business segments: EQT Production, EQM Gathering (formerly known as EQT Gathering), EQM Transmission (formerly known as EQT Transmission), RMP Gathering and RMP Water. On July 23, 2018, pursuant to the Midstream Merger Agreement, RMP and the RMP General Partner each became wholly owned subsidiaries of EQM as a result of the Midstream Mergers. The Company now conducts its business through four business segments: EQT Production, EQM Gathering, EQM Transmission and EQM Water.
Rice Olympus, Strike Force Holdings and Rice West Virginia were businesses and the Drop-Down Transaction was a transaction between entities under common control; therefore, EQM recorded the assets and liabilities of these entities at their carrying amounts to EQT on the effective date of the transaction. EQM also recast its consolidated financial statements to retrospectively reflect the pre-acquisition results as if the entities were owned by EQM from the date of the Rice Merger, November 13, 2017, as that is the date those entities came under the common control of EQT.
In addition, the assets associated with the investment in the MVP Joint Venture were included within the headquarters segment assets balance prior to June 30, 2018. The investment in the MVP Joint Venture is now included in the transmission segment as this segment classification better aligns with the ultimate operations of the MVP. Segment asset balances at December 31, 2017 have been reclassified to conform to this presentation.

Three Months Ended September 30, 2018 | EQT Production |  | EQM Gathering |  | EQM Transmission |  | EQM Water |  | Intersegment Eliminations |  | EQT Corporation
Revenues: | (Thousands)
Sales of natural gas, oil and NGLs | $ | 1,046,989 |  |  | $ | — |  |  | $ | — |  |  | $ | — |  |  | $ | — |  |  | $ | 1,046,989 |
Pipeline, water and net marketing services | 6,132 |  |  | 252,861 |  |  | 89,350 |  |  | 22,373 |  |  | (255,760 | ) |  | 114,956 |
Loss on derivatives not designated as hedges | (3,075 | ) |  | — |  |  | — |  |  | — |  |  | — |  |  | (3,075 | )
Total operating revenues | $ | 1,050,046 |  |  | $ | 252,861 |  |  | $ | 89,350 |  |  | $ | 22,373 |  |  | $ | (255,760 | ) |  | $ | 1,158,870 |

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Notes to the Condensed Consolidated Financial Statements (Unaudited)

Three Months Ended September 30, 2017 | EQT Production |  | EQM Gathering |  | EQM Transmission |  | Intersegment Eliminations |  | EQT Corporation
Revenues: | (Thousands)
Sales of natural gas, oil and NGLs | $ | 552,953 |  |  | $ | — |  |  | $ | — |  |  | $ | — |  |  | $ | 552,953 |
Pipeline and net marketing services | 9,140 |  |  | 116,522 |  |  | 89,771 |  |  | (144,598 | ) |  | 70,835 |
Gain on derivatives not designated as hedges | 35,625 |  |  | — |  |  | — |  |  | — |  |  | 35,625 |
Total operating revenues | $ | 597,718 |  |  | $ | 116,522 |  |  | $ | 89,771 |  |  | $ | (144,598 | ) |  | $ | 659,413 |

Nine Months Ended September 30, 2018 | EQT Production |  | EQM Gathering |  | EQM Transmission |  | EQM Water |  | Intersegment Eliminations |  | EQT Corporation
Revenues: | (Thousands)
Sales of natural gas, oil and NGLs | $ | 3,264,728 |  |  | $ | — |  |  | $ | — |  |  | $ | — |  |  | $ | — |  |  | $ | 3,264,728 |
Pipeline and net marketing services | 42,382 |  |  | 731,440 |  |  | 285,429 |  |  | 93,438 |  |  | (775,913 | ) |  | 376,776 |
Gain on derivatives not designated as hedges | 5,620 |  |  | — |  |  | — |  |  | — |  |  | — |  |  | 5,620 |
Total operating revenues | $ | 3,312,730 |  |  | $ | 731,440 |  |  | $ | 285,429 |  |  | $ | 93,438 |  |  | $ | (775,913 | ) |  | $ | 3,647,124 |

Nine Months Ended September 30, 2017 | EQT Production |  | EQM Gathering |  | EQM Transmission |  | Intersegment Eliminations |  | EQT Corporation
Revenues: | (Thousands)
Sales of natural gas, oil and NGLs | $ | 1,803,132 |  |  | $ | — |  |  | $ | — |  |  | $ | — |  |  | $ | 1,803,132 |
Pipeline and net marketing services | 31,656 |  |  | 330,996 |  |  | 272,184 |  |  | (418,337 | ) |  | 216,499 |
Gain on derivatives not designated as hedges | 222,693 |  |  | — |  |  | — |  |  | — |  |  | 222,693 |
Total operating revenues | $ | 2,057,481 |  |  | $ | 330,996 |  |  | $ | 272,184 |  |  | $ | (418,337 | ) |  | $ | 2,242,324 |

| Three Months Ended September 30, |  | Nine Months Ended September 30,
| 2018 |  | 2017 |  | 2018 |  | 2017
| (Thousands)
Operating income (loss): |  |  |  |  |  |  |  |  |
EQT Production (a) | $ | (121,678 | ) |  | $ | 12,201 |  |  | $ | (2,127,323 | ) |  | $ | 322,634 |
EQM Gathering | 177,902 |  |  | 85,932 |  |  | 510,755 |  |  | 243,061 |
EQM Transmission | 58,691 |  |  | 59,770 |  |  | 198,784 |  |  | 189,237 |
EQM Water | (3,093 | ) |  | — |  |  | 35,627 |  |  | — |
Unallocated expenses and intersegment eliminations (b) | (39,998 | ) |  | (19,876 | ) |  | (169,566 | ) |  | (35,802 | )
Total operating income (loss) | $ | 71,824 |  |  | $ | 138,027 |  |  | $ | (1,551,723 | ) |  | $ | 719,130 |

(a) | Impairment of long-lived assets of $0.3 billion and $2.7 billion are included in EQT Production operating income for the three and nine months ended September 30, 2018, respectively. See Note Q.

(b) | Unallocated expenses consist of compensation expense, administrative costs and the amortization expense related to non-compete agreements with former Rice executives. Administrative costs include transaction costs of $29.3 million and $85.7 million for the three and nine months ended September 30, 2018, respectively. Amortization expense related to non-compete agreements with former Rice executives was $10.4 million and $31.0 million for the three and nine months ended September 30, 2018, respectively.

Intersegment eliminations include the elimination of profit on water services that are provided to EQT Production and capitalized as part of development costs of $3.2 million and $50.7 million for the three and nine months ended September 30, 2018, respectively.
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Notes to the Condensed Consolidated Financial Statements (Unaudited)
Reconciliation of operating income (loss) to net income (loss):

| Three Months Ended September 30, |  | Nine Months Ended September 30,
| 2018 |  | 2017 |  | 2018 |  | 2017
| (Thousands) |  |  |  |
Total operating income (loss) | $ | 71,824 |  |  | $ | 138,027 |  |  | $ | (1,551,723 | ) |  | $ | 719,130 |
Other income | 21,755 |  |  | 6,526 |  |  | 43,092 |  |  | 15,880 |
Interest expense | 93,042 |  |  | 50,377 |  |  | 240,059 |  |  | 137,110 |
Income tax (benefit) expense | (62,911 | ) |  | (11,281 | ) |  | (503,505 | ) |  | 119,093 |
Net income (loss) | $ | 63,448 |  |  | $ | 105,457 |  |  | $ | (1,245,185 | ) |  | $ | 478,807 |

| September 30, 2018 |  | December 31, 2017
| (Thousands)
Segment assets: |  |  |  |  |
EQT Production | $ | 19,278,308 |  |  | $ | 21,015,132 |
EQM Gathering | 5,994,891 |  |  | 5,681,404 |
EQM Transmission | 2,813,644 |  |  | 1,923,427 |
EQM Water | 141,403 |  |  | 185,079 |
Total operating segments | 28,228,246 |  |  | 28,805,042 |
Headquarters assets, including cash and short-term investments | 433,083 |  |  | 717,562 |
Total assets | $ | 28,661,329 |  |  | $ | 29,522,604 |

| Three Months Ended September 30, |  | Nine Months Ended September 30,
| 2018 |  | 2017 |  | 2018 |  | 2017
| (Thousands)
Depreciation and depletion: (c) |  |  |  |  |  |  |  |  |
EQT Production | $ | 391,083 |  |  | $ | 224,103 |  |  | $ | 1,161,718 |  |  | $ | 654,411 |
EQM Gathering | 25,359 |  |  | 9,983 |  |  | 72,309 |  |  | 28,398 |
EQM Transmission | 12,357 |  |  | 12,261 |  |  | 37,228 |  |  | 35,793 |
EQM Water | 5,851 |  |  | — |  |  | 17,420 |  |  | — |
Other | 661 |  |  | 213 |  |  | 2,201 |  |  | 693 |
Total | $ | 435,311 |  |  | $ | 246,560 |  |  | $ | 1,290,876 |  |  | $ | 719,295 |
Expenditures for segment assets: (d) |  |  |  |  |  |  |  |  |
EQT Production (e) | $ | 855,494 |  |  | $ | 449,303 |  |  | $ | 2,225,435 |  |  | $ | 1,850,482 |
EQM Gathering | 194,477 |  |  | 48,182 |  |  | 515,072 |  |  | 150,728 |
EQM Transmission | 37,626 |  |  | 22,312 |  |  | 84,517 |  |  | 73,679 |
EQM Water | 7,981 |  |  | — |  |  | 17,358 |  |  | — |
Other and intersegment eliminations (f) | 10,284 |  |  | 2,502 |  |  | (32,864 | ) |  | 7,097 |
Total | $ | 1,105,862 |  |  | $ | 522,299 |  |  | $ | 2,809,518 |  |  | $ | 2,081,986 |

(c) | Excludes amortization of intangible assets.

(d) | Includes the capitalized portion of non-cash stock-based compensation costs, non-cash acquisitions and the impact of capital accruals. The impact of accrued capital expenditures includes the reversal of the prior period accrual as well as the current period estimate, both of which are non-cash items. The net impact of these non-cash items was $(51.8) million and $44.3 million for the three months ended September 30, 2018 and 2017, respectively, and $(45.2) million and $102.7 million for the nine months ended September 30, 2018 and 2017, respectively. These non-cash items are excluded from capital expenditures on the Statements of Condensed Consolidated Cash Flows. Expenditures for segment assets does not include consideration for the Rice Merger.

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Notes to the Condensed Consolidated Financial Statements (Unaudited)

(e) | The three and nine months ended September 30, 2017 included $7.8 million and $819.0 million of cash capital expenditures, respectively, and the nine months ended September 30, 2017 included $7.5 million of non-cash capital expenditures for the acquisitions discussed in Note P.

(f) | Intersegment eliminations include profit on water services that are provided to EQT Production and capitalized as part of development costs.

J. Derivative Instruments
The Company’s primary market risk exposure is the volatility of future prices for natural gas and NGLs, which can affect the operating results of the Company primarily at EQT Production. The Company’s overall objective in its hedging program is to protect cash flows from undue exposure to the risk of changing commodity prices.
The Company primarily uses over the counter (OTC) derivative commodity instruments, primarily swap, collar and option agreements that are typically placed with financial institutions. The creditworthiness of all counterparties is regularly monitored. Swap agreements involve payments to or receipts from counterparties based on the differential between two prices for the commodity. Collar agreements require the counterparty to pay the Company if the index price falls below the floor price and the Company to pay the counterparty if the index price rises above the cap price. The Company sells call options that require the Company to pay the counterparty if the index price rises above the strike price and purchases call options that require the counterparty to pay the Company if the index price rises above the strike price. The Company engages in basis swaps to protect earnings from undue exposure to the risk of geographic disparities in commodity prices and interest rate swaps to hedge exposure to fluctuations in interest rates. The Company also engages in a limited number of swaptions.
The Company recognizes all derivative instruments as either assets or liabilities at fair value on a gross basis. These derivative instruments are reported as either current assets or current liabilities due to their highly liquid nature. The Company can net settle its derivative instruments at any time.
The Company discontinued cash flow hedge accounting in 2014; therefore, all changes in fair value of the Company’s derivative instruments are recognized within operating revenues in the Statements of Consolidated Operations.
In connection with the Rice Merger, the Company assumed all outstanding derivative commodity instruments held by Rice. The assets and liabilities assumed were recognized at fair value at the closing date and subsequent changes in fair value were recognized within operating revenues in the Statements of Consolidated Operations. The derivative commodity instruments assumed were substantially similar to instruments previously held by the Company.
Contracts which result in physical delivery of a commodity expected to be used or sold by the Company in the normal course of business are designated as normal purchases and sales and are exempt from derivative accounting.
OTC arrangements require settlement in cash. The Company also enters into exchange traded derivative commodity instruments that are generally settled with offsetting positions. Settlements of derivative commodity instruments are reported as a component of cash flows from operations in the accompanying Statements of Condensed Consolidated Cash Flows.
With respect to the derivative commodity instruments held by the Company, the Company hedged portions of expected sales of equity production and portions of its basis exposure covering approximately 3,005 Bcf of natural gas and 2,058 Mbbls of NGLs as of September 30, 2018, and 2,148 Bcf of natural gas and 1,460 Mbbls of NGLs as of December 31, 2017. The open positions at September 30, 2018 and December 31, 2017 had maturities extending through December 2024 and December 2022, respectively.
The Company has netting agreements with financial institutions and its brokers that permit net settlement of gross commodity derivative assets against gross commodity derivative liabilities. The table below reflects the impact of netting agreements and margin deposits on gross derivative assets and liabilities as of September 30, 2018 and December 31, 2017. The margin deposit within the table as of September 30, 2018 represents funds remitted to a broker for exchange traded derivative commodity instruments.
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As of September 30, 2018 |  | Derivative instruments, recorded in the Condensed Consolidated Balance Sheet, gross |  | Derivative instruments subject to master netting agreements |  | Margin deposits remitted to counterparties |  | Derivative instruments, net
|  | (Thousands)
Asset derivatives: |  |  |  |  |  |  |  |  |  |  |  |
Derivative instruments, at fair value |  | $ | 315,564 |  |  | $ | (104,559 | ) |  | $ | — |  |  | $ | 211,005 |
Liability derivatives: |  |  |  |  |  |  |  |  |  |
Derivative instruments, at fair value |  | $ | 183,677 |  |  | $ | (104,559 | ) |  | $ | (11,110 | ) |  | $ | 68,008 |

As of December 31, 2017 |  | Derivative instruments, recorded in the Condensed Consolidated Balance Sheet, gross |  | Derivative instruments subject to master netting agreements |  | Margin deposits remitted to counterparties |  | Derivative instruments, net
|  | (Thousands)
Asset derivatives: |  |  |  |  |  |  |  |  |  |  |  |
Derivative instruments, at fair value |  | $ | 241,952 |  |  | $ | (86,856 | ) |  | $ | — |  |  | $ | 155,096 |
Liability derivatives: |  |  |  |  |  |  |  |  |  |  |  |
Derivative instruments, at fair value |  | $ | 139,089 |  |  | $ | (86,856 | ) |  | $ | — |  |  | $ | 52,233 |

Certain of the Company’s OTC derivative instrument contracts provide that if the Company’s credit ratings by Standard & Poor’s Rating Service (S&P) or Moody’s Investors Service (Moody’s) are lowered below investment grade, additional collateral must be deposited with the counterparty if the amounts outstanding on those contracts exceed certain thresholds. The additional collateral can be up to 100% of the derivative liability. As of September 30, 2018, the aggregate fair value of all derivative instruments with credit risk-related contingent features that were in a net liability position was $109.2 million, for which the Company had no collateral posted on September 30, 2018. If the Company’s credit rating by S&P or Moody’s had been downgraded below investment grade on September 30, 2018, the Company would not have been required to post any additional collateral under the agreements with the respective counterparties. The required margin on the Company’s derivative instruments is subject to significant change as a result of factors other than credit rating, such as gas prices and credit thresholds set forth in agreements between the hedging counterparties and the Company. Investment grade refers to the quality of the Company’s credit as assessed by one or more credit rating agencies. The Company’s senior unsecured debt was rated BBB by S&P and Baa3 by Moody’s at September 30, 2018. In order to be considered investment grade, the Company must be rated BBB- or higher by S&P and Baa3 or higher by Moody’s. Anything below these ratings is considered non-investment grade. See also "Security Ratings and Financing Triggers" under Part I, Item 2, "Management's Discussion and Analysis of Financial Condition and Results of Operations."
K. Fair Value Measurements
The Company records its financial instruments, principally derivative instruments, at fair value in its Condensed Consolidated Balance Sheets. The Company estimates the fair value using quoted market prices, where available. If quoted market prices are not available, fair value is based upon models that use market-based parameters as inputs, including forward curves, discount rates, volatilities and nonperformance risk. Nonperformance risk considers the effect of the Company’s credit standing on the fair value of liabilities and the effect of the counterparty’s credit standing on the fair value of assets. The Company estimates nonperformance risk by analyzing publicly available market information, including a comparison of the yield on debt instruments with credit ratings similar to the Company’s or counterparty’s credit rating and the yield of a risk-free instrument and credit default swaps rates where available.
The Company has categorized its assets and liabilities recorded at fair value into a three-level fair value hierarchy, based on the priority of the inputs to the valuation technique. The fair value hierarchy gives the highest priority to quoted prices in active markets for identical assets and liabilities (Level 1) and the lowest priority to unobservable inputs (Level 3). Assets and liabilities in Level 2 primarily include the Company’s swap, collar and option agreements.
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Notes to the Condensed Consolidated Financial Statements (Unaudited)
Exchange traded commodity swaps are included in Level 1. The fair value of the commodity swaps included in Level 2 is based on standard industry income approach models that use significant observable inputs, including but not limited to NYMEX natural gas forward curves, LIBOR-based discount rates, basis forward curves and natural gas liquids forward curves. The Company’s collars, options and swaptions are valued using standard industry income approach option models. The significant observable inputs utilized by the option pricing models include NYMEX forward curves, natural gas volatilities and LIBOR-based discount rates. The NYMEX natural gas forward curves, LIBOR-based discount rates, natural gas volatilities, basis forward curves and NGLs forward curves are validated to external sources at least monthly.
The following assets and liabilities were measured at fair value on a recurring basis during the applicable period:

|  |  |  | Fair value measurements at reporting date using
Description |  | As of September 30, 2018 |  | Quoted prices in active markets for identical assets (Level 1) |  | Significant other observable inputs (Level 2) |  | Significant unobservable inputs (Level 3)
|  | (Thousands)
Assets |  |  |  |  |  |  |  |  |  |  |  |
Derivative instruments, at fair value |  | $ | 315,564 |  |  | $ | 7,661 |  |  | $ | 307,903 |  |  | $ | — |
Liabilities |  |  |  |  |  |  |  |
Derivative instruments, at fair value |  | $ | 183,677 |  |  | $ | 12,058 |  |  | $ | 171,619 |  |  | $ | — |

|  |  |  | Fair value measurements at reporting date using
Description |  | As of December 31, 2017 |  | Quoted prices in active markets for identical assets (Level 1) |  | Significant other observable inputs (Level 2) |  | Significant unobservable inputs (Level 3)
|  | (Thousands)
Assets |  |  |  |  |  |  |  |  |  |  |  |
Derivative instruments, at fair value |  | $ | 241,952 |  |  | $ | — |  |  | $ | 241,952 |  |  | $ | — |
Liabilities |  |  |  |  |  |  |  |  |  |  |  |
Derivative instruments, at fair value |  | $ | 139,089 |  |  | $ | — |  |  | $ | 139,089 |  |  | $ | — |

The carrying values of cash equivalents, accounts receivable and accounts payable approximate fair value due to the short-term maturity of the instruments. The carrying values of borrowings under the Company's various credit facilities approximate fair value as the interest rates are based on prevailing market rates.
The Company also has an immaterial investment in a fund that invests in companies developing technology and operating solutions for exploration and production companies for which it recognized a cumulative effect of accounting change in the first quarter 2018. The investment is valued using the net asset value as a practical expedient as provided in the financial statements received from fund managers.
The Company estimates the fair value of its Senior Notes using its established fair value methodology. Because not all of the Company’s Senior Notes are actively traded, the fair value of the Company's Senior Notes are a Level 2 fair value measurement. Fair value for the Company's non-traded Senior Notes are estimated using a standard industry income approach model that utilizes a discount rate based on market rates for debt with similar remaining time to maturity and credit risk. The estimated fair value of Senior Notes (including EQM’s Senior Notes) on the Condensed Consolidated Balance Sheets was approximately $8.1 billion at September 30, 2018 and $5.7 billion at December 31, 2017.
The Company recognizes transfers between Levels as of the actual date of the event or change in circumstances that caused the transfer. There were no transfers between Levels 1, 2 and 3 during the periods presented.
For information on the fair values of assets related to the impairments of proved and unproved oil and gas properties and of other long-lived assets, see Note Q and Note 1 in EQT's Annual Report on Form 10-K for the year ended December 31, 2017. For information on the assets acquired in the Rice Merger and the assets acquired in other acquisition transactions, see Notes A and P.
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Notes to the Condensed Consolidated Financial Statements (Unaudited)
L. Income Taxes
On December 22, 2017, the U.S. Congress enacted the law known as the Tax Cuts and Jobs Act of 2017 (Tax Reform Legislation), which made significant changes to U.S. federal income tax law, including lowering the federal corporate tax rate to 21% from 35% beginning January 1, 2018. The Company is still analyzing certain aspects of the Tax Reform Legislation and refining calculations, which could potentially impact the measurement of deferred tax balances or potentially give rise to new deferred tax amounts. The Company will refine its estimates to incorporate new or better information as it comes available through the filing date of its 2017 U.S. income tax returns in the fourth quarter of 2018.
For the nine months ended September 30, 2018 and 2017, the Company calculated the provision for income taxes by applying 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 quarter.
All of EQGP's, RMP’s and Strike Force Midstream’s income is included in the Company's pre-tax income (loss). However, the Company is not required to record income tax expense on income allocated to the noncontrolling public limited partners of EQGP and EQM, or to the noncontrolling public limited partners of RMP prior to the Midstream Mergers or to the portion of Strike Force Midstream’s income allocated to the minority owner prior to the closing of the Gulfport Transaction. The exclusion of this income is allocated to noncontrolling interest from the Company's taxable income which reduces the Company's effective tax rate in periods when the Company has consolidated pre-tax income and increases the Company's effective tax rate in periods when the Company has consolidated pre-tax loss.
The Company recorded income tax benefit at an effective tax rate of 28.8% for the nine months ended September 30, 2018 and income tax expense at an effective tax rate of 19.9% for the nine months ended September 30, 2017. The Company’s forecasted annual effective tax rate for 2018 was higher than the statutory rate due to the impact of income allocated to non-controlling limited partners on a forecasted consolidated pre-tax loss and the impact of state taxes. The state taxes increased the forecasted annual effective tax rate as compared to the statutory rate as a result of the pre-tax loss on entities with higher state applicable rates and pre-tax income on entities with lower state applicable rates. The Company’s effective tax rate for the nine months ended September 30, 2018 was lower because the amount of benefit recorded for the year-to-date is limited to the amount of benefit forecasted for the entire year.
There were no material changes to the Company’s methodology for determining unrecognized tax benefits during the three months ended September 30, 2018.
M. Revolving Credit Facilities
The Company has a $2.5 billion revolving credit facility that expires in July 2022. The Company had $0.5 billion in borrowings and no letters of credit outstanding under the credit facility as of September 30, 2018. The Company had $1.3 billion in borrowings and $159.4 million of letters of credit outstanding under the credit facility as of December 31, 2017. The maximum amount of outstanding borrowings at any time under the credit facility during the three and nine months ended September 30, 2018 was $0.7 billion and $1.6 billion, respectively, and the average daily balance of borrowings outstanding was approximately $0.3 billion and $0.9 billion, respectively, at a weighted average annual interest rate of approximately 3.6% and 3.3%, respectively. The Company had no borrowings or letters of credit outstanding under its credit facility at any time during the three and nine months ended September 30, 2017.
EQM has a $1 billion revolving credit facility that expires in July 2022. EQM had $22 million in borrowings and $1 million of letters of credit outstanding under the credit facility as of September 30, 2018. EQM had $180 million in borrowings and no letters of credit outstanding under the credit facility as of December 31, 2017. The maximum amount of outstanding borrowings under EQM’s revolving credit facility at any time during the three and nine months ended September 30, 2018 was $74 million and $420 million, respectively, and the average daily balance of borrowings outstanding was approximately $22 million and $147 million, respectively. EQM incurred interest at a weighted average annual interest rate of approximately 3.7% and 3.2% for the three and nine months ended September 30, 2018, respectively. The maximum amount of outstanding borrowings under EQM's revolving credit facility at any time during each of the three and nine months ended September 30, 2017 was $177 million and the average daily balance of borrowings outstanding was approximately $95 million and $32 million, respectively. EQM incurred interest at a weighted average annual interest rate of approximately 2.7% for both the three and nine months ended September 30, 2017. Prior to the Separation, EQM intends to increase its borrowing capacity from $1 billion up to $3 billion.
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Notes to the Condensed Consolidated Financial Statements (Unaudited)
See Note B to the Condensed Consolidated Financial Statements for a discussion of the borrowings on the EQM Term Loan Facility. As a result of the termination of the EQM Term Loan Facility, EQM expensed $3 million of deferred issuance costs. From April 25, 2018 through June 25, 2018, the maximum amount of EQM's outstanding borrowings under the EQM Term Loan Facility at any time was $1,825 million and the average daily balance was approximately $1,231 million. EQM incurred interest at a weighted average annual interest rate of approximately 3.3% for the period from April 25, 2018 through June 25, 2018.
In connection with the completion of the Midstream Mergers discussed in Note B, on July 23, 2018, EQM repaid the approximately $260 million of borrowings outstanding under the RMP Credit Agreement and the RMP Credit Agreement was terminated. RMP OpCo had $286 million in borrowings and $1 million of letters of credit outstanding under the RMP Credit Agreement as of December 31, 2017. The maximum amount of outstanding borrowings under the RMP Credit Agreement at any time from July 1, 2018 through July 23, 2018 and from January 1, 2018 through July 23, 2018 was $260 million and $375 million, respectively, and the average daily balance of borrowings outstanding during such periods was approximately $249 million and $300 million, respectively, at a weighted average annual interest rate of approximately 4.1% and 3.8%, respectively.
N. Earnings Per Share
In periods when the Company reports a net loss, all options and restricted stock are excluded from the calculation of diluted weighted average shares outstanding because of their anti-dilutive effect on loss per share. As a result, all options and all restricted stock were excluded from the calculation of diluted earnings per share for the three and nine months ended September 30, 2018. Potentially dilutive securities (options and restricted stock awards) included in the calculation of diluted earnings per share totaled 199,376 and 204,080 for the three and nine months ended September 30, 2017, respectively. Options to purchase common stock excluded from potentially dilutive securities because they were anti-dilutive totaled 425,100 and 431,190 for the three and nine months ended September 30, 2017, respectively. The impact of EQM’s and EQGP’s dilutive units did not have a material impact on the Company’s earnings per share calculations for any of the periods presented.
O. Changes in Accumulated Other Comprehensive Income by Component
The following tables explain the changes in accumulated other comprehensive income (OCI) by component during the applicable period:

| Three Months Ended September 30, 2018
| Natural gas cash flow hedges, net of tax |  | Interest rate cash flow hedges, net of tax |  | Other post- retirement benefit liability adjustment, net of tax |  | Accumulated OCI, net of tax
| (Thousands)
Accumulated OCI (loss), net of tax, as of July 1, 2018 | $ | 3,872 |  |  | $ | (475 | ) |  | $ | (6,356 | ) |  | $ | (2,959 | )
(Gains) losses reclassified from accumulated OCI, net of tax | (430 | ) | (a) | 52 |  | (a) | 86 |  | (b) | (292 | )
Accumulated OCI (loss), net of tax, as of September 30, 2018 | $ | 3,442 |  |  | $ | (423 | ) |  | $ | (6,270 | ) |  | $ | (3,251 | )

| Three Months Ended September 30, 2017
| Natural gas cash flow hedges, net of tax |  | Interest rate cash flow hedges, net of tax |  | Other post- retirement benefit liability adjustment, net of tax |  | Accumulated OCI, net of tax
| (Thousands)
Accumulated OCI (loss), net of tax, as of July 1, 2017 | $ | 7,047 |  |  | $ | (627 | ) |  | $ | (6,713 | ) |  | $ | (293 | )
(Gains) losses reclassified from accumulated OCI, net of tax | (1,451 | ) | (a) | 36 |  | (a) | 77 |  | (b) | (1,338 | )
Accumulated OCI (loss), net of tax, as of September 30, 2017 | $ | 5,596 |  |  | $ | (591 | ) |  | $ | (6,636 | ) |  | $ | (1,631 | )

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Notes to the Condensed Consolidated Financial Statements (Unaudited)

| Nine Months Ended September 30, 2018
| Natural gas cash flow hedges, net of tax |  | Interest rate cash flow hedges, net of tax |  | Other post- retirement benefit liability adjustment, net of tax |  | Accumulated OCI, net of tax
| (Thousands)
Accumulated OCI (loss), net of tax, as of January 1, 2018 | $ | 4,625 |  |  | $ | (555 | ) |  | $ | (6,528 | ) |  | $ | (2,458 | )
(Gains) losses reclassified from accumulated OCI, net of tax | (1,183 | ) | (a) | 132 |  | (a) | 258 |  | (b) | (793 | )
Accumulated OCI (loss), net of tax, as of September 30, 2018 | $ | 3,442 |  |  | $ | (423 | ) |  | $ | (6,270 | ) |  | $ | (3,251 | )

| Nine Months Ended September 30, 2017
| Natural gas cash flow hedges, net of tax |  | Interest rate cash flow hedges, net of tax |  | Pension and other post- retirement benefits liability adjustment, net of tax |  | Accumulated OCI, net of tax
| (Thousands)
Accumulated OCI (loss), net of tax, as of January 1, 2017 | $ | 9,607 |  |  | $ | (699 | ) |  | $ | (6,866 | ) |  | $ | 2,042 |
(Gains) losses reclassified from accumulated OCI, net of tax | (4,011 | ) | (a) | 108 |  | (a) | 230 |  | (b) | (3,673 | )
Accumulated OCI (loss), net of tax, as of September 30, 2017 | $ | 5,596 |  |  | $ | (591 | ) |  | $ | (6,636 | ) |  | $ | (1,631 | )

(a) (Gains) losses reclassified from accumulated OCI, net of tax related to natural gas cash flow hedges were reclassified into operating revenues. Losses from accumulated OCI, net of tax related to interest rate cash flow hedges were reclassified into interest expense.
(b) The accumulated OCI reclassification is attributable to the net actuarial loss and net prior service cost related to the Company’s post-retirement benefit plans. See Note 1 to the Consolidated Financial Statements in the Company’s Annual Report on Form 10-K for the year ended December 31, 2017 for additional information.
P. Acquisitions
On February 1, 2017, the Company acquired approximately 14,000 net Marcellus acres located in Marion, Monongalia and Wetzel Counties of West Virginia from a third-party.
On February 27, 2017, the Company acquired approximately 85,000 net Marcellus acres, including drilling rights on approximately 44,000 net Utica acres and current natural gas production of approximately 110 MMcfe per day, from Stone Energy Corporation. The acquired acres are primarily located in Wetzel, Marshall, Tyler and Marion Counties of West Virginia. The acquired assets also included 174 Marcellus wells, 120 of which were producing at the time of the acquisition, and 20 miles of gathering pipeline.
On June 30, 2017, the Company acquired approximately 11,000 net Marcellus acres, and the associated Utica drilling rights from a third-party. The acquired acres are primarily located in Allegheny, Washington and Westmoreland Countries of Pennsylvania.
The Company paid net cash of $740.1 million for the 2017 acquisitions during the nine months ended September 30, 2017. The preliminary fair value assigned to the acquired property, plant and equipment as of the opening balance sheet dates totaled $750.1 million. In connection with the 2017 acquisitions, the Company assumed approximately $5.3 million of net current liabilities and $4.7 million of non-current liabilities.
Fair Value Measurement
As these acquisitions qualified as business combinations under GAAP, the fair value of the acquired assets was determined using a market approach for the undeveloped acreage and a discounted cash flow model under the income approach for the wells. Significant unobservable inputs used in the analysis included the determination of estimated developed reserves and forward pricing estimates. As a result, valuation of the acquired assets was a Level 3 fair value measurement.
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Notes to Condensed Consolidated Financial Statements (Unaudited)
Q. Divestitures
On June 19, 2018, the Company sold its non-core Permian Basin assets located in Texas for net proceeds of $57.7 million, subject to final purchase price adjustments (the Permian Divestiture). The assets sold in the Permian Divestiture included approximately 970 productive wells with current net production of approximately 20 MMcfe per day, approximately 350 miles of low-pressure gathering lines and 26 compressors.
On July 18, 2018, the Company sold approximately 2.5 million non-core, net acres in the Huron Play for net proceeds of $523.6 million, subject to final purchase price adjustments (the Huron Divestiture). The assets sold in the Huron Divestiture included approximately 12,000 productive wells with current net production of approximately 200 MMcfe per day, approximately 6,400 miles of low-pressure gathering lines and 59 compressor stations. The Company retained the deep drilling rights across the divested acreage.
During the first quarter of 2018, the Company recorded an impairment of $2.3 billion associated with the production and related midstream assets in the Huron and Permian Plays. The impairment of these properties and related pipeline assets recorded during the first quarter of 2018 was due to the carrying value of the assets exceeding the undiscounted cash flows which were expected to result from the continued use and potential disposition of the underlying assets as well as management’s determination that it no longer intended to develop the associated unproved properties. The first quarter of 2018 impairment reduced these assets to their estimated fair value at that time of approximately $1 billion.
The fair value of the impaired assets, as determined at March 31, 2018, was based on significant inputs that were not observable in the market and as such are considered to be Level 3 fair value measurements. See Note K for a description of the fair value hierarchy and Note 1 included in the Company’s Annual Report on Form 10-K for the year ended December 31, 2017 for our policy on impairment of proved and unproved properties. Key assumptions included in the calculation of the fair value of the impaired assets as of March 31, 2018 included (i) reserves, including risk adjustments for probable and possible reserves; (ii) future commodity prices; (iii) to the extent available, market based indicators of fair value including estimated proceeds which could be realized upon a potential disposition; (iv) production rates based on the Company's experience with similar properties in which it operates; (v) estimated future operating and development costs; and (vi) a market-based weighted average cost of capital.
In connection with the Permian Divestiture and the Huron Divestiture, the Company recorded an additional impairment/loss on sale of long-lived assets of $118.1 million during the second quarter of 2018 to write down the carrying value of the disposal groups to the estimated amounts to be received upon the closing of the transactions.
In connection with the closing of the Huron Divestiture, the Company recorded a loss of $259.3 million during the third quarter of 2018 related to certain capacity contracts that the Company no longer has existing production to satisfy and does not plan to utilize in the future. The loss was recorded within operating expenses under the impairment/loss on sale of long-lived assets caption within the Statements of Consolidated Operations.
The fair value of the loss for the initial measurement was based upon significant inputs that were not observable in the market and as such is considered a Level 3 fair value measurement. The key unobservable input in the calculation is the amount, if any, of potential future economic benefit from the contracts.
R. Subsequent Events
On October 24, 2018, the Company’s Board of Directors approved the completion of the Separation by means of a pro-rata distribution (the Distribution) of 80.1% of the outstanding common stock of Equitrans Midstream to the Company’s shareholders of record as of the close of business on November 1, 2018 (the Record Date). Pursuant to the plan of Distribution approved by the Company’s Board of Directors, each Company shareholder will receive 0.80 shares of Equitrans Midstream common stock for every one share of the Company’s common stock held as of the close of business on the Record Date. Shareholders will receive cash in lieu of fractional shares of Equitrans Midstream common stock. After considering that EQT will retain an additional 19.9% of Equitrans Midstream's common stock, total Equitrans Midstream shares outstanding after the Distribution are expected to be approximately 255 million shares.
In connection with the Separation, the Company and its subsidiaries will enter into certain agreements with Equitrans Midstream to implement the legal and structural separation between the two companies, govern the relationship between the Company and Equitrans Midstream after completion of the Separation, and allocate between the Company and Equitrans Midstream, various assets, liabilities and obligations, including, among other things, employee benefits, litigation, contracts, equipment, real property,
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Notes to Condensed Consolidated Financial Statements (Unaudited)
intellectual property and tax-related assets and liabilities. These agreements include a Separation and Distribution Agreement, Tax Matters Agreement, Employee Matters Agreement, Transition Services Agreement and Shareholder and Registration Rights Agreement, the form of which has been approved by the Company’s Board of Directors.
The accompanying unaudited Condensed Consolidated Financial Statements include the historical results of Equitrans Midstream, as the Distribution is expected to be effective at 11:59 p.m. eastern time on November 12, 2018, which is after the most recent period reported in this Form 10-Q. In future filings, the historical results of the businesses that comprise Equitrans Midstream Corporation will be reported as discontinued operations in the Company’s Consolidated Financial Statements. As a result of the Separation and Distribution, the accompanying unaudited, interim Condensed Consolidated Financial Statements are not indicative of the Company’s future financial position, results of operations or cash flows.
S. Recently Issued Accounting Standards
In May 2014, the Financial Accounting Standards Board (FASB) issued ASU No. 2014-09, Revenue from Contracts with Customers. The standard requires an entity to recognize revenue in a manner that depicts the transfer of goods or services to customers at an amount that reflects the consideration to which the entity expects to be entitled in exchange for those goods or services. The Company adopted this standard on January 1, 2018 using the modified retrospective method of adoption. Adoption of the ASU did not require an adjustment to the opening balance of equity. The Company does not expect the standard to have a significant effect on its results of operations, liquidity or financial position in 2018. The Company implemented processes and controls to ensure new contracts are reviewed for the appropriate accounting treatment and to generate the disclosures required under the new standard in the first quarter of 2018. For the disclosures required by this ASU, see Note F.
In January 2016, the FASB issued ASU No. 2016-01, Financial Instruments-Overall: Recognition and Measurement of Financial Assets and Financial Liabilities. The standard affects accounting for equity investments and financial liabilities under the fair value option, the presentation and disclosure requirements for financial instruments, and eliminates the cost method of accounting for equity investments. The Company adopted this standard in the first quarter of 2018 which resulted in a cumulative effect adjustment of $4.1 million on the Statement of Condensed Consolidated Equity.
In February 2016, the FASB issued ASU No. 2016-02, Leases. The standard requires an entity to record assets and obligations for contracts currently recognized as operating leases. In July 2018, the FASB issued targeted improvements to this ASU in ASU 2018-11. This update provides entities with an optional transition method, which permits an entity to initially apply the new leases standard at the adoption date and recognize a cumulative-effect adjustment to the opening balance of retained earnings in the period of adoption. The Company has elected to utilize the optional transition method. The ASU will be effective for annual reporting periods beginning after December 15, 2018, including interim periods within that reporting period, with early adoption permitted. The Company is utilizing a lease accounting system to document its current population of contracts classified as leases, which will be updated as the lease population changes. The Company continues to evaluate new business processes and related internal controls and is assessing and documenting the accounting impacts related to the new standard. Although the evaluation is ongoing, the Company expects that the adoption will impact its financial statements as the standard requires recognition on the balance sheet of a right of use asset and corresponding lease liability.
In June 2016, the FASB issued ASU No. 2016-13, Financial Instruments-Credit Losses: Measurement of Credit Losses on Financial Instruments. This ASU amends 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 ASU eliminates the probable initial recognition threshold in current GAAP and requires an entity to reflect its current estimate of all expected credit losses. The amendments affect loans, debt securities, trade receivables, net investments in leases, off balance sheet credit exposures, reinsurance receivables, and any other financial assets not excluded from the scope that have the contractual right to receive cash. The ASU will be effective for annual reporting periods beginning after December 15, 2019, including interim periods within that reporting period. The Company is currently evaluating the effect this standard will have on its financial statements and related disclosures.
In November 2016, the FASB issued ASU No. 2016-18, Statement of Cash Flows: Restricted Cash. This ASU requires that a statement of cash flows explain the change during the period in the total of cash, cash equivalents, and amounts generally described as restricted cash or restricted cash equivalents. Therefore, amounts generally described as restricted cash and restricted cash equivalents should be included with cash and cash equivalents when reconciling the beginning of period and end of period total amounts shown on the statement of cash flows. The Company adopted this standard in the first quarter of 2018. The Company had $75 million restricted cash at December 31, 2016. In accordance with ASU 2016-18, restricted cash is included in the beginning of period cash balance and excluded from investing activities on the Statements of Condensed Consolidated Cash Flows for the
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Notes to Condensed Consolidated Financial Statements (Unaudited)
nine months ended September 30, 2017. The Company had no restricted cash on the Condensed Consolidated Balance Sheet from March 31, 2017 through the current period.
In January 2017, the FASB issued ASU No. 2017-01, Business Combinations: Clarifying the Definition of a Business. This ASU clarifies the definition of a business with the objective of adding guidance to assist entities with evaluating whether transactions should be recorded as acquisitions (or disposals) of assets or businesses. The Company adopted this standard in the first quarter of 2018 with no significant effect on its financial statements or related disclosures.
In January 2017, the FASB issued ASU No. 2017-04, Simplifying the Test of Goodwill Impairment. This ASU simplifies the quantitative goodwill impairment test requirements by eliminating the requirement to calculate the implied fair value of goodwill. Instead, a company would record an impairment charge based on the excess of a reporting unit’s carrying value over its fair value. The standard’s provisions are to be applied prospectively. The Company adopted this standard in the first quarter of 2018 with no significant effect on its financial statements or related disclosures.
In March 2017, the FASB issued ASU No. 2017-07, Compensation - Retirement Benefits: Improving the Presentation of Net Periodic Pension Cost and Net Periodic Postretirement Benefit Cost. This ASU provides additional guidance on the presentation of net benefit cost in the income statement and on the components eligible for capitalization in assets. The Company adopted this standard in the first quarter of 2018 with no significant effect on its financial statements or related disclosures.
In May 2017, the FASB issued ASU No. 2017-09, Compensation - Stock Compensation: Scope of Modification Accounting. This ASU provides guidance regarding which changes to the terms or conditions of a share-based payment award require an entity to apply modification accounting. The Company adopted this standard in the first quarter of 2018 with no significant effect on its financial statements or related disclosures. This ASU will be applied prospectively to awards modified on or after the adoption date.
In February 2018, the FASB issued ASU No. 2018-02, Income Statement—Reporting Comprehensive Income: Reclassification of Certain Tax Effects from Accumulated Other Comprehensive Income. This ASU allows companies to reclassify stranded tax effects resulting from the Tax Reform Legislation from accumulated other comprehensive income to retained earnings. The ASU is effective for fiscal years beginning after December 15, 2018 and early adoption is permitted. The reclassification permitted under this ASU should be applied either in the period of adoption or retrospectively to each period (or periods) in which the effect of the change in the U.S. federal corporate income tax rate in the Tax Reform Legislation is recognized. The Company is currently evaluating the effect this standard will have on its financial statements and related disclosures.
In August 2018, the FASB issued ASU 2018-13, Fair Value Measurement (Topic 820), 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. Early adoption is permitted. The Company is currently evaluating the effect this standard will have on its financial statements and related disclosures but does not expect the adoption of this standard to have a material impact on its financial statements and related disclosures.
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Management’s Discussion and Analysis of Financial Condition and Results of Operations
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 Condensed 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, and Section 27A of the Securities Act of 1933, as amended. 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” and other words of similar meaning, or the negative thereof, 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 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 the Company and its subsidiaries, including guidance regarding the Company’s strategy to develop its Marcellus, Utica, Upper Devonian and other reserves; drilling plans and programs (including the number, type, feet of pay, average lateral lengths and location of wells to be drilled and the availability of capital to complete these plans and programs); production sales volumes (including liquids volumes) and growth rates; gathering, transmission and water volumes; infrastructure programs (including the timing, cost and capacity of the gathering, transmission and water expansion projects); the cost, capacity, timing of regulatory approvals and anticipated in-service date of the Mountain Valley Pipeline (MVP) and MVP Southgate projects; the ultimate terms, partners and structure of Mountain Valley Pipeline, LLC (the MVP Joint Venture); monetization transactions, including asset sales, joint ventures or other transactions involving the Company’s assets; acquisition transactions; the impact and outcome of pending and future litigation, whether the separation of the Company’s production and midstream businesses (the Separation) will be completed and the timing and terms of the Separation; the timing and structure of any dispositions of the Company's 19.9% retained common stock of Equitrans Midstream Corporation (Equitrans Midstream) following the Separation and the Company's planned use of the proceeds from any such dispositions; whether EQGP will enter into a transaction to eliminate its incentive distribution rights following the Separation, including the timing and terms of such transaction; the Company’s ability to achieve the anticipated synergies, operational efficiencies and returns from its acquisition of Rice Energy Inc. (Rice) and the Midstream Streamlining Transactions (as defined in Note B to the Condensed Consolidated Financial Statements); natural gas prices, changes in basis and the impact of commodity prices on the Company's business; reserves, including potential future downward adjustments; projected capital expenditures and capital contributions; liquidity and financing requirements, including funding sources and availability and EQM's plan to increase its borrowing capacity to up to $3 billion; hedging strategy; the effects of government regulation; the expected impact of the Tax Cuts and Jobs Act of 2017; and tax 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 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 and other risks and uncertainties, many of which are difficult to predict and 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”, and elsewhere in the Company’s Annual Report on Form 10-K for the year ended December 31, 2017, as updated by Part II, Item 1A, "Risk Factors" in 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, whether as a result of new information, future events or otherwise.
In reviewing any agreements incorporated by reference in or filed with this Quarterly Report on Form 10-Q, please remember that such agreements are included to provide information regarding the terms of such agreements and are not intended to provide any other factual or disclosure information about the Company. The agreements may contain representations and warranties by the Company, which should not in all instances be treated as categorical statements of fact, but rather as a way of allocating the risk to one of the parties to such agreements should those statements prove to be inaccurate. The representations and warranties were made only as of the date of the relevant agreement or such other date or dates as may be specified in such agreement and are subject to more recent developments. Accordingly, these representations and warranties alone may not describe the actual state of affairs of the Company or its affiliates as of the date they were made or at any other time.
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Management’s Discussion and Analysis of Financial Condition and Results of Operations
CORPORATE OVERVIEW
Three Months Ended September 30, 2018 vs. Three Months Ended September 30, 2017
Net loss attributable to EQT Corporation for the three months ended September 30, 2018 was $39.7 million, a loss of $0.15 per diluted share, compared to net income attributable to EQT Corporation of $23.3 million, $0.13 per diluted share, for the three months ended September 30, 2017. The decrease was primarily attributable to higher operating costs, including a loss of $259.3 million recorded in the third quarter of 2018 primarily associated with the divestiture of certain non-core production and related pipeline assets in the Huron Play, higher interest expense and higher net income attributable to noncontrolling interests. These expenses were partly offset by higher revenues primarily from an 82.5% increase in production sales volumes, a larger income tax benefit for the three months ended September 30, 2018 compared to the income tax benefit for the three months ended September 30, 2017, and higher other income.
During the three months ended September 30, 2018, the Company recorded transaction costs of approximately $31.5 million. Transaction costs include $17.8 million for the Company's sum-of-the-parts review and Midstream Streamlining Transactions and $13.7 million for the Rice Merger (as defined in Note A to the Condensed Consolidated Financial Statements). Transaction costs are reflected in unallocated expenses as they are not allocated to any operating segment.
In connection with the Rice Merger, the Company obtained intangible assets composed of customer relationships and non-compete agreements with former Rice executives. Amortization expense for the three months ended September 30, 2018 related to non-compete agreements with former Rice executives is approximately $10.4 million and is not allocated to any operating segment.
Nine Months Ended September 30, 2018 vs. Nine Months Ended September 30, 2017
Net loss attributable to EQT Corporation for the nine months ended September 30, 2018 was $1,607.9 million, a loss of $6.12 per diluted share, compared to net income attributable to EQT Corporation of $228.5 million, $1.32 per diluted share, for the nine months ended September 30, 2017. The decrease was primarily due to higher operating expenses, including impairment/loss on sale of $2.7 billion associated with the divestiture of certain non-core production and related pipeline assets in the Huron and Permian Plays, higher net income attributable to noncontrolling interests and higher interest expense. These decreases were partly offset by higher revenues primarily from an 84.4% increase in production sales volumes, an income tax benefit for the nine months ended September 30, 2018 compared to income tax expense for the nine months ended September 30, 2017, and higher other income.
During the nine months ended September 30, 2018, the Company recorded transaction costs of $93.2 million. Transaction costs include $55.9 million for the Company's sum-of-the-parts review and Midstream Streamlining Transactions and $37.3 million for the Rice Merger and are reflected in unallocated expenses as they are not allocated to any operating segment.
In connection with the Rice Merger, the Company obtained intangible assets composed of customer relationships and non-compete agreements with former Rice executives. Amortization expense for the nine months ended September 30, 2018 related to non-compete agreements with former Rice executives is approximately $31.0 million and is not allocated to any operating segment.
See “Business Segment Results of Operations” for a discussion of segment operating expenses and revenues.
See “Investing Activities” under the caption “Capital Resources and Liquidity” for a discussion of capital expenditures.
Consolidated Operational Data
The following table presents detailed natural gas and liquids operational information to assist in the understanding of the Company’s consolidated operations, including the calculation of the Company's average realized price ($/Mcfe), which is based on EQT Production adjusted operating revenues, a non-GAAP supplemental financial measure. EQT Production adjusted operating revenues is presented because it is an important measure used by the Company’s management to evaluate period-to-period comparisons of earnings trends. EQT Production adjusted operating revenues should not be considered as an alternative to EQT Production total operating revenues. See “Reconciliation of Non-GAAP Financial Measures” for a reconciliation of EQT Production adjusted operating revenues to EQT Production total operating revenues and Note I to the Condensed Consolidated Financial Statements for a reconciliation of EQT Production total operating revenues to EQT Corporation total operating revenues.
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Management’s Discussion and Analysis of Financial Condition and Results of Operations

|  | Three Months Ended September 30, |  | Nine Months Ended September 30,
in thousands (unless noted) |  | 2018 (e) |  | 2017 |  | % |  | 2018 (e) |  | 2017 |  | %
NATURAL GAS |  |  |  |  |  |  |  |  |  |  |  |  |
Sales volume (MMcf) |  | 350,297 |  |  | 176,311 |  |  | 98.7 |  |  | 1,013,836 |  |  | 508,457 |  |  | 99.4 |
NYMEX price ($/MMBtu) (a) |  | $ | 2.90 |  |  | $ | 3.00 |  |  | (3.3 | ) |  | $ | 2.89 |  |  | $ | 3.16 |  |  | (8.5 | )
Btu uplift |  | 0.17 |  |  | 0.30 |  |  | (43.3 | ) |  | 0.19 |  |  | 0.28 |  |  | (32.1 | )
Natural gas price ($/Mcf) |  | $ | 3.07 |  |  | $ | 3.30 |  |  | (7.0 | ) |  | $ | 3.08 |  |  | $ | 3.44 |  |  | (10.5 | )
Basis ($/Mcf) (b) |  | $ | (0.41 | ) |  | $ | (0.81 | ) |  | (49.4 | ) |  | $ | (0.24 | ) |  | $ | (0.53 | ) |  | (54.7 | )
Cash settled basis swaps (not designated as hedges) ($/Mcf) |  | (0.06 | ) |  | (0.04 | ) |  | 50.0 |  |  | (0.07 | ) |  | (0.02 | ) |  | 250.0 |
Average differential, including cash settled basis swaps ($/Mcf) |  | $ | (0.47 | ) |  | $ | (0.85 | ) |  | (44.7 | ) |  | $ | (0.31 | ) |  | $ | (0.55 | ) |  | (43.6 | )
Average adjusted price ($/Mcf) |  | $ | 2.60 |  |  | $ | 2.45 |  |  | 6.1 |  |  | $ | 2.77 |  |  | $ | 2.89 |  |  | (4.2 | )
Cash settled derivatives (cash flow hedges) ($/Mcf) |  | — |  |  | 0.01 |  |  | (100.0 | ) |  | — |  |  | 0.01 |  |  | (100.0 | )
Cash settled derivatives (not designated as hedges) ($/Mcf) |  | 0.03 |  |  | 0.13 |  |  | (76.9 | ) |  | 0.05 |  |  | 0.01 |  |  | 400.0 |
Average natural gas price, including cash settled derivatives ($/Mcf) |  | $ | 2.63 |  |  | $ | 2.59 |  |  | 1.5 |  |  | $ | 2.82 |  |  | $ | 2.91 |  |  | (3.1 | )
Natural gas sales, including cash settled derivatives |  | $ | 922,974 |  |  | $ | 456,347 |  |  | 102.3 |  |  | $ | 2,862,582 |  |  | $ | 1,484,711 |  |  | 92.8 |
LIQUIDS |  |  |  |  |  |  |  |  |  |  |  |  |
NGLs (excluding ethane): |  |  |  |  |  |  |  |  |  |  |  |  |
Sales volume (MMcfe) (c) |  | 13,964 |  |  | 19,054 |  |  | (26.7 | ) |  | 51,299 |  |  | 55,089 |  |  | (6.9 | )
Sales volume (Mbbls) |  | 2,328 |  |  | 3,176 |  |  | (26.7 | ) |  | 8,550 |  |  | 9,182 |  |  | (6.9 | )
Price ($/Bbl) |  | $ | 40.73 |  |  | $ | 29.81 |  |  | 36.6 |  |  | $ | 37.97 |  |  | $ | 28.33 |  |  | 34.0 |
Cash settled derivatives (not designated as hedges) ($/Bbl) |  | (2.28 | ) |  | (0.44 | ) |  | 418.2 |  |  | (1.39 | ) |  | (0.43 | ) |  | 223.3 |
Average NGLs price, including cash settled derivatives ($/Bbl) |  | $ | 38.45 |  |  | $ | 29.37 |  |  | 30.9 |  |  | $ | 36.58 |  |  | $ | 27.90 |  |  | 31.1 |
NGLs sales |  | $ | 89,498 |  |  | $ | 93,273 |  |  | (4.0 | ) |  | $ | 312,768 |  |  | $ | 256,123 |  |  | 22.1 |
Ethane: |  |  |  |  |  |  |  |  |  |  |  |
Sales volume (MMcfe) (c) |  | 9,002 |  |  | 8,226 |  |  | 9.4 |  |  | 25,413 |  |  | 24,970 |  |  | 1.8 |
Sales volume (Mbbls) |  | 1,501 |  |  | 1,371 |  |  | 9.5 |  |  | 4,236 |  |  | 4,162 |  |  | 1.8 |
Price ($/Bbl) |  | $ | 7.88 |  |  | $ | 5.92 |  |  | 33.1 |  |  | $ | 7.82 |  |  | $ | 6.45 |  |  | 21.2 |
Ethane sales |  | $ | 11,822 |  |  | $ | 8,119 |  |  | 45.6 |  |  | $ | 33,108 |  |  | $ | 26,858 |  |  | 23.3 |
Oil: |  |  |  |  |  |  |  |  |  |  |  |  |
Sales volume (MMcfe) (c) |  | 974 |  |  | 1,476 |  |  | (34.0 | ) |  | 3,234 |  |  | 4,565 |  |  | (29.2 | )
Sales volume (Mbbls) |  | 162 |  |  | 246 |  |  | (34.1 | ) |  | 539 |  |  | 761 |  |  | (29.2 | )
Price ($/Bbl) |  | $ | 51.73 |  |  | $ | 36.86 |  |  | 40.3 |  |  | $ | 54.41 |  |  | $ | 39.96 |  |  | 36.2 |
Oil sales |  | $ | 8,392 |  |  | $ | 9,072 |  |  | (7.5 | ) |  | $ | 29,322 |  |  | $ | 30,198 |  |  | (2.9 | )
Total liquids sales volume (MMcfe) (c) |  | 23,940 |  |  | 28,756 |  |  | (16.7 | ) |  | 79,946 |  |  | 84,624 |  |  | (5.5 | )
Total liquids sales volume (Mbbls) |  | 3,991 |  |  | 4,793 |  |  | (16.7 | ) |  | 13,325 |  |  | 14,105 |  |  | (5.5 | )
Liquids sales |  | $ | 109,712 |  |  | $ | 110,464 |  |  | (0.7 | ) |  | $ | 375,198 |  |  | $ | 313,179 |  |  | 19.8 |
TOTAL PRODUCTION |  |  |  |  |  |  |  |  |  |  |  |
Total natural gas & liquids sales, including cash settled derivatives (d) |  | $ | 1,032,686 |  |  | $ | 566,811 |  |  | 82.2 |  |  | $ | 3,237,780 |  |  | $ | 1,797,890 |  |  | 80.1 |
Total sales volume (MMcfe) |  | 374,237 |  |  | 205,067 |  |  | 82.5 |  |  | 1,093,782 |  |  | 593,081 |  |  | 84.4 |
Average realized price ($/Mcfe) |  | $ | 2.76 |  |  | $ | 2.76 |  |  | — |  |  | $ | 2.96 |  |  | $ | 3.03 |  |  | (2.3 | )

(a) | The Company’s volume weighted NYMEX natural gas price (actual average NYMEX natural gas price ($/MMBtu) was $2.90 and $3.00 for the three months ended September 30, 2018 and 2017, respectively, and $2.90 and $3.17 for the nine months ended September 30, 2018 and 2017, respectively).

(b) | Basis represents the difference between the ultimate sales price for natural gas and the NYMEX natural gas price.

(c) | NGLs, ethane and crude oil were converted to Mcfe at the rate of six Mcfe per barrel for all periods.

(d) | Also referred to in this report as EQT Production adjusted operating revenues, a non-GAAP supplemental financial measure.

(e) | EQT Production includes the results of production operations acquired in the Rice Merger, which occurred on November 13, 2017.

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EQT Corporation and Subsidiaries
Management’s Discussion and Analysis of Financial Condition and Results of Operations
Reconciliation of Non-GAAP Financial Measures
The table below reconciles EQT Production adjusted operating revenues, a non-GAAP supplemental financial measure, to EQT Production total operating revenues reported under EQT Production Results of Operations, its most directly comparable financial measure calculated in accordance with GAAP. See Note I to the Condensed Consolidated Financial Statements in this Quarterly Report on Form 10-Q for a reconciliation of EQT Production operating revenues to EQT Corporation total operating revenues as reported in the Statements of Consolidated Operations.
EQT Production adjusted operating revenues (also referred to as total natural gas & liquids sales, including cash settled derivatives) is presented because it is an important measure used by the Company’s management to evaluate period-over-period comparisons of earnings trends. EQT Production adjusted operating revenues excludes the revenue impact of changes in the fair value of derivative instruments prior to settlement and the revenue impact of certain pipeline and net marketing services. Management utilizes EQT Production adjusted operating revenues to evaluate earnings trends because the measure reflects only the impact of settled derivative contracts and thus does not impact the revenue from natural gas sales with the often volatile fluctuations in the fair value of derivatives prior to settlement. EQT Production adjusted operating revenues also excludes pipeline and net marketing services because management considers these revenues to be unrelated to the revenues for its natural gas and liquids production. Pipeline and net marketing services primarily includes revenues for gathering services provided to third-parties as well as both the cost of and recoveries on third-party pipeline capacity not used for EQT Production sales volumes. Management further believes that EQT Production adjusted operating revenues as presented provides useful information to investors for evaluating period-over-period earnings trends.

Calculation of EQT Production adjusted operating revenues | Three Months Ended September 30, |  | Nine Months Ended September 30,
$ in thousands (unless noted) | 2018 |  | 2017 |  | 2018 |  | 2017
EQT Production total operating revenues | $ | 1,050,046 |  |  | $ | 597,718 |  |  | $ | 3,312,730 |  |  | $ | 2,057,481 |
Add back (deduct): |  |  |  |  |  |  |
Loss (gain) on derivatives not designated as hedges | 3,075 |  |  | (35,625 | ) |  | (5,620 | ) |  | (222,693 | )
Net cash settlements (paid) received on derivatives not designated as hedges | (14,285 | ) |  | 13,321 |  |  | (27,401 | ) |  | (6,837 | )
Premiums (paid) received for derivatives that settled during the period | (18 | ) |  | 537 |  |  | 453 |  |  | 1,595 |
Pipeline and net marketing services | (6,132 | ) |  | (9,140 | ) |  | (42,382 | ) |  | (31,656 | )
EQT Production adjusted operating revenues, a non-GAAP financial measure | $ | 1,032,686 |  |  | $ | 566,811 |  |  | $ | 3,237,780 |  |  | $ | 1,797,890 |
Total sales volumes (MMcfe) | 374,237 |  |  | 205,067 |  |  | 1,093,782 |  |  | 593,081 |
Average realized price ($/Mcfe) | $ | 2.76 |  |  | $ | 2.76 |  |  | $ | 2.96 |  |  | $ | 3.03 |

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Table of Contents
EQT Corporation and Subsidiaries
Management’s Discussion and Analysis of Financial Condition and Results of Operations
Business Segment Results of Operations
Business segment operating results are presented in the segment discussions and financial tables on the following pages. Operating segments are evaluated on their contribution to the Company’s consolidated results based on operating income. Other income, interest and income taxes are managed on a consolidated basis. Headquarters’ costs are billed to the operating segments based upon a fixed allocation of the headquarters’ annual operating budget. Unallocated expenses incurred in 2018 consist primarily of incentive compensation and administrative costs, which included transaction costs associated with the Company's sum-of-the-parts review, the Midstream Streamlining Transactions and the Rice Merger.
The Company has reported the components of each segment’s operating income and various operational measures in the sections below, and where appropriate, has provided information describing how a measure was derived. EQT’s management believes that presentation of this information provides useful information to management and investors regarding the financial condition, operations and trends of each of EQT’s business segments without being obscured by the financial condition, operations and trends for the other segments or by the effects of corporate allocations of interest, income taxes and other income. In addition, management uses these measures for budget planning purposes. The Company has reconciled each segment’s operating income to the Company’s consolidated operating income and net income in Note I to the Condensed Consolidated Financial Statements in this Quarterly Report on Form 10-Q.
Prior to the Rice Merger, the Company reported its results of operations through three business segments: EQT Production, EQT Gathering and EQT Transmission. These reporting segments reflected the Company's lines of business and were reported in the same manner in which the Company evaluated its operating performance through September 30, 2017. Following the Rice Merger, the Company adjusted its internal reporting structure to incorporate the newly acquired assets and conducted its business through five business segments: EQT Production, EQM Gathering (formerly known as EQT Gathering), EQM Transmission (formerly known as EQT Transmission), RMP Gathering and RMP Water. On July 23, 2018, pursuant to the Midstream Merger Agreement, RMP and the RMP General Partner each became wholly owned subsidiaries of EQM as a result of the Midstream Mergers. The Company now conducts its business through four business segments: EQT Production, EQM Gathering, EQM Transmission and EQM Water.
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EQT Corporation and Subsidiaries
Management’s Discussion and Analysis of Financial Condition and Results of Operations
EQT PRODUCTION
RESULTS OF OPERATIONS

| Three Months Ended September 30, |  | Nine Months Ended September 30,
| 2018 (a) |  | 2017 |  | % |  | 2018 (a) |  | 2017 |  | %
OPERATIONAL DATA |  |  |  |  |  |  |  |  |  |  |
Sales volume detail (MMcfe): |  |  |  |  |  |  |  |  |  |  |  |  |  |
Marcellus (b) | 316,740 |  |  | 181,650 |  |  | 74.4 |  |  | 899,642 |  |  | 523,122 |  |  | 72.0 |
Ohio Utica | 52,400 |  |  | (4 | ) |  | (1,310,100.0 | ) |  | 147,706 |  |  | 247 |  |  | 59,700.0 |
Other | 5,097 |  |  | 23,421 |  |  | (78.2 | ) |  | 46,434 |  |  | 69,712 |  |  | (33.4 | )
Total production sales volumes (c) | 374,237 |  |  | 205,067 |  |  | 82.5 |  |  | 1,093,782 |  |  | 593,081 |  |  | 84.4 |
Average daily sales volumes (MMcfe/d) | 4,068 |  |  | 2,229 |  |  | 82.5 |  |  | 4,007 |  |  | 2,172 |  |  | 84.5 |
Average realized price ($/Mcfe) | $ | 2.76 |  |  | $ | 2.76 |  |  | — |  |  | $ | 2.96 |  |  | $ | 3.03 |  |  | (2.3 | )
Gathering to EQM Gathering ($/Mcfe) | $ | 0.50 |  |  | $ | 0.47 |  |  | 6.4 |  |  | $ | 0.50 |  |  | $ | 0.48 |  |  | 4.2 |
Transmission to EQM Transmission ($/Mcfe) | $ | 0.12 |  |  | $ | 0.23 |  |  | (47.8 | ) |  | $ | 0.13 |  |  | $ | 0.23 |  |  | (43.5 | )
Third-party gathering and transmission ($/Mcfe) | $ | 0.40 |  |  | $ | 0.45 |  |  | (11.1 | ) |  | $ | 0.41 |  |  | $ | 0.46 |  |  | (10.9 | )
Processing ($/Mcfe) | $ | 0.10 |  |  | $ | 0.22 |  |  | (54.5 | ) |  | $ | 0.12 |  |  | $ | 0.23 |  |  | (47.8 | )
Lease operating expenses (LOE), excluding production taxes ($/Mcfe) | $ | 0.06 |  |  | $ | 0.13 |  |  | (53.8 | ) |  | $ | 0.08 |  |  | $ | 0.13 |  |  | (38.5 | )
Production taxes ($/Mcfe) | $ | 0.06 |  |  | $ | 0.07 |  |  | (14.3 | ) |  | $ | 0.06 |  |  | $ | 0.09 |  |  | (33.3 | )
Production depletion ($/Mcfe) | $ | 1.03 |  |  | $ | 1.03 |  |  | — |  |  | $ | 1.03 |  |  | $ | 1.03 |  |  | — |
Depreciation and depletion (thousands): |  |  |  |  |  |  |  |  |  |  |  |  |  |  |
Production depletion | $ | 384,965 |  |  | $ | 210,393 |  |  | 83.0 |  |  | $ | 1,128,248 |  |  | $ | 613,379 |  |  | 83.9 |
Other depreciation and depletion | 6,118 |  |  | 13,710 |  |  | (55.4 | ) |  | 33,470 |  |  | 41,032 |  |  | (18.4 | )
Total depreciation and depletion | $ | 391,083 |  |  | $ | 224,103 |  |  | 74.5 |  |  | $ | 1,161,718 |  |  | $ | 654,411 |  |  | 77.5 |
Capital expenditures (thousands) (d) | $ | 855,494 |  |  | $ | 449,303 |  |  | 90.4 |  |  | $ | 2,225,435 |  |  | $ | 1,850,482 |  |  | 20.3 |
FINANCIAL DATA (thousands) |  |  |  |  |  |  |  |  |  |  |  |  |  |  |
Revenues: |  |  |  |  |  |  |  |  |  |  |
Sales of natural gas, oil and NGLs | $ | 1,046,989 |  |  | $ | 552,953 |  |  | 89.3 |  |  | $ | 3,264,728 |  |  | $ | 1,803,132 |  |  | 81.1 |
Pipeline and net marketing services | 6,132 |  |  | 9,140 |  |  | (32.9 | ) |  | 42,382 |  |  | 31,656 |  |  | 33.9 |
(Loss) gain on derivatives not designated as hedges | (3,075 | ) |  | 35,625 |  |  | (108.6 | ) |  | 5,620 |  |  | 222,693 |  |  | (97.5 | )
Total operating revenues | 1,050,046 |  |  | 597,718 |  |  | 75.7 |  |  | 3,312,730 |  |  | 2,057,481 |  |  | 61.0 |
Operating expenses: |  |  |  |  |  |  |  |  |  |  |  |  |  |  |
Gathering | 199,475 |  |  | 116,921 |  |  | 70.6 |  |  | 587,844 |  |  | 334,801 |  |  | 75.6 |
Transmission | 182,932 |  |  | 119,729 |  |  | 52.8 |  |  | 548,106 |  |  | 354,534 |  |  | 54.6 |
Processing | 38,340 |  |  | 44,166 |  |  | (13.2 | ) |  | 129,523 |  |  | 133,745 |  |  | (3.2 | )
LOE, excluding production taxes | 21,480 |  |  | 26,060 |  |  | (17.6 | ) |  | 83,069 |  |  | 77,171 |  |  | 7.6 |
Production taxes | 21,254 |  |  | 13,453 |  |  | 58.0 |  |  | 66,162 |  |  | 52,290 |  |  | 26.5 |
Exploration | 15,772 |  |  | 2,437 |  |  | 547.2 |  |  | 42,058 |  |  | 9,040 |  |  | 365.2 |
Selling, general and administrative (SG&A) | 42,109 |  |  | 38,648 |  |  | 9.0 |  |  | 115,135 |  |  | 118,855 |  |  | (3.1 | )
Depreciation and depletion | 391,083 |  |  | 224,103 |  |  | 74.5 |  |  | 1,161,718 |  |  | 654,411 |  |  | 77.5 |
Impairment/loss on sale of long-lived assets | 259,279 |  |  | — |  |  | 100.0 |  |  | 2,706,438 |  |  | — |  |  | 100.0 |
Total operating expenses | 1,171,724 |  |  | 585,517 |  |  | 100.1 |  |  | 5,440,053 |  |  | 1,734,847 |  |  | 213.6 |
Operating (loss) income | $ | (121,678 | ) |  | $ | 12,201 |  |  | (1,097.3 | ) |  | $ | (2,127,323 | ) |  | $ | 322,634 |  |  | (759.4 | )

(a) | Operational data for EQT Production includes results of operations for production operations acquired in the Rice Merger, which occurred on November 13, 2017.

(b) | Includes Upper Devonian wells.

(c) | NGLs, ethane and crude oil were converted to Mcfe at the rate of six Mcfe per barrel for all periods.

(d) | Expenditures for segment assets in the EQT Production segment included $35.7 million and $50.7 million for fill-ins and bolt-ons associated with legacy EQT acreage for the three months ended September 30, 2018 and 2017, respectively, and $113.8 million and $140.4 million for fill-ins and bolt-ons associated with legacy EQT acreage for the nine months ended September 30, 2018 and 2017, respectively. The three and nine months ended September 30, 2017 included $7.8 million and $819.0 million of cash capital expenditures, respectively, and the nine months ended September 30, 2017 included $7.5 million of non-cash capital expenditures for the acquisitions discussed in Note P.

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EQT Corporation and Subsidiaries
Management’s Discussion and Analysis of Financial Condition and Results of Operations
Three Months Ended September 30, 2018 vs. Three Months Ended September 30, 2017
EQT Production’s operating loss was $121.7 million for the three months ended September 30, 2018 compared to operating income of $12.2 million for the three months ended September 30, 2017. The decrease was primarily due to higher operating costs, including a loss recorded in the third quarter of 2018 associated with certain capacity contracts that the Company will no longer have existing production to satisfy and does not plan to utilize in the future as a result of the Huron Divestiture and a loss on derivatives not designated as hedges compared to a gain on derivatives not designated as hedges in the prior year partly offset by increased sales volumes of produced natural gas. These variances include the impact of operating the assets acquired from Rice for the three months ended September 30, 2018, as the Rice Merger was completed in the fourth quarter of 2017. These variances also include the impacts of the divestiture of the non-core Permian assets, which was completed in the second quarter of 2018, and the divestiture of the non-core Huron assets, which was completed in the third quarter of 2018 (collectively, the 2018 Divestitures).
Total operating revenues were $1,050.0 million for the three months ended September 30, 2018 compared to $597.7 million for the three months ended September 30, 2017. Sales of natural gas, oil and NGLs increased as a result of an 82.5% increase in production sales volumes in the current period which was primarily a result of the Rice Merger and increased production from the 2016 and 2017 drilling programs, partly offset by the 2018 Divestitures and the normal production decline in the Company’s producing wells. The average realized price for the three months ended September 30, 2018 was comparable to the average realized price for the three months ended September 30, 2017. EQT Production paid $14.3 million and received $13.3 million of net cash settlements for derivatives not designated as hedges during the three months ended September 30, 2018 and 2017, respectively, that are included in the average realized price but are not in GAAP operating revenues.
There was no change in average realized price quarter over quarter as a $0.38 per Mcf improvement in the average natural gas differential was offset by a decrease in the average NYMEX natural gas price net of cash settled derivatives of $0.34 per Mcf and a decrease in higher priced liquids sales as a result of the 2018 Divestitures. The improvement in the average differential related to higher basis in the Appalachian Basin and at certain sales points reached through the Company's transportation portfolio, which increased following the Rice Merger.
Pipeline and net marketing services primarily includes gathering revenues from gathering services provided to third parties and both the cost of, and recoveries on, third-party pipeline capacity not used to transport EQT Production’s produced volumes. The decrease in these revenues primarily related to reduced gathering revenues as a result of the Huron Divestiture.
EQT Production total operating revenues for the three months ended September 30, 2018 included a $3.1 million loss on derivatives not designated as hedges compared to a $35.6 million gain on derivatives not designated as hedges for the three months ended September 30, 2017. The losses for the three months ended September 30, 2018 primarily related to a decrease in the fair market value of EQT Production’s basis swaps due to an increase in basis prices, partially offset by an increase in the fair market value of EQT Production's NYMEX swaps and NYMEX options due to a decrease in NYMEX prices during the third quarter of 2018.
Gathering expense increased consistent with production sales volumes, partly offset by a lower gathering rate per unit on gathering capacity acquired in the Rice Merger. Transmission expense increased due to increased third party capacity incurred to move EQT Production’s natural gas out of the Appalachian Basin, primarily due to firm capacity acquired in connection with the Rice Merger as well as the Company's capacity on the Rover pipeline, which started in 2018, partly offset by reduced firm capacity costs as a result of the Huron Divestiture. Processing expenses decreased primarily as a result of the 2018 Divestitures. On a per unit basis, these costs and other operating costs are lower for the three months ended September 30, 2018 compared to the three months ended September 30, 2017 reflecting the savings achieved through the Rice Merger as well as the 2018 Divestitures.
LOE decreased primarily as a result of the 2018 Divestitures partly offset by higher salt water disposal costs and higher personnel costs due to increased activity in EPC Production's Marcellus and Utica operations. Production taxes increased primarily as a result of increased development activity in Pennsylvania as well as the increased asset base and production volumes in Ohio following the Rice Merger, partly offset by the lower asset base and production volumes in Kentucky, West Virginia, Virginia and Texas following the 2018 Divestitures. Exploration expense increased primarily due to an increase in the number of leases expiring during the third quarter of 2018 and increased delay rentals on leases acquired in the Rice Merger.
Depreciation and depletion expense increased as a result of higher produced volumes in the third quarter of 2018, partly offset by lower depreciation as a result of the 2018 Divestitures.
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EQT Corporation and Subsidiaries
Management’s Discussion and Analysis of Financial Condition and Results of Operations
Nine Months Ended September 30, 2018 vs. Nine Months Ended September 30, 2017
EQT Production's operating loss was $2,127.3 million for the nine months ended September 30, 2018 compared to operating income of $322.6 million for the nine months ended September 30, 2017. The decrease was primarily due to impairment charges recorded in 2018 associated with the 2018 Divestitures, including the third quarter loss associated with related capacity contracts that the Company will no longer have existing production to satisfy and does not plan to utilize in the future. Excluding the impairments, EQT Production's higher operating expenses, lower gains on derivatives not designated as hedges and a lower average realized price were more than offset by the increased sales volumes of produced natural gas. These variances include the impact of operating the assets acquired from Rice for the nine months ended September 30, 2018, as the Rice Merger was completed in the fourth quarter of 2017. These variances also include the impacts of the 2018 Divestitures which were completed in the second and third quarters of 2018.
Total operating revenues were $3,312.7 million for the nine months ended September 30, 2018 compared to $2,057.5 million for the nine months ended September 30, 2017. Sales of natural gas, oil and NGLs increased as a result of an 84.4% increase in production sales volumes in the current period which was primarily a result of the Rice Merger and increased production from the 2016 and 2017 drilling programs, partly offset by the 2018 Divestitures and the normal production decline in the Company's producing wells. The increase in production sales volumes was partly offset by a lower average realized price. EQT Production paid $27.4 million and $6.8 million of net cash settlements for derivatives not designated as hedges during the nine months ended September 30, 2018 and 2017, respectively, that are included in the average realized price but are not in the GAAP operating revenues.
The $0.07 per Mcfe decrease in the average realized price for the nine months ended September 30, 2018 compared to the nine months ended September 30, 2017 was primarily due to a decrease in the average NYMEX natural gas price net of cash settled derivatives of $0.33 per Mcf, partly offset by a $0.24 per Mcf improvement in the average natural gas differential and higher liquids prices. The increase in the average differential primarily related to higher prices during the first quarter of 2018 at sales points in the United States Northeast where colder weather led to increased demand, higher Appalachian Basin basis as well as increased sales volumes at higher priced Gulf Coast and Midwest markets accessible through the Company's increased transportation portfolio following the Rice Merger.
The increase in pipeline and net marketing services primarily related to favorable price spreads on the Company's Tennessee Gas Pipeline capacity, partly offset by reduced gathering revenues due to the Huron Divestiture.
EQT Production total operating revenues for the nine months ended September 30, 2018 and 2017 included a $5.6 million and $222.7 million gain on derivatives not designated as hedges, respectively. The gains for the nine months ended September 30, 2018 primarily related to an increase in the fair market value of EQT Production's NYMEX swaps and NYMEX options due to a decrease in NYMEX prices, partially offset by a decrease in the fair market value of EQT Production's basis swaps due to an increase in basis prices during the first nine months of 2018.
Gathering expense increased consistent with production sales volumes, partly offset by a lower gathering rate per unit on gathering capacity acquired in the Rice Merger. Transmission expense increased due to increased third party capacity incurred to move EQT Production’s natural gas out of the Appalachian Basin, primarily due to firm capacity acquired in connection with the Rice Merger as well as the Company’s capacity on the Rover pipeline, which started in 2018, partly offset by reduced firm capacity costs as a result of the Huron Divestiture. On a per unit basis, these costs and other operating costs were lower for the nine months ended September 30, 2018 compared to the nine months ended September 30, 2017 reflecting the savings achieved through the Rice Merger as well as the 2018 Divestitures.
On an absolute basis, LOE increased primarily due to increased salt water disposal costs in 2018 related to increased activity from the Rice Merger and higher personnel costs, partly offset by the reduced costs resulting from the 2018 Divestitures. Production taxes increased primarily as a result of increased development activity in Pennsylvania as well as the increased asset base and production volumes in Ohio following the Rice Merger. SG&A expense decreased primarily due to decreased legal reserves, partly offset by higher personnel costs including corporate overhead allocations. Exploration expense increased primarily due to an increase in the number of leases expiring during the first nine months of 2018 and increased delay rentals on leases acquired in the Rice Merger.
Depreciation and depletion expense increased as a result of higher produced volumes in 2018, partly offset by lower depreciation as a result of the 2018 Divestitures.
See Note Q to the Condensed Consolidated Financial Statements for a discussion of the asset impairment.
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EQT Corporation and Subsidiaries
Management’s Discussion and Analysis of Financial Condition and Results of Operations
EQM GATHERING
RESULTS OF OPERATIONS

| Three Months Ended September 30, |  | Nine Months Ended September 30,
| 2018 (a) |  | 2017 |  | % |  | 2018 (a) |  | 2017 |  | %
| (Thousands, other than per day amounts)
FINANCIAL DATA |  |  |  |  |  |  |  |  |  |  |
Firm reservation fee revenues | $ | 112,598 |  |  | $ | 104,772 |  |  | 7.5 |  | $ | 334,233 |  |  | $ | 300,901 |  |  | 11.1
Volumetric based fee revenues: |  |  |  |  |  |  |  |  |  |  |
Usage fees under firm contracts (b) | 8,661 |  |  | 7,873 |  |  | 10.0 |  | 30,725 |  |  | 19,173 |  |  | 60.3
Usage fees under interruptible contracts (c) | 131,602 |  |  | 3,877 |  |  | 3,294.4 |  | 366,482 |  |  | 10,922 |  |  | 3,255.4
Total volumetric based fee revenues | 140,263 |  |  | 11,750 |  |  | 1,093.7 |  | 397,207 |  |  | 30,095 |  |  | 1,219.8
Total operating revenues | 252,861 |  |  | 116,522 |  |  | 117.0 |  | 731,440 |  |  | 330,996 |  |  | 121.0
Operating expenses: |  |  |  |  |  |  |  |  |  |  |
Operating and maintenance | 18,850 |  |  | 10,104 |  |  | 86.6 |  | 54,551 |  |  | 30,737 |  |  | 77.5
SG&A | 20,363 |  |  | 10,503 |  |  | 93.9 |  | 62,665 |  |  | 28,800 |  |  | 117.6
Depreciation | 25,359 |  |  | 9,983 |  |  | 154.0 |  | 72,309 |  |  | 28,398 |  |  | 154.6
Amortization of intangible assets | 10,387 |  |  | — |  |  | 100.0 |  | 31,160 |  |  | — |  |  | 100.0
Total operating expenses | 74,959 |  |  | 30,590 |  |  | 145.0 |  | 220,685 |  |  | 87,935 |  |  | 151.0
Operating income | $ | 177,902 |  |  | $ | 85,932 |  |  | 107.0 |  | $ | 510,755 |  |  | $ | 243,061 |  |  | 110.1
OPERATIONAL DATA |  |  |  |  |  |  |  |  |  |  |  |  |  |  |
Gathered volumes (BBtu per day) |  |  |  |  |  |  |  |  |  |  |
Firm capacity reservation | 2,114 |  |  | 1,838 |  |  | 15.0 |  | 2,029 |  |  | 1,783 |  |  | 13.8
Volumetric based services (d) | 4,437 |  |  | 370 |  |  | 1,099.2 |  | 4,291 |  |  | 292 |  |  | 1,369.5
Total gathered volumes | 6,551 |  |  | 2,208 |  |  | 196.7 |  | 6,320 |  |  | 2,075 |  |  | 204.6
Capital expenditures | $ | 194,477 |  |  | $ | 48,182 |  |  | 303.6 |  | $ | 515,072 |  |  | $ | 150,728 |  |  | 241.7

(a) | Includes the pre-acquisition results of the Drop-Down Transaction and the Midstream Mergers, which were effective May 1, 2018 and July 23, 2018, respectively. The recast is for the period the acquired businesses were under the common control of EQT, which began on November 13, 2017 as a result of the Rice Merger.

(b) | Includes fees on volumes gathered in excess of firm contracted capacity.

(c) | Includes volumes from contracts under which EQM has agreed to hold capacity available without charging a capacity reservation fee.

(d) | Includes volumes gathered under interruptible contracts and volumes gathered in excess of firm contracted capacity.

Three Months Ended September 30, 2018 vs. Three Months Ended September 30, 2017
Gathering revenues increased by $136.3 million for the three months ended September 30, 2018 compared to the three months ended September 30, 2017 primarily driven by the Midstream Mergers, the Drop-Down Transaction and affiliate and third party production development in the Marcellus and Utica Shales. Firm reservation fee revenues increased primarily as a result of increased affiliate contracted gathering capacity and higher rates on various affiliate wellhead expansion projects in the current period. Usage fees under firm contracts increased due to increased third party volumes gathered in excess of firm contracted capacity. Usage fees under interruptible contracts increased as a result of the Midstream Mergers and the Drop-Down Transaction, which added revenues of $69.7 million and $58.4 million, respectively, for the three months ended September 30, 2018.
Operating expenses increased by $44.4 million for the three months ended September 30, 2018 compared to the three months ended September 30, 2017. Operating expenses increased $17.9 million and $24.5 million as a result of RMP and the former Rice assets acquired in the Drop-Down Transaction (the Drop-Down Entities), respectively. In addition, operating and maintenance expense increased due to higher repairs and maintenance expense consistent with the growth of the business. Selling, general and administrative also increased due to transaction costs of $2.2 million. Depreciation expense also increased as a result of additional assets placed in-service. Amortization of intangible assets relates to the customer contract intangible associated with the Drop-Down Entities.
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Management’s Discussion and Analysis of Financial Condition and Results of Operations
Nine Months Ended September 30, 2018 vs. Nine Months Ended September 30, 2017
Gathering revenues increased by $400.4 million for the nine months ended September 30, 2018 compared to the nine months ended September 30, 2017 primarily driven by RMP, the Drop-Down Entities and affiliate and third party production development in the Marcellus and Utica Shales. Firm reservation fee revenues increased primarily as a result of increased affiliate and third party contracted gathering capacity and higher rates on various affiliate wellhead expansion projects in the current period. Usage fees under firm contracts increased due to increased third party and affiliate volumes gathered in excess of firm contracted capacity. Usage fees under interruptible contracts increased as a result of RMP and the Drop-Down Entities, which added revenues of $193.5 million and $161.9 million, respectively, for the nine months ended September 30, 2018.
Operating expenses increased by $132.8 million for the nine months ended September 30, 2018 compared to the nine months ended September 30, 2017. Operating expenses increased $53.2 million and $72.8 million as a result of RMP and the Drop-Down Entities, respectively. In addition, operating and maintenance expense increased due to higher repairs and maintenance expense consistent with the growth of the business. Selling, general and administrative also increased due to transaction costs of $7.5 million. Depreciation expense also increased as a result of additional assets placed in-service, including those associated with the Range Resources header pipeline project and various wellhead gathering expansion projects. Amortization of intangible assets relates to the customer contract intangible associated with the Drop-Down Entities.
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Management’s Discussion and Analysis of Financial Condition and Results of Operations
EQM TRANSMISSION
RESULTS OF OPERATIONS

| Three Months Ended September 30, |  | Nine Months Ended September 30,
| 2018 |  | 2017 |  | % |  | 2018 |  | 2017 |  | %
| (Thousands, other than per day amounts)
FINANCIAL DATA |  |  |  |  |  |  |  |  |  |  |
Firm reservation fee revenues | $ | 82,669 |  |  | $ | 84,438 |  |  | (2.1 | ) |  | $ | 262,666 |  |  | $ | 256,224 |  |  | 2.5 |
Volumetric based fee revenues: |  |  |  |  |  |  |  |  |  |  |
Usage fees under firm contracts (a) | 5,331 |  |  | 3,427 |  |  | 55.6 |  |  | 13,981 |  |  | 9,787 |  |  | 42.9 |
Usage fees under interruptible contracts | 1,350 |  |  | 1,906 |  |  | (29.2 | ) |  | 8,782 |  |  | 6,173 |  |  | 42.3 |
Total volumetric based fee revenues | 6,681 |  |  | 5,333 |  |  | 25.3 |  |  | 22,763 |  |  | 15,960 |  |  | 42.6 |
Total operating revenues | 89,350 |  |  | 89,771 |  |  | (0.5 | ) |  | 285,429 |  |  | 272,184 |  |  | 4.9 |
Operating expenses: |  |  |  |  |  |  |  |  |  |  |
Operating and maintenance | 10,721 |  |  | 9,485 |  |  | 13.0 |  |  | 27,082 |  |  | 23,984 |  |  | 12.9 |
SG&A | 7,581 |  |  | 8,255 |  |  | (8.2 | ) |  | 22,335 |  |  | 23,170 |  |  | (3.6 | )
Depreciation | 12,357 |  |  | 12,261 |  |  | 0.8 |  |  | 37,228 |  |  | 35,793 |  |  | 4.0 |
Total operating expenses | 30,659 |  |  | 30,001 |  |  | 2.2 |  |  | 86,645 |  |  | 82,947 |  |  | 4.5 |
Operating income | $ | 58,691 |  |  | $ | 59,770 |  |  | (1.8 | ) |  | $ | 198,784 |  |  | $ | 189,237 |  |  | 5.0 |
Equity income | $ | 16,087 |  |  | $ | 6,025 |  |  | 167.0 |  |  | $ | 35,836 |  |  | $ | 15,413 |  |  | 132.5 |
OPERATIONAL DATA |  |  |  |  |  |  |  |  |  |  |  |  |  |  |
Transmission pipeline throughput (BBtu per day) |  |  |  |  |  |  |  |  |  |  |
Firm capacity reservation | 2,927 |  |  | 2,517 |  |  | 16.3 |  |  | 2,857 |  |  | 2,288 |  |  | 24.9 |
Volumetric based services (b) | 104 |  |  | 21 |  |  | 395.2 |  |  | 62 |  |  | 22 |  |  | 181.8 |
Total transmission pipeline throughput | 3,031 |  |  | 2,538 |  |  | 19.4 |  |  | 2,919 |  |  | 2,310 |  |  | 26.4 |
Average contracted firm transmission reservation commitments (BBtu per day) | 3,658 |  |  | 3,474 |  |  | 5.3 |  |  | 3,801 |  |  | 3,519 |  |  | 8.0 |
Capital expenditures | $ | 37,626 |  |  | $ | 22,312 |  |  | 68.6 |  |  | $ | 84,517 |  |  | $ | 73,679 |  |  | 14.7 |

(a) | Includes fees on volumes transported in excess of firm contracted capacity as well as usage fees and fees on all volumes transported under firm contracts.

(b) | Includes volumes transported under interruptible contracts and volumes transported in excess of firm contracted capacity.

Three Months Ended September 30, 2018 vs. Three Months Ended September 30, 2017
Transmission and storage revenues decreased by $0.4 million for the three months ended September 30, 2018 compared to the three months ended September 30, 2017. Firm reservation fee revenues decreased as a result of a third quarter 2017 FERC-approved retroactive negotiated rate adjustment of approximately $3.4 million for the period from October 1, 2016 through June 30, 2017 partially offset by increased affiliate firm capacity and higher contractual rates on existing contracts with third parties in the current period. Usage fees under firm contracts increased primarily due to higher affiliate and third party volumes and increased commodity charges on higher firm contracted volumes. The decrease in usage fees under interruptible contracts primarily relates to lower parking revenue, which does not have associated pipeline throughput.
Operating expenses increased by $0.7 million for the three months ended September 30, 2018 compared to the three months ended September 30, 2017 primarily as a result of higher operating and maintenance personnel costs partly offset by lower selling, general and administrative expenses resulting from lower allocations from EQT and professional fees.
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Management’s Discussion and Analysis of Financial Condition and Results of Operations
The increase in equity income of $10.1 million for the three months ended September 30, 2018 compared to the three months ended September 30, 2017 was related to the increase in the MVP Joint Venture's AFUDC on the MVP.
Nine Months Ended September 30, 2018 vs. Nine Months Ended September 30, 2017
Transmission and storage revenues increased by $13.2 million for the nine months ended September 30, 2018 compared to the nine months ended September 30, 2017. Firm reservation fee revenues increased due to higher contractual rates on existing contracts with third parties and affiliates in the current period and affiliates contracting for additional firm capacity. Usage fees under firm contracts increased primarily due to increased commodity charges. The increase in usage fees under interruptible contracts primarily relates to higher parking revenue, which does not have associated pipeline throughput.
Operating expenses increased by $3.7 million for the nine months ended September 30, 2018 compared to the nine months ended September 30, 2017 consistent with the growth of the business.
Equity income increased $20.4 million for the nine months ended September 30, 2018 compared to the nine months ended September 30, 2017 due to the increase in the MVP Joint Venture's AFUDC on the MVP.
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Management’s Discussion and Analysis of Financial Condition and Results of Operations
EQM WATER
RESULTS OF OPERATIONS

|  | Three Months Ended September 30, |  | Nine Months Ended September 30,
|  | 2018 (a) |  | 2017 |  | % |  | 2018 (a) |  | 2017 |  | %
FINANCIAL DATA |  | (Thousands, other than per day amounts)
Water services revenues |  | $ | 22,373 |  |  | $ | — |  |  | 100.0 |  |  | $ | 93,438 |  |  | — |  |  | $ | 100.0 |
Operating expenses: |  |  |  |  |  |  |  |  |  |  |  |
Operation and maintenance |  | 18,521 |  |  | — |  |  | 100.0 |  |  | 36,901 |  |  | — |  |  | 100.0 |
SG&A |  | 1,094 |  |  | — |  |  | 100.0 |  |  | 3,490 |  |  | — |  |  | 100.0 |
Depreciation |  | 5,851 |  |  | — |  |  | 100.0 |  |  | 17,420 |  |  | — |  |  | 100.0 |
Total operating expenses |  | 25,466 |  |  | — |  |  | 100.0 |  |  | 57,811 |  |  | — |  |  | 100.0 |
Operating (loss) income |  | $ | (3,093 | ) |  | $ | — |  |  | 100.0 |  |  | $ | 35,627 |  |  | $ | — |  |  | 100.0 |
OPERATIONAL DATA |  |  |  |  |  |  |  |  |  |  |  |
Water services volumes (MMgal) |  | 449 |  |  | — |  |  | 100.0 |  |  | 1,740 |  |  | — |  |  | 100.0 |
Capital expenditures |  | $ | 7,981 |  |  | $ | — |  |  | 100.0 |  |  | $ | 17,358 |  |  | $ | — |  |  | 100.0 |

(a) | This table sets forth selected financial and operational data for RMP Water. The Company acquired the water assets that constitute RMP Water on November 13, 2017 as part of the Rice Merger. On July 23, 2018, following the completion of the Midstream Mergers, RMP Water became EQM Water.

EQM Water provides fresh water for well completions operations in the Marcellus and Utica Shales and collects flowback and produced water for recycling or disposal. Substantially all of EQM Water's services are provided to EQT's Production business. EQM Water offers its water services on a volumetric basis, supported by an acreage dedication from EQT for certain drilling areas. The fee EQM Water charges per gallon of water is tiered and thus is lower on a per gallon basis once certain volumetric thresholds are met. During the three and nine months ended September 30, 2018, operating expenses were composed of customary expenses for a water services business, including water procurement costs. The operating loss for the three months ended September 30, 2018 was due to timing of costs related to activities on drilling pads.
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Management’s Discussion and Analysis of Financial Condition and Results of Operations
Other Income Statement Items
Other Income
For the three months ended September 30, 2018 and 2017, the Company recorded equity in earnings of nonconsolidated investments of $16.1 million and $6.0 million, respectively, related to EQM's portion of the MVP Joint Venture's AFUDC on the MVP. For the nine months ended September 30, 2018 and 2017, the Company recorded equity in earnings of nonconsolidated investments of $35.8 million and $15.4 million, respectively, related to EQM's portion of the MVP Joint Venture's AFUDC on the MVP. EQT includes the equity investment in MVP in the EQM Transmission segment.
Other income also includes AFUDC - equity which varies based on EQM's level of spending on regulated projects.
For the nine months ended September 30, 2017, other income was partly offset by losses on the sale of trading securities. As of March 31, 2017, the Company closed its positions on all trading securities.
Interest Expense
Interest expense increased by $42.7 million for the three months ended September 30, 2018 compared to the three months ended September 30, 2017, which was primarily driven by $24.8 million of interest incurred on EQT's Senior Notes issued in October 2017, $33.7 million of interest incurred on EQM's Senior Notes issued in June 2018 and $3.3 million of interest incurred on credit facility borrowings partly offset by a $10.7 million decrease due to the early extinguishment of certain EQT Senior Notes and a decrease of $6.8 million related to expense incurred in 2017 on the Company's senior unsecured bridge loans.
Interest expense increased by $102.9 million for the nine months ended September 30, 2018 compared to the nine months ended September 30, 2017, which was primarily driven by $72.9 million of interest incurred on EQT's Senior Notes issued in October 2017, $35.9 million of interest incurred on EQM'S Senior Notes issued in June 2018, $38.9 million of interest incurred on credit facility borrowings and $3.0 million of deferred fees expensed upon termination of the EQM Term Loan Facility partly offset by a $32.1 million decrease due to the early extinguishment of certain EQT Senior Notes and a decrease of $7.6 million related to expense incurred in 2017 on the Company's senior unsecured bridge loans.
Income Tax Expense
See discussion of income tax expense in Note L to the Condensed Consolidated Financial Statements.
Net Income Attributable to Noncontrolling Interests
The increase in net income attributable to noncontrolling interests for the three months and nine months ended September 30, 2018 was the result of higher net income at EQM and noncontrolling interests in RMP and Strike Force Midstream as a result of the Rice Merger on November 13, 2017. As described in Note B to the Condensed Consolidated Financial Statements, Strike Force Midstream and RMP are now wholly owned subsidiaries of EQM following the Gulfport Transaction and the Midstream Mergers, respectively.
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Management’s Discussion and Analysis of Financial Condition and Results of Operations
OUTLOOK
On February 21, 2018, the Company announced a plan to separate its upstream and midstream businesses, creating a standalone publicly traded corporation, Equitrans Midstream, that will focus on midstream operations. Following the Separation, Equitrans Midstream will own the midstream interests held by the Company, including the interests in EQGP and EQM. The Separation is intended to qualify as tax-free to the Company’s shareholders for U.S. federal income tax purposes.
On October 24, 2018, the Company’s Board of Directors approved the completion of the Separation by means of a pro-rata distribution (the Distribution) by the Company of 80.1% of the outstanding common stock of Equitrans Midstream to the Company’s shareholders of record as of the close of business on November 1, 2018 (the Record Date). Pursuant to the plan of Distribution approved by the Company’s Board of Directors, each Company shareholder will receive 0.80 shares of Equitrans Midstream common stock for every one share of the Company’s common stock held as of the close of business on the Record Date. Shareholders will receive cash in lieu of fractional shares of Equitrans Midstream common stock. After considering that EQT will retain an additional 19.9% of Equitrans Midstream's common stock, total Equitrans Midstream shares outstanding after the Distribution are expected to be approximately 255 million shares.
In connection with the Separation, the Company and certain of its subsidiaries will enter into agreements with Equitrans Midstream to implement the legal and structural separation between the two companies, govern the relationship between the Company and Equitrans Midstream after completion of the Separation, and allocate between the Company and Equitrans Midstream, various assets, liabilities and obligations, including, among other things, employee benefits, litigation, contracts, equipment, real property, intellectual property and tax-related assets and liabilities. These agreements include a Separation and Distribution Agreement, Tax Matters Agreement, Employee Matters Agreement, Transition Services Agreement and Shareholder and Registration Rights Agreement, the forms of which have been approved by the Company’s Board of Directors and will be filed with the SEC following the Separation.
The Company plans to dispose of all of its retained Equitrans Midstream common stock, which may include dispositions through one or more subsequent exchanges for debt or a sale of its shares for cash. The Company expects to dispose its retained Equitrans Midstream common stock in order to reduce the Company's post Separation debt.
The accompanying Management’s Discussion and Analysis of Financial Condition and Results of Operations is presented on a consolidated basis for the Company, which includes the results of the businesses that comprise Equitrans Midstream, as the Distribution is expected to be effective at 11:59 p.m. eastern time, on November 12, 2018, which is after the most recent period reported in this Form 10-Q. In future filings, the historical results of the businesses that comprise Equitrans Midstream will be presented as discontinued operations. As a result of the Separation and Distribution, Management’s Discussion and Analysis of Financial Condition and Results of Operations is not indicative of the Company’s future financial position, results of operations or cash flows.
The Company is committed to profitably and safely developing its Appalachian Basin natural gas and NGLs reserves through environmentally responsible, cost-effective and technologically advanced horizontal drilling. The Company believes the long-term outlook for its business is favorable due to the Company’s substantial resource base, low cost structure, financial strength, risk management, including its commodity hedging strategy, and disciplined investment of capital. The Company believes the combination of these factors provide it with an opportunity to exploit and develop its positions and maximize efficiency through economies of scale in its strategic operating area.
The Company’s production business strategy is transitioning from one focused on volume growth to one focused on capital efficiency and free cash flow generation. In preparation for the Separation, the Company has been evaluating EQT Production's long-term pace of development in order to achieve the optimal balance between free cash flow generation and volume growth. Based on this evaluation, the Company is currently targeting mid-single digit annual production growth over the next five years. This is expected to result in lower annual drilling and capital expenditures in the future.
EQT Production capital expenditures estimate for 2018 well development increased by $300 million to $2.5 billion. This was driven by inefficiencies resulting from higher activity levels, the learning curve on ultra-long laterals and service cost increases. Estimated sales volumes are expected to be 1,460 - 1,480 Bcfe for 2018. The 2018 capital investment plan for EQT Production is expected to be funded by cash generated from operations and asset sales.
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Management’s Discussion and Analysis of Financial Condition and Results of Operations
The Company plans to invest approximately $1.8 billion on midstream infrastructure through EQM in 2018, including capital contributions to the MVP Joint Venture of $0.9 billion, on gathering expansion projects, primarily driven by wellhead and header projects in Pennsylvania, West Virginia and Ohio. This also includes expansion and ongoing maintenance capital expenditures of RMP as a result of the completion of the Midstream Mergers on July 23, 2018 and approximately $150 million on commencing construction activities on the Hammerhead project. The Hammerhead project is a 1.2 Bcf per day gathering header pipeline connecting natural gas produced in Pennsylvania and West Virginia to the MVP primarily for EQT that is expected to cost a total of $555 million and be placed in service in the fourth quarter of 2019. EQM's future capital investments may vary significantly from period to period based on the available investment opportunities and the timing of construction for the MVP. Maintenance related capital expenditures are also expected to vary quarter to quarter. EQM's available sources of liquidity include cash generated from operations, borrowing under EQM's credit facilities, cash on hand, debt offerings and issuance of additional EQM partnership units. EQM is not forecasting any public equity issuance for the foreseeable future.
The Company has also announced that it expects the Equitrans Midstream board of directors will evaluate the possible simplification of the EQM structure by addressing the incentive distribution rights, although the ultimate decision of whether to propose any such changes will be made by the Equitrans Midstream board of directors following the Separation.
The Company’s revenues, earnings, liquidity and ability to grow are substantially dependent on the prices it receives for, and the Company’s ability to develop its reserves of, natural gas and NGLs. Due to the volatility of commodity prices, the Company is unable to predict future potential movements in the market prices for natural gas, including Appalachian and other market point basis, and NGLs and thus cannot predict the ultimate impact of prices on its operations.
Changes in natural gas, NGLs and oil prices could affect, among other things, the Company's development plans, which would increase or decrease the pace of the development and the level of the Company's reserves, as well as the Company's revenues, earnings or liquidity. Lower prices could also result in non-cash impairments in the book value of the Company’s oil and gas properties, goodwill or other long lived intangible assets or downward adjustments to the Company’s estimated proved reserves. Any such impairment and/or downward adjustment to the Company’s estimated reserves could potentially be material to the Company.
See "Impairment of Oil and Gas Properties and Goodwill" and “Critical Accounting Policies and Estimates” included in the Company's Annual Report on Form 10-K for the year ended December 31, 2017 for a discussion of the Company’s accounting policies and significant assumptions related to accounting for oil and gas producing activities, and the Company's policies and processes with respect to impairment reviews for proved and unproved property and goodwill. The Company did not identify an impairment indicator related to goodwill during the third quarter of 2018.
CAPITAL RESOURCES AND LIQUIDITY
Operating Activities
Net cash flows provided by operating activities totaled $2,445.4 million for the nine months ended September 30, 2018 compared to $1,211.4 million for the nine months ended September 30, 2017. The $1,234.0 million increase in cash flows provided by operating activities was primarily the result of higher operating revenues partially offset by increased cash operating expenses.
Investing Activities
Net cash flows used in investing activities totaled $2,719.5 million for the nine months ended September 30, 2018 compared to $1,791.5 million for the nine months ended September 30, 2017. The $928.0 million increase was primarily due to the Company's capital expenditures and higher contributions to the MVP Joint Venture during the nine months ended September 30, 2018. These increases were partly offset by proceeds from the 2018 Divestitures and capital expenditures for acquisitions during the nine months ended September 30, 2017. The Company spud 125 gross wells in the first nine months of 2018, including 89 horizontal Marcellus wells, five horizontal Upper Devonian wells and 31 horizontal Utica wells. The Company spud 149 gross wells in the first nine months of 2017, including 100 horizontal Marcellus wells, 48 horizontal Upper Devonian wells and one horizontal Utica well. The Company completed approximately 1,744,000 feet of pay in the first nine months of 2018, approximately three times the 646,000 feet of pay completed during the same period of 2017. Gathering capital expenditures increased primarily in support of gathering projects supporting EQT's production development in the Marcellus Shale.
Capital expenditures as reported on the Statements of Condensed Consolidated Cash Flows for the nine months ended September 30, 2018 and 2017 excluded capitalized non-cash stock-based compensation expense and accruals. The impact of accrued capital
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Management’s Discussion and Analysis of Financial Condition and Results of Operations
expenditures includes the reversal of the prior period accrual as well as the current period estimate, both of which are non-cash items. The net impact of these non-cash items was $(45.2) million and $102.7 million for the nine months ended September 30, 2018 and 2017, respectively. There were no non-cash capital expenditures excluded for acquisitions as reported on the Statements of Condensed Consolidated Cash Flows for the nine months ended September 30, 2018. The Company excluded non-cash capital expenditures as reported on the Statements of Condensed Consolidated Cash Flows of $7.5 million related to the Company's acquisitions for the nine months ended September 30, 2017.
Financing Activities
Net cash flows provided by financing activities totaled $131.6 million for the nine months ended September 30, 2018 compared to net cash flows used in financing activities of $114.8 million for the nine months ended September 30, 2017. For the nine months ended September 30, 2018, the primary source of financing cash flows was net proceeds from the EQM 2018 Senior Notes (as defined in Note B to the Condensed Consolidated Financial Statements) offering net of offering costs, while the primary use of financing cash flows was a net decrease in EQT, EQM and RMP credit facility borrowings, repurchase and retirement of common stock, distributions to noncontrolling interests, EQM's acquisition of the 25% ownership interest in Strike Force Midstream, dividends paid and cash paid for taxes on share-based incentive awards. For the nine months ended September 30, 2017, the primary financing uses of cash were distributions to noncontrolling interests, cash paid for taxes on share-based incentive awards and dividends paid. The primary financing source of cash was a net increase in EQM credit facility borrowings during the nine months ended September 30, 2017.
The Company may from time to time seek to repurchase its outstanding debt securities. Such repurchases, if any, will depend on prevailing market conditions, the Company's liquidity requirements, contractual and legal restrictions and other factors. In addition, following completion of the Distribution, the Company plans to dispose of its 19.9% retained shares of Equitrans Midstream’s common stock, which may include dispositions through one or more exchanges for debt or a sale of the retained shares for cash. The Company expects to use the proceeds from the sale of its retained Equitrans Midstream common stock to reduce the Company’s post-Separation debt, which was initially funded by borrowings on the Company's credit facility and cash on hand. The Company has $700 million of debt that matures in 2019; these maturities may be funded by sales of, or exchanges for, the retained interest in Equitrans Midstream common stock, borrowings on the Company's credit facility, cash from operations or a combination thereof.
Refer to Part II, Item 2, "Unregistered Sales of Equity Securities and Use of Proceeds" for discussion of the Company's $500 million share repurchase program.
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Management’s Discussion and Analysis of Financial Condition and Results of Operations
Security Ratings and Financing Triggers
The table below reflects the credit ratings for debt instruments of the Company at September 30, 2018. Changes in credit ratings may affect the interest rates on the Company’s short-term and floating rate long-term debt and the fees it pays under its lines of credit. These ratings may also affect collateral requirements on derivative instruments, pipeline capacity contracts, joint venture arrangements and subsidiary construction contracts, as well as the rates available on new long-term debt and access to the credit markets.

Rating Service |  | Senior Notes |  | Outlook
Moody's |  | Baa3 |  | Stable
S&P |  | BBB |  | Negative
Fitch Ratings Service (Fitch) |  | BBB- |  | Stable

The table below reflects the credit ratings for debt instruments of EQM at September 30, 2018. Changes in credit ratings may affect EQM’s cost of short-term debt through interest rates and fees under its lines of credit. These ratings may also affect collateral requirements under joint venture arrangements and subsidiary construction contracts, as well as the rates available on new long-term debt and access to the credit markets.

Rating Service |  | Senior Notes |  | Outlook
Moody’s |  | Ba1 |  | Stable
S&P |  | BBB- |  | Stable
Fitch |  | BBB- |  | Stable

EQGP has no long-term debt and is not currently rated by Moody’s, S&P or Fitch.
The Company’s and EQM’s credit ratings are subject to revision or withdrawal at any time by the assigning rating organization, and each rating should be evaluated independently of any other rating. The Company and EQM 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 by a credit rating agency if, in its judgment, circumstances so warrant. If any credit rating agency downgrades the ratings, particularly below investment grade, the Company’s or EQM’s access to the capital markets may be limited, borrowing costs and margin deposits on the Company’s derivative contracts would increase, counterparties may request additional assurances, including collateral, and the potential pool of investors and funding sources may decrease. See Note J to the Condensed Consolidated Financial Statements for further discussion on what is deemed investment grade and a discussion of other factors affecting margin deposit requirements.
The Company’s debt agreements and other financial obligations contain various provisions that could result in termination of the agreements, require early payment of amounts outstanding or similar actions in the event of noncompliance. The most significant covenants and events of default under the debt agreements relate to maintenance of a debt-to-total capitalization ratio, limitations on transactions with affiliates, insolvency events, nonpayment of scheduled principal or interest payments, acceleration of other financial obligations and change of control provisions. The Company’s credit facility contains financial covenants that require a total debt-to-total capitalization ratio of no greater than 65%. The calculation of this ratio excludes the effects of accumulated other comprehensive income (OCI). As of September 30, 2018, the Company was in compliance with all debt provisions and covenants.
EQM’s debt agreements and other financial obligations contain various provisions that could result in termination of the agreements, require early payment of amounts outstanding or similar actions in the event of noncompliance. The most significant covenants and events of default under the debt agreements relate to maintenance of a permitted leverage ratio, limitations on transactions with affiliates, limitations on restricted payments, insolvency events, nonpayment of scheduled principal or interest payments, acceleration of and certain other defaults under other financial obligations and change of control provisions. Under EQM’s $1 billion credit facility, EQM is required to maintain a consolidated leverage ratio of not more than 5.00 to 1.00 (or not more than 5.50 to 1.00 for certain measurement periods following the consummation of certain acquisitions). As of September 30, 2018, EQM was in compliance with all debt provisions and covenants.
See Note M to the Condensed Consolidated Financial Statements for a discussion of the borrowings on the revolving credit facilities.
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Management’s Discussion and Analysis of Financial Condition and Results of Operations
Commodity Risk Management
The substantial majority of the Company’s commodity risk management program is related to hedging sales of the Company’s produced natural gas. The Company’s overall objective in this hedging program is to protect cash flow from undue exposure to the risk of changing commodity prices. The derivative commodity instruments currently utilized by the Company are primarily NYMEX swaps, collars and options.
As of October 23, 2018, the approximate volumes and prices of the Company’s derivative commodity instruments hedging sales of produced gas for 2018 through 2020 were:

NYMEX Swaps |  | 2018 (a)(b)(c) |  | 2019 (b)(c) |  | 2020 (b)
Total Volume (Bcf) |  | 186 |  |  | 600 |  |  | 393 |
Average Price per Mcf (NYMEX) (d) |  | $ | 3.10 |  |  | $ | 2.99 |  |  | $ | 2.98 |
Collars |  |  |  |  |  |
Total Volume (Bcf) |  | 31 |  |  | 73 |  |  | — |
Average Floor Price per Mcf (NYMEX) (d) |  | $ | 3.28 |  |  | $ | 3.12 |  |  | $ | — |
Average Cap Price per Mcf (NYMEX) (d) |  | $ | 3.79 |  |  | $ | 3.60 |  |  | $ | — |
Puts (Long) |  |  |  |  |  |
Total Volume (Bcf) |  | 1 |  |  | 3 |  |  | — |
Average Floor Price per Mcf (NYMEX) |  | $ | 3.02 |  |  | $ | 3.15 |  |  | $ | — |

(a) October through December 31.
(b) The Company also sold calendar year 2018, 2019 and 2020 calls for approximately 28 Bcf, 145 Bcf and 127 Bcf, respectively, at strike prices of $3.45 per Mcf, $3.41 per Mcf and $3.46 per Mcf, respectively. The Company also purchased calendar year 2018, 2019 and 2020 calls for approximately 16 Bcf, 56 Bcf, and 35 Bcf at strike prices of $3.34 per Mcf, $3.38 per Mcf, and $3.36 per Mcf, respectively.

(c) | The Company sold calendar year 2018 and 2019 puts for approximately 8 and 27 Bcf at strike prices of $2.99 and $2.88 per Mcf, respectively.

(d) The average price is based on a conversion rate of 1.05 MMBtu/Mcf.
The Company also enters into fixed price natural gas sales agreements that can be physically or financially settled. The difference between these sales prices and NYMEX are included in average differential on the Company's price reconciliation under "Consolidated Operational Data". The Company has fixed price natural gas sales agreements for the remainder of 2018, 2019 and 2020 of 50 Bcf, 116 Bcf and 9 Bcf, respectively, at average NYMEX prices of $3.03 per Mcf, $2.99 per Mcf and $2.93 per Mcf, respectively. For 2018, the Company has a natural gas sales agreement for approximately 35 Bcf that includes a NYMEX ceiling price of $4.88 per Mcf. For the remainder of 2018, 2019 and 2020, the Company also has a natural gas sales agreement for approximately 2 Bcf, 7 Bcf and 6 Bcf, respectively, that includes a NYMEX floor price of $2.16 per Mcf and a NYMEX ceiling price of $4.47 per Mcf. Currently, the Company has also entered into derivative instruments to hedge basis and a limited number of contracts to hedge its NGLs exposure. The Company may also use other contractual agreements in implementing its commodity hedging strategy.
See Item 3, “Quantitative and Qualitative Disclosures About Market Risk,” and Note J to the Company’s Condensed Consolidated Financial Statements for further discussion of the Company’s hedging program.
Commitments and Contingencies
In the ordinary course of business, various legal and regulatory claims and proceedings are pending or threatened against the Company. 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 actually incurred. The Company has established reserves it believes to be appropriate for pending matters and, after consultation with counsel and giving appropriate consideration to available insurance, the Company believes that the ultimate outcome of any matter currently pending against the Company will not materially affect the Company’s financial position, results of operations or liquidity.
Kay Company, LLC, et al. v. EQT Production Company, et al., United States District Court for the Northern District of West Virginia
On January 16, 2013, several royalty owners who have entered into leases with EQT Production Company, a subsidiary of the Company, filed a gas royalty class action in the Circuit Court of Doddridge County, West Virginia. The suit alleges that EQT
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EQT Corporation and Subsidiaries
Management’s Discussion and Analysis of Financial Condition and Results of Operations
Production Company and a number of related companies, including the Company, EQT Energy, LLC, Equitrans Gathering Holdings, LLC (formerly known as EQT Gathering Holdings, LLC), EQT Investments Holdings, LLC and EQM, have failed to pay royalties on the fair value of the gas produced from the leases and have taken improper post-production deductions from the royalties paid. The plaintiffs seek more than $100,000,000 (according to recently disclosed expert reports) in compensatory damages, punitive damages, and other relief. The Company denies that it underpaid royalties or that it took improper deductions. The Company further refutes that the amount of damages sought is supported by the facts and law and is vigorously defending the case. EQT has reserved approximately $1.5 million related to this case.
On May 31, 2013, the EQT defendants removed the lawsuit to federal court. On September 6, 2017, the district court granted the plaintiffs’ motion to certify the class and granted plaintiffs’ motion for summary judgment, finding that EQT Production Company and its marketing affiliate EQT Energy, LLC are alter egos of one another. The EQT defendants sought immediate appeal of the class certification. On November 30, 2017, the court of appeals declined the request for an immediate review. Trial is scheduled for November 27, 2018. In the event of an adverse judgment, the EQT defendants intend to appeal the class certification, alter ego ruling, and any assessment of liability.
Off-Balance Sheet Arrangements
See Note G to the Condensed Consolidated Financial Statements in this Quarterly Report on Form 10-Q for further discussion of the MVP Joint Venture guarantee.
Dividend
On October 10, 2018, the Board of Directors of the Company declared a regular quarterly cash dividend of three cents per share, payable December 1, 2018, to the Company’s shareholders of record at the close of business on November 9, 2018.
See Notes C, D and E to the Condensed Consolidated Financial Statements in this Quarterly Report on Form 10-Q for discussion of partnership distributions.
Critical Accounting Policies
The Company’s significant 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, 2017. 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 Condensed Consolidated Financial Statements contained in this Quarterly Report on Form 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 Condensed 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.
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Item 3. Quantitative and Qualitative Disclosures About Market Risk
Commodity Price Risk and Derivative Instruments
The Company’s primary market risk exposure is the volatility of future prices for natural gas and NGLs. Due to the volatility of commodity prices, the Company is unable to predict future potential movements in the market prices for natural gas, including Appalachian and other market point basis, and NGLs and thus cannot predict the ultimate impact of prices on its operations. Prolonged low, and/or significant or extended declines in, natural gas and NGLs prices could adversely affect, among other things, the Company’s development plans, which would decrease the pace of development and the level of the Company’s proved reserves. Such changes or similar impacts on third-party shippers on the Company's midstream assets could also impact the Company’s revenues, earnings or liquidity and could result in material non-cash impairments to the recorded value of the Company’s property, plant and equipment.
The Company uses derivatives to reduce the effect of commodity price volatility. The Company’s use of derivatives is further described in Note J to the Condensed Consolidated Financial Statements and under the caption “Commodity Risk Management” in the “Capital Resources and Liquidity” section of Item 2, “Management’s Discussion and Analysis of Financial Condition and Results of Operations” of this Quarterly Report on Form 10-Q. The Company uses derivative commodity instruments that are placed primarily with financial institutions and the creditworthiness of these institutions is regularly monitored. The Company primarily enters into derivative instruments to hedge forecasted sales of production. The Company also enters into derivative instruments to hedge basis and exposure to fluctuations in interest rates. The Company’s use of derivative instruments is implemented under a set of policies approved by the Company’s Hedge and Financial Risk Committee and reviewed by the Audit Committee of the Company’s Board of Directors.
For the derivative commodity instruments used to hedge the Company’s forecasted sales of production, most of which are hedged at NYMEX natural gas prices, the Company sets policy limits relative to the expected production and sales levels which are exposed to price risk. The Company has an insignificant amount of financial natural gas derivative commodity instruments for trading purposes.
The derivative commodity instruments currently utilized by the Company are primarily fixed price swap agreements, collar agreements and option agreements which may require payments to or receipt of payments from counterparties based on the differential between two prices for the commodity. The Company may also use other contractual agreements in implementing its commodity hedging strategy.
The Company monitors price and production levels on a continuous basis and makes adjustments to quantities hedged as warranted. The Company’s overall objective in its hedging program is to protect a portion of cash flows from undue exposure to the risk of changing commodity prices.
For information on the quantity of derivative commodity instruments held by the Company, see Note J to the Condensed Consolidated Financial Statements and the “Commodity Risk Management” section in the “Capital Resources and Liquidity” section of Item 2, “Management’s Discussion and Analysis of Financial Condition and Results of Operations” of this Quarterly Report on Form 10-Q for further discussion.
A hypothetical decrease of 10% in the market price of natural gas from the September 30, 2018 and December 31, 2017 levels would have increased the fair value of these natural gas derivative instruments by approximately $413.0 million and $386.2 million, respectively. A hypothetical increase of 10% in the market price of natural gas from the September 30, 2018 and December 31, 2017 levels would have decreased the fair value of these natural gas derivative instruments by approximately $418.4 million and $384.9 million, respectively. The Company determined the change in the fair value of the derivative commodity instruments using a method similar to its normal determination of fair value as described in Note K to the Condensed Consolidated Financial Statements. The Company assumed a 10% change in the price of natural gas from its levels at September 30, 2018 and December 31, 2017. The price change was then applied to these natural gas derivative commodity instruments recorded on the Company’s Consolidated Balance Sheets, resulting in the hypothetical change in fair value.
The above analysis of the derivative commodity instruments held by the Company does not include the offsetting impact that the same hypothetical price movement may have on the Company’s physical sales of natural gas. The portfolio of derivative commodity instruments held to hedge the Company’s forecasted produced gas approximates a portion of the Company’s expected physical sales of natural gas. Therefore, an adverse impact to the fair value of the portfolio of derivative commodity instruments held to hedge the Company’s forecasted production associated with the hypothetical changes in commodity prices referenced above should be offset by a favorable impact on the Company’s physical sales of natural gas, assuming the derivative commodity instruments
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are not closed out in advance of their expected term, and the derivative commodity instruments continue to function effectively as hedges of the underlying risk.
If the underlying physical transactions or positions are liquidated prior to the maturity of the derivative commodity instruments, a loss on the financial instruments may occur or the derivative commodity instruments might be worthless as determined by the prevailing market value on their termination or maturity date, whichever comes first.
Interest Rate Risk
Changes in interest rates affect the amount of interest the Company, EQGP and EQM earn on cash, cash equivalents and short-term investments and the interest rates the Company and EQM pay on borrowings under their respective revolving credit facilities and the Company's floating rate notes. All of the Company’s and EQM’s Senior Notes, other than the floating rate notes, are fixed rate and thus do not expose the Company to fluctuations in its results of operations or liquidity from changes in market interest rates. Changes in interest rates do affect the fair value of the Company’s and EQM’s fixed rate debt. See Note M to the Condensed Consolidated Financial Statements for further discussion of the Company’s and EQM’s credit facility borrowings, as applicable, and Note K to the Condensed Consolidated Financial Statements for a discussion of fair value measurements, including the fair value of long-term debt.
Other Market Risks
The Company is exposed to credit loss in the event of nonperformance by counterparties to derivative contracts. This credit exposure is limited to derivative contracts with a positive fair value, which may change as market prices change. The Company’s over-the-counter (OTC) derivative instruments are primarily with financial institutions and, thus, are subject to events that would impact those companies individually as well as that industry as a whole. The Company utilizes various processes and analyses to monitor and evaluate its credit risk exposures. These include closely monitoring current market conditions, counterparty credit fundamentals and credit default swap rates. Credit exposure is controlled through credit approvals and limits based on counterparty credit fundamentals. To manage the level of credit risk, the Company enters into transactions with financial counterparties that are of investment grade, enters into netting agreements whenever possible and may obtain collateral or other security.
Approximately 63%, or $315.6 million, of the Company’s OTC derivative contracts outstanding at September 30, 2018 had a positive fair value. Approximately 63%, or $242.0 million, of the Company’s OTC derivative contracts outstanding at December 31, 2017 had a positive fair value.
As of September 30, 2018, the Company was not in default under any derivative contracts and had no knowledge of default by any counterparty to its derivative contracts. The Company made no adjustments to the fair value of derivative contracts due to credit related concerns outside of the normal non-performance risk adjustment included in the Company’s established fair value procedure. The Company monitors market conditions that may impact the fair value of derivative contracts reported in the Condensed Consolidated Balance Sheets.
The Company is also exposed to the risk of nonperformance by credit customers on physical sales or transportation of natural gas. A significant amount of revenues and related accounts receivable are generated from the sale of produced natural gas and NGLs to certain marketers, utility and industrial customers located mainly in the Appalachian Basin and in markets available through the Company's current transportation portfolio, which includes markets in the Gulf Coast, Midwest and Northeast United States. The Company also contracts with certain processors to market a portion of NGLs on behalf of the Company. Similarly, revenues and related accounts receivable are generated from the gathering, transmission and storage of natural gas in the Appalachian Basin for independent producers, local distribution companies and marketers.
No one lender of the large group of financial institutions in the syndicates for the EQT and EQM credit facilities holds more than 10% of the respective facility. The large syndicate groups and relatively low percentage of participation by each lender are expected to limit the Company’s and EQM's exposure to disruption or consolidation in the banking industry.
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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 Securities Exchange Act of 1934, as amended (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
As noted under Item 9A, “Controls and Procedures,” contained in the Company’s Annual Report on Form 10-K for the year ended December 31, 2017, management’s assessment of, and conclusion on, the effectiveness of internal control over financial reporting did not include the internal controls of the entities acquired in the Rice Merger on November 13, 2017. Under guidelines established by the SEC, companies are permitted to exclude acquisitions from their assessment of internal control over financial reporting for a period of up to one year following an acquisition while integrating the acquired company. The Company is in the process of integrating Rice’s and the Company’s internal controls over financial reporting. As a result of these integration activities, certain controls will be evaluated and may be changed. Except as noted above, there were no changes in the Company’s internal control over financial reporting that occurred during the third quarter of 2018 that have materially affected, or are reasonably likely to materially affect, the Company’s internal control over financial reporting.
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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. 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 actually incurred. The Company has established reserves it believes to be appropriate for pending matters and, after consultation with counsel and giving appropriate consideration to available insurance, the Company believes that the ultimate outcome of any matter currently pending against the Company will not materially affect the financial position, results of operations or liquidity of the Company.
Environmental Proceedings
Phoenix S Impoundment, Tioga County, Pennsylvania
In June and August 2012, the Company received three Notices of Violation (NOVs) from the Pennsylvania Department of Environmental Protection (the PADEP). The NOVs alleged violations of the Pennsylvania Oil and Gas Act and Clean Streams Law in connection with the unintentional release in May 2012, by a Company vendor, of water from an impaired water pit at a Company well location in Tioga County, Pennsylvania. Since confirming a release, the Company has cooperated with the PADEP in remediating the affected areas.
During the second quarter of 2014, the Company received a proposed consent assessment of civil penalty from the PADEP that proposed a civil penalty related to the NOVs. On September 19, 2014, the Company filed a declaratory judgment action in the Commonwealth Court of Pennsylvania against the PADEP seeking a court ruling on the PADEP’s legal interpretation of the penalty provisions of the Clean Streams Law, which interpretation the Company believed was legally flawed and unsupportable. On October 7, 2014, based on its interpretation of the penalty provisions, the PADEP filed a complaint against the Company before the Pennsylvania Environmental Hearing Board (the EHB) seeking $4.53 million in civil penalties. In January 2017, the Commonwealth Court ruled in favor of the Company, finding the PADEP’s interpretation of the penalty provisions of the Clean Streams Law erroneous. The PADEP appealed that decision to the Pennsylvania Supreme Court, and the parties made oral arguments in front of the Pennsylvania Supreme Court on November 28, 2017. Following a July 2016 hearing before the EHB, in May 2017, the EHB ruled that the Company should pay $1.1 million in civil penalties. In June 2017, both the Company and the PADEP appealed the EHB’s decision to the Commonwealth Court. In September 2018, the Commonwealth Court upheld the $1.1 million-dollar civil penalty, which the Company will pay. The payment of the civil penalty will not have a material impact on the financial condition, results of operations or liquidity of the Company.
Wilson Creek Water Withdrawals, Tioga County, Pennsylvania
On June 7, 2018, the Company received an NOV from the Susquehanna River Basin Commission (the SRBC). The NOV alleged violations of the Company’s Water Management Plan and its Wilson Creek Docket related to the withdrawal of water from Wilson Creek in Tioga County, Pennsylvania, between March 14, 2018 and April 3, 2018, when the stream flow was below the required flow protection threshold set forth in the Docket. The Company cooperated fully with the SRBC to address the matter. Civil penalty settlement discussions between the Company and the SRBC are ongoing. While the Company expects the SRBC’s claims to result in penalties that exceed $100,000, the Company expects that the resolution of this matter will not have a material impact on the financial condition, results of operations or liquidity of the Company.
Erosion and Sedimentation Best Management Practice BMP Failures, Allegheny County, Pennsylvania
Between November 2017 and March 2018, the Company received multiple NOVs from the PADEP relating to four of the Company’s well pads in Allegheny County, Pennsylvania. During this time period, Pennsylvania experienced unprecedented amounts of rainfall. The NOVs alleged violations of the Oil and Gas Act, and Clean Stream Law in connection with the effects of this rainfall on erosion and sedimentation controls at the Prentice, Fetchen, Oliver East, and Oliver West well pads. The Company has cooperated fully with the PADEP to take appropriate actions to address the erosion and sedimentation control issues. The Company and the PADEP are currently negotiating a civil penalty settlement. While the Company expects the PADEP’s claims to result in penalties that exceed $100,000, the Company expects that the resolution of this matter will not have a material impact on the financial condition, results of operations or liquidity of the Company.
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Other
Kay Company, LLC, et al. v. EQT Production Company, et al., United States District Court for the Northern District of West Virginia
On January 16, 2013, several royalty owners who have entered into leases with EQT Production Company, a subsidiary of the Company, filed a gas royalty class action in the Circuit Court of Doddridge County, West Virginia. The suit alleges that EQT Production Company and a number of related companies, including the Company, EQT Energy, LLC, Equitrans Gathering Holdings, LLC (formerly known as EQT Gathering Holdings, LLC), EQT Investments Holdings, LLC and EQM, have failed to pay royalties on the fair value of the gas produced from the leases and have taken improper post-production deductions from the royalties paid. The plaintiffs seek more than $100,000,000 (according to recently disclosed expert reports) in compensatory damages, punitive damages, and other relief. The Company denies that it underpaid royalties or that it took improper deductions. The Company further refutes that the amount of damages sought is supported by the facts and law and is vigorously defending the case. EQT has reserved approximately $1.5 million related to this case.
On May 31, 2013, the EQT defendants removed the lawsuit to federal court. On September 6, 2017, the district court granted the plaintiffs’ motion to certify the class and granted plaintiffs’ motion for summary judgment, finding that EQT Production Company and its marketing affiliate EQT Energy, LLC are alter egos of one another. The EQT defendants sought immediate appeal of the class certification. On November 30, 2017, the court of appeals declined the request for an immediate review. Trial is scheduled for November 27, 2018. In the event of an adverse judgment, the EQT defendants intend to appeal the class certification, alter ego ruling, and any assessment of liability.
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, 2017, other than those listed in this section.
Our plan to separate into two independent publicly-traded companies is subject to various risks and uncertainties and may not be completed in accordance with the expected plans or anticipated timeline, or at all, and will involve significant time and expense, which could disrupt or adversely affect our business.
On February 21, 2018, we announced plans to separate into two independent publicly-traded companies. Completion of the Separation was approved by our Board of Directors on October 24, 2018; however, the Separation and Distribution remain subject to market, regulatory and certain other conditions. Unanticipated developments, including changes in the competitive conditions of our upstream and midstream businesses, possible delays in obtaining various tax opinions or rulings, regulatory approvals or clearances, the uncertainty of the financial markets and challenges in executing the Separation, could delay or prevent the completion of the proposed Separation, or cause the proposed Separation to occur on terms or conditions that are different or less favorable than expected.
We expect that the process of completing the proposed Separation will be time-consuming and involve significant costs and expenses, which may be significantly higher than what we currently anticipate and may not yield a discernible benefit if the Separation is not completed. Executing the proposed Separation will require significant time and attention from our senior management and employees, which could adversely affect our business, financial results and results of operations. We may also experience increased difficulties in attracting, retaining and motivating employees during the pendency of the Separation and following its completion, which could harm our businesses.
The Separation may not achieve some or all of the anticipated benefits.
We may not realize some or all of the anticipated strategic, financial, operational or other benefits from the Separation. As independent publicly-traded companies, our upstream and midstream businesses will be smaller, less diversified companies with a narrower business focus and may be more vulnerable to changing market conditions, which could materially and adversely affect their respective business, financial condition and results of operations. Further, there can be no assurance that the combined value of the common stock of the two publicly-traded companies will be equal to or greater than what the value of our common stock would have been had the proposed Separation not occurred.
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The Separation and Distribution could result in substantial tax liability.
The Separation will be effected by a pro rata distribution to our shareholders of 80.1% of the outstanding stock of Equitrans Midstream. We have obtained (i) a private letter ruling from the U.S. Internal Revenue Service (the IRS) and intend to obtain (ii) one or more opinions of outside counsel regarding the qualification of the Distribution, together with certain related transactions, as a transaction that is generally tax-free, for U.S. federal income tax purposes, under Sections 355 and 368(a)(1)(D) of the U.S. Internal Revenue Code (the Code) and certain other U.S. federal income tax matters relating to the Distribution and certain related transactions. The IRS private letter ruling and the opinion of counsel will be based upon and rely on, among other things, various facts and assumptions, as well as certain representations, statements and undertakings of us and Equitrans Midstream, including those relating to the past and future conduct of us and Equitrans Midstream. If any of these representations, statements or undertakings is, or becomes, inaccurate or incomplete, or if we or Equitrans Midstream breach any representations or covenants contained in any of the Separation-related agreements and documents or in any documents relating to the IRS private letter ruling and/or the opinion of counsel, the IRS private letter ruling and/or the opinion of counsel may be invalid and the conclusions reached therein could be jeopardized.
Notwithstanding receipt of the IRS private letter ruling and the opinion of counsel, the IRS could determine that the Distribution and/or certain related transactions should be treated as taxable transactions for U.S. federal income tax purposes if it determines that any of the representations, assumptions or undertakings upon which the IRS private letter ruling or the opinion of counsel was based are false or have been violated. In addition, any opinion of counsel will represent the judgment of such counsel and is not binding on the IRS or any court and the IRS or a court may disagree with the conclusions in such opinion of counsel. Accordingly, notwithstanding receipt of the IRS private letter ruling and the opinion of counsel, there can be no assurance that the IRS will not assert that the Distribution and/or certain related transactions do not qualify for the intended tax treatment or that a court would not sustain such a challenge. In the event the IRS were to prevail with such challenge, we, Equitrans Midstream and our shareholders could be subject to material U.S. federal income tax liability.
Even if the Distribution otherwise qualifies as generally tax-free under Section 355 and Section 368(a)(1)(D) of the Code, it would result in a material U.S. federal income tax liability to us (but not to our shareholders) under Section 355(e) of the Code if one or more persons acquire, directly or indirectly, a 50-percent or greater interest (measured by either vote or value) in our stock or in the stock of Equitrans Midstream (excluding, for this purpose, the acquisition of stock of Equitrans Midstream by holders of our stock in the Distribution) as part of a plan or series of related transactions that includes the Distribution. Any acquisition of our stock or stock of Equitrans Midstream (or any predecessor or successor corporation) within two years before or after the Distribution generally would be presumed to be part of a plan that includes the Distribution, although the parties may be able to rebut that presumption under certain circumstances. The process for determining whether an acquisition is part of a plan under these rules is complex, inherently factual in nature and subject to a comprehensive analysis of the facts and circumstances of the particular case. Notwithstanding the IRS private letter ruling or any opinion of counsel described above, we or Equitrans Midstream may cause or permit a change in ownership of our stock or stock of Equitrans Midstream sufficient to result in a material tax liability to us.
In connection with the Distribution and to effect the Separation, we expect to effect certain restructuring transactions that are expected to be taxable to us (but not our shareholders) and to result in a material tax liability, which we expect to be offset in part by certain tax attributes.
We may determine to forgo certain transactions in order to avoid the risk of incurring material tax-related liabilities.
As a result of requirements of Section 355 of the Code and/or other applicable tax laws, we may determine to forgo certain transactions that would otherwise be advantageous. In particular, we may determine to continue to operate certain of our business operations for the foreseeable future even if a sale or discontinuance of such business would otherwise be advantageous. Moreover, in light of the requirements of Section 355(e) of the Code, we may determine to forgo certain transactions, including share repurchases, stock issuances, certain asset dispositions and other strategic transactions, for some period of time following the Separation.
The proposed Separation may result in disruptions to, and negatively impact our relationships with, our customers and other business partners.
Uncertainty related to the proposed Separation may lead customers and other parties with which we currently do business or may do business in the future to terminate or attempt to negotiate changes in existing business relationships, or consider entering into business relationships with parties other than us. These disruptions could have a material and adverse effect on our business,
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financial condition, results of operations and prospects. Further, the effect of such disruptions could be exacerbated by any delays in the completion of the Separation.
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 EQM's 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 its ability to achieve the expected investment return on the project.
Certain of EQM’s internal growth projects may require regulatory approval from federal, state and local authorities prior to construction, including any extensions from or additions to our transmission and storage system. The approval process for storage and transportation projects has become increasingly challenging, due in part to state and local concerns related to exploration and production and gathering activities in new production areas, including the Marcellus, Utica and Upper Devonian Shales, and negative public perception regarding the oil and gas industry. Such authorization may not be granted or, if granted, such authorization may include burdensome or expensive conditions.
In addition, any significant delays in the regulatory approval process for the MVP project could increase costs and negatively impact the scheduled in-service date of fourth quarter 2019, which in turn could adversely affect the ability for MVP and its owners, including EQM, to achieve the expected investment return. The MVP project is subject to several challenges that must be resolved before the MVP project can be completed. For example, on October 2, 2018, the Fourth Circuit Court of Appeals vacated the MVP project’s use of U.S. Army Corps of Engineers Nationwide Permit 12 in West Virginia. In related proceedings, the MVP project’s use of Nationwide Permit 12 has also been stayed on other segments of the project.
Although the MVP Joint Venture is actively defending the relevant agency actions and judicial challenges to the project, and is in active dialogue with all of the affected agencies to resolve these issues and restore the affected permits, there is no guarantee as to how long the agency proceedings and judicial challenges will take to resolve, or whether the MVP Joint Venture will ultimately succeed in restoring the permits in their present form or within the MVP Joint Venture's targeted time frame for placing the project in service. This and other similar litigation could adversely affect EQM's business, financial condition, results of operations, liquidity and ability to make quarterly cash distributions to its unitholders, including us and EQGP.
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Item 2. Unregistered Sales of Equity Securities and Use of Proceeds
The following table sets forth the Company’s repurchases of equity securities registered under Section 12 of the Exchange Act that have occurred during the three months ended September 30, 2018:

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 (b)
July 2018 (July 1 – July 31) |  | 436,944 |  |  | $ | 49.62 |  |  | 436,944 |  |  | $ | 478,322,854 |
August 2018 (August 1 – August 31) |  | 9,516,164 |  |  | 50.46 |  |  | 9,509,438 |  |  | — |
September 2018 (September 1 – September 30) |  | 21,627 |  |  | 50.53 |  |  | — |  |  | — |
Total |  | 9,974,735 |  |  | $ | 50.39 |  |  | 9,946,382 |  |  | — |

(a) | Reflects the number of shares withheld by the Company to pay taxes upon vesting of restricted stock plus the number of shares purchased as part of publicly announced plans or programs.

(b) | On July 11, 2018, the Company’s Board of Directors approved a share repurchase authorization to repurchase shares of the Company’s outstanding common stock for an aggregate purchase price of not more than $500 million. Pursuant to the share repurchase authorization, the Company may repurchase shares from time to time in open market or in privately negotiated transactions. The share repurchase authorization does not obligate the Company to acquire any specific number of shares, has no pre-established end date and may be discontinued by the Company at any time. As of September 30, 2018, the Company had purchased shares for an aggregate purchase price of $500 million under this authorization, and therefore no additional shares may be purchased under this authorization.

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Item 6. Exhibits

Exhibit No. |  | Description |  | Method of Filing
10.1 |  |  | Agreement and Release, dated as of August 13, 2018, between the Company and Jeremiah J. Ashcroft III |  | Filed herewith as Exhibit 10.1
10.2 |  |  | Offer letter dated as of August 9, 2018, between the Company and Thomas F. Karam |  | Filed herewith as Exhibit 10.2
10.3 |  |  | Confidentiality, Non-Solicitation and Non-Competition Agreement, dated as of August 9, 2018, between the Company and Thomas F. Karam |  | Filed herewith as Exhibit 10.3
10.4 |  |  | Amendment to 1999 Directors’ Deferred Compensation Plan (as amended October 2, 2018) |  | Filed herewith as Exhibit 10.4
10.5 |  |  | Amendment to 2005 Directors’ Deferred Compensation Plan (as amended October 2, 2018) |  | Filed herewith as Exhibit 10.5
31.01 |  |  | Rule 13(a)-14(a) Certification of Principal Executive Officer |  | Filed herewith as Exhibit 31.01
31.02 |  |  | Rule 13(a)-14(a) Certification of Principal Financial Officer |  | Filed herewith as Exhibit 31.02
32 |  |  | Section 1350 Certification of Principal Executive Officer and Principal Financial Officer |  | Furnished herewith as Exhibit 32
101 |  |  | Interactive Data File |  | Filed herewith as Exhibit 101

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Table of Contents
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.

|  | EQT CORPORATION
|  | (Registrant)
| By: | /s/ Robert J. McNally
|  | Robert J. McNally
|  | Senior Vice President and Chief Financial Officer

Date: October 25, 2018
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