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EX-32 - EXHIBIT 32 - EQT Corpeqtq32016ex32.htm
EX-31.02 - EXHIBIT 31.02 - EQT Corpeqtq32016ex3102.htm
EX-31.01 - EXHIBIT 31.01 - EQT Corpeqtq32016ex3101.htm

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, 2016
 
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 1-3551
 
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 and posted on its corporate Web site, if any, every Interactive Data File required to be submitted and posted 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 and post such files).  Yes x  No ¨
 
Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer, or a smaller reporting company.  See the definitions of “large accelerated filer,” “accelerated filer” and “smaller reporting company” in Rule 12b-2 of the Exchange Act.
 
Large Accelerated Filer  x
 
Accelerated Filer                 ¨
Non-Accelerated Filer    ¨
 
Smaller reporting company ¨
 
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, 2016, 172,758 (in thousands) shares of common stock, no par value, of the registrant were outstanding.



EQT CORPORATION AND SUBSIDIARIES
 
Index
 
 
 
Page No.
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 

2

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,
 
2016
 
2015
 
2016
 
2015
 
(Thousands, except per share amounts)
Revenues:
 
 
 
 
 
 
 
Sales of natural gas, oil and NGLs
$
403,939

 
$
365,940

 
$
1,072,898

 
$
1,326,104

Pipeline and marketing services
59,431

 
56,775

 
188,770

 
203,164

Gain (loss) on derivatives not designated as hedges
93,356

 
161,263

 
(32,342
)
 
209,114

Total operating revenues
556,726

 
583,978

 
1,229,326

 
1,738,382

 
 
 
 
 
 
 
 
Operating expenses:
 

 
 

 
 

 
 

Transportation and processing
89,883

 
71,996

 
251,283

 
207,129

Operation and maintenance
31,185

 
32,385

 
91,921

 
92,693

Production
26,058

 
32,505

 
85,998

 
95,353

Exploration
2,671

 
8,177

 
9,385

 
32,153

Selling, general and administrative
61,384

 
60,633

 
196,625

 
189,163

Depreciation, depletion and amortization
237,088

 
208,227

 
682,948

 
599,791

Impairment of long-lived assets

 

 

 
4,252

Total operating expenses
448,269

 
413,923

 
1,318,160

 
1,220,534

 
 
 
 
 
 
 
 
Operating income (loss)
108,457

 
170,055

 
(88,834
)
 
517,848

 
 
 
 
 
 
 
 
Other income
10,715

 
2,661

 
23,199

 
6,289

Interest expense
35,984

 
36,547

 
108,469

 
110,596

Income (loss) before income taxes
83,188

 
136,169

 
(174,104
)
 
413,541

Income tax expense (benefit)
13,084

 
35,936

 
(151,826
)
 
28,393

Net income (loss)
70,104

 
100,233

 
(22,278
)
 
385,148

Less: Net income attributable to noncontrolling interests
78,120

 
59,446

 
238,747

 
165,398

Net (loss) income attributable to EQT Corporation
$
(8,016
)
 
$
40,787

 
$
(261,025
)
 
$
219,750

 
 
 
 
 
 
 
 
Earnings per share of common stock attributable to EQT Corporation:
 

 
 

 
 

 
 

Basic:
 

 
 

 
 

 
 

Weighted average common stock outstanding
172,867

 
152,551

 
165,197

 
152,326

Net (loss) income
$
(0.05
)
 
$
0.27

 
$
(1.58
)
 
$
1.44

Diluted:
 

 
 

 
 

 
 

Weighted average common stock outstanding
172,867

 
152,854

 
165,197

 
152,789

Net (loss) income
$
(0.05
)
 
$
0.27

 
$
(1.58
)
 
$
1.44

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.

3


EQT CORPORATION AND SUBSIDIARIES
 
Statements of Consolidated Comprehensive (Loss) Income (Unaudited)
 
 
Three Months Ended September 30,
 
Nine Months Ended September 30,
 
2016
 
2015
 
2016
 
2015
 
(Thousands)
Net income (loss)
$
70,104

 
$
100,233

 
$
(22,278
)
 
$
385,148

 
 
 
 
 
 
 
 
Other comprehensive (loss) income, net of tax:
 

 
 

 
 

 
 

Net change in cash flow hedges:
 

 
 

 
 

 
 

Natural gas, net of tax benefit of $(9,894), $(26,093), $(28,934), and $(81,279)
(14,740
)
 
(39,346
)
 
(43,104
)
 
(122,678
)
Interest rate, net of tax expense of $26, $25, $78, and $75
36

 
36

 
108

 
108

Pension and other post-retirement benefits liability adjustment, net of tax expense of $52, $127, $6,287, and $382
82

 
202

 
9,917

 
606

Other comprehensive loss
(14,622
)
 
(39,108
)
 
(33,079
)
 
(121,964
)
Comprehensive income (loss)
55,482

 
61,125

 
(55,357
)
 
263,184

Less: Comprehensive income attributable to noncontrolling interests
78,120

 
59,446

 
238,747

 
165,398

Comprehensive (loss) income attributable to EQT Corporation
$
(22,638
)
 
$
1,679

 
$
(294,104
)
 
$
97,786

 
The accompanying notes are an integral part of these Condensed Consolidated Financial Statements.
 

4


EQT CORPORATION AND SUBSIDIARIES

Statements of Condensed Consolidated Cash Flows (Unaudited)

 
Nine Months Ended September 30,
 
2016
 
2015
 
(Thousands)
Cash flows from operating activities:
 
Net (loss) income
$
(22,278
)
 
$
385,148

Adjustments to reconcile net (loss) income to net cash provided by operating activities:
 

 
 

Deferred income tax benefit
(145,739
)
 
(78,958
)
Depreciation, depletion and amortization
682,948

 
599,791

Asset and lease impairments
5,498

 
35,004

Provision for losses on (recoveries of) accounts receivable
1,165

 
(2,262
)
Other income
(23,199
)
 
(6,276
)
Stock-based compensation expense
34,551

 
41,622

Loss (gain) on derivatives not designated as hedges
32,342

 
(209,114
)
Cash settlements received on derivatives not designated as hedges
222,516

 
70,874

Pension settlement charge
9,403

 

Changes in other assets and liabilities:
 

 
 

Excess tax benefits on stock-based compensation

 
(21,176
)
Accounts receivable
(11,521
)
 
161,118

Accounts payable
(12,916
)
 
(84,262
)
Other items, net
(5,071
)
 
8,709

Net cash provided by operating activities
767,699

 
900,218

 
 
 
 
Cash flows from investing activities:
 

 
 

Capital expenditures
(1,193,321
)
 
(1,899,338
)
Consideration paid for Statoil acquisition
(412,348
)
 

Capital contributions to Mountain Valley Pipeline, LLC
(76,297
)
 
(84,182
)
Sales of interests in Mountain Valley Pipeline, LLC
12,533

 
8,344

Net cash used in investing activities
(1,669,433
)
 
(1,975,176
)
 
 
 
 
Cash flows from financing activities:
 

 
 

Proceeds from the issuance of common shares of EQT Corporation, net of issuance costs
1,225,999

 

Proceeds from the issuance of common units of EQT Midstream Partners, LP, net of issuance costs
217,102

 
758,812

Proceeds from the sale of common units of EQT GP Holdings, LP, net of sale costs

 
674,010

Increase in borrowings on EQT Midstream Partners, LP credit facility
430,000

 
561,500

Repayment of borrowings on EQT Midstream Partners, LP credit facility
(638,000
)
 
(211,500
)
Dividends paid
(14,966
)
 
(13,725
)
Distributions to noncontrolling interests
(137,719
)
 
(85,218
)
Repayments and retirements of long-term debt

 
(9,004
)
Proceeds and excess tax benefits from awards under employee compensation plans
2,040

 
35,196

Cash paid for taxes related to net settlement of share-based incentive awards
(26,517
)
 
(46,492
)
Repurchase of common stock
(23
)
 
(3,375
)
Net cash provided by financing activities
1,057,916

 
1,660,204

Net change in cash and cash equivalents
156,182

 
585,246

Cash and cash equivalents at beginning of period
1,601,232

 
1,077,429

Cash and cash equivalents at end of period
$
1,757,414

 
$
1,662,675

 
 
 
 
Cash paid during the period for:
 

 
 

Interest, net of amount capitalized
$
88,281

 
$
87,661

Income taxes, net
$
1,294

 
$
100,987

 
 
 
 
Non-cash activity during the period for:
 
 
 
Increase in Mountain Valley Pipeline, LLC investment/payable for capital contributions
$
13,095

 
$

 

The accompanying notes are an integral part of these Condensed Consolidated Financial Statements.

5


EQT CORPORATION AND SUBSIDIARIES
 
Condensed Consolidated Balance Sheets (Unaudited)
 
 
September 30, 2016
 
December 31, 2015
 
(Thousands)
Assets
 

 
 

 
 
 
 
Current assets:
 

 
 

Cash and cash equivalents
$
1,757,414

 
$
1,601,232

Accounts receivable (less accumulated provision for doubtful accounts:
$4,231 at September 30, 2016 and $3,018 at December 31, 2015)
189,416

 
176,957

Derivative instruments, at fair value
134,698

 
417,397

Prepaid expenses and other
64,541

 
55,433

Total current assets
2,146,069

 
2,251,019

 
 
 
 
Property, plant and equipment
17,238,045

 
15,635,549

Less: accumulated depreciation and depletion
4,830,265

 
4,163,528

Net property, plant and equipment
12,407,780

 
11,472,021

 
 
 
 
Investment in nonconsolidated entity
160,326

 
77,025

Other assets
175,809

 
176,107

Total assets
$
14,889,984

 
$
13,976,172

  
The accompanying notes are an integral part of these Condensed Consolidated Financial Statements.

6


EQT CORPORATION AND SUBSIDIARIES
 
Condensed Consolidated Balance Sheets (Unaudited)

 
September 30, 2016
 
December 31, 2015
 
(Thousands)
Liabilities and Stockholders’ Equity
 

 
 

 
 
 
 
Current liabilities:
 

 
 

Credit facility borrowings
$
91,000

 
$
299,000

Accounts payable
264,782

 
291,550

Derivative instruments, at fair value
67,871

 
23,434

Other current liabilities
194,973

 
181,835

Total current liabilities
618,626

 
795,819

 
 
 
 
Long-term debt
2,796,759

 
2,793,343

Deferred income taxes
1,817,894

 
1,972,170

Other liabilities and credits
382,426

 
386,798

Total liabilities
5,615,705

 
5,948,130

 
 
 
 
Equity:
 

 
 

Stockholders’ equity:
 

 
 

Common stock, no par value, authorized 320,000 shares, shares issued:
177,897 at September 30, 2016 and 158,347 at December 31, 2015
3,418,979

 
2,153,280

Treasury stock, shares at cost: 5,139 at September 30, 2016 (including 226 held in rabbi trust) and 5,793 at December 31, 2015 (including 292 held in rabbi trust)
(92,275
)
 
(104,079
)
Retained earnings
2,706,221

 
2,982,212

Accumulated other comprehensive income
13,299

 
46,378

Total common stockholders’ equity
6,046,224

 
5,077,791

Noncontrolling interests in consolidated subsidiaries
3,228,055

 
2,950,251

Total equity
9,274,279

 
8,028,042

Total liabilities and equity
$
14,889,984

 
$
13,976,172


The accompanying notes are an integral part of these Condensed Consolidated Financial Statements.


7


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, 2015
151,596

 
$
1,466,192

 
$
2,917,129

 
$
199,494

 
$
1,790,248

 
$
6,373,063

Comprehensive income (net of tax):
 
 
 
 
 
 
 
 
 
 
 
Net income
 

 
 

 
219,750

 
 

 
165,398

 
385,148

Net change in cash flow hedges:
 

 
 

 
 

 
 
 
 

 
 
Natural gas, net of tax benefit of $(81,279)
 
 
 
 
 
 
(122,678
)
 
 
 
(122,678
)
Interest rate, net of tax expense of $75
 
 
 
 
 
 
108

 
 
 
108

Pension and other post-retirement benefits liability adjustment,
net of tax expense of $382
 
 
 
 
 
 
606

 
 
 
606

Dividends ($0.09 per share)
 

 
 

 
(13,725
)
 
 

 
 

 
(13,725
)
Stock-based compensation plans, net
982

 
54,238

 
 

 
 

 
796

 
55,034

Distributions to noncontrolling interests ($1.83 and $0.04739 per common unit from EQT Midstream Partners, LP and EQT GP Holdings, LP, respectively)
 

 
 

 
 

 
 

 
(85,218
)
 
(85,218
)
Issuance of common units of EQT Midstream Partners, LP


 


 


 


 
758,812

 
758,812

Sale of common units of EQT GP Holdings, LP
 
 
 
 
 
 
 
 
674,010

 
674,010

Changes in ownership of consolidated subsidiary, net


 
453,778

 


 
 
 
(723,290
)
 
(269,512
)
Repurchase and retirement of common stock
(38
)
 
(1,597
)
 
(1,778
)
 
 
 
 
 
(3,375
)
Balance, September 30, 2015
152,540

 
$
1,972,611

 
$
3,121,376

 
$
77,530

 
$
2,580,756

 
$
7,752,273

 
 
 
 
 
 
 
 
 
 
 
 
Balance, January 1, 2016
152,554

 
$
2,049,201

 
$
2,982,212

 
$
46,378

 
$
2,950,251

 
$
8,028,042

Comprehensive income (net of tax):
 
 
 
 
 
 
 
 
 
 
 
Net (loss) income
 

 
 

 
(261,025
)
 
 

 
238,747

 
(22,278
)
Net change in cash flow hedges:
 

 
 

 
 

 
 
 
 

 
 
Natural gas, net of tax benefit of $(28,934)
 
 
 
 
 
 
(43,104
)
 
 
 
(43,104
)
Interest rate, net of tax expense of $78
 
 
 
 
 
 
108

 
 
 
108

Pension and other post-retirement benefits liability adjustment,
net of tax expense of $6,287
 
 
 
 
 
 
9,917

 
 
 
9,917

Dividends ($0.09 per share)
 

 
 

 
(14,966
)
 
 

 
 

 
(14,966
)
Stock-based compensation plans, net
654

 
26,211

 
 

 
 

 
161

 
26,372

Distributions to noncontrolling interests ($2.235 and $0.406 per common unit from EQT Midstream Partners, LP and EQT GP Holdings, LP, respectively)
 

 
 

 
 

 
 

 
(137,719
)
 
(137,719
)
Issuance of common shares of EQT Corporation
19,550

 
1,225,999

 
 
 
 
 


 
1,225,999

Issuance of common units of EQT Midstream Partners, LP
 

 
 

 
 

 
 

 
217,102

 
217,102

Changes in ownership of consolidated subsidiaries
 
 
25,293

 
 
 
 
 
(40,487
)
 
(15,194
)
Balance, September 30, 2016
172,758

 
$
3,326,704

 
$
2,706,221

 
$
13,299

 
$
3,228,055

 
$
9,274,279

 
The accompanying notes are an integral part of these Condensed Consolidated Financial Statements.


8

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 Form 10-Q) necessary for a fair presentation of the financial position of EQT Corporation and subsidiaries as of September 30, 2016 and December 31, 2015, the results of its operations for the three and nine month periods ended September 30, 2016 and 2015 and its cash flows for the nine month periods ended September 30, 2016 and 2015.  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.
 
Certain previously reported amounts have been reclassified to conform to the current year presentation. The impact of these reclassifications was not material to any of the previously issued financial statements.

The balance sheet at December 31, 2015 has been derived from the audited financial statements at that date but does not include all of the information and footnotes required by United States GAAP for complete financial statements.

On May 2, 2016, the Company entered into an Underwriting Agreement with Credit Suisse Securities (USA) LLC and J.P. Morgan Securities LLC, as representatives of the several underwriters named in the Underwriting Agreement (the Underwriters), under which the Company sold to the Underwriters 10,500,000 shares of the Company's common stock, no par value (common stock), at a price to the public of $67.00 per share (the May Offering). On May 3, 2016, the Underwriters exercised their option within the Underwriting Agreement to purchase an additional 1,575,000 shares of common stock on the same terms. The May Offering closed on May 6, 2016, and the Company received net proceeds of approximately $795.6 million after deducting underwriting discounts and commissions and offering expenses. The Company used a portion of the net proceeds from the May Offering to fund the Statoil Acquisition discussed in Note N, and intends to use the remainder to fund the acquisitions discussed in Note O and for general corporate purposes.

On February 19, 2016, the Company entered into an Underwriting Agreement with Goldman, Sachs & Co. (Goldman) under which the Company sold to Goldman 6,500,000 shares of common stock, at a price to the public of $58.50 per share (the February Offering). On February 22, 2016, Goldman exercised its option within the Underwriting Agreement to purchase an additional 975,000 shares of common stock on the same terms. The February Offering closed on February 24, 2016, and the Company received net proceeds of approximately $430.4 million, after deducting underwriting discounts and commissions and offering expenses. The Company intends to use the net proceeds from the February Offering for general corporate purposes.

For further information, refer to the consolidated financial statements and footnotes thereto included in the Company’s Annual Report on Form 10-K for the year ended December 31, 2015 as well as “Management’s Discussion and Analysis of Financial Condition and Results of Operations” beginning on page 23 of this Quarterly Report on Form 10-Q.

B.                        EQT GP Holdings, LP

In January 2015, the Company formed EQT GP Holdings, LP (EQGP) (NYSE: EQGP), a Delaware limited partnership, to own the Company's partnership interests in EQT Midstream Partners, LP (EQM) (NYSE: EQM). EQGP owned the following EQM partnership interests as of September 30, 2016, which represent EQGP’s only cash-generating assets: 21,811,643 EQM common units, representing a 26.6% limited partner interest in EQM; 1,443,015 EQM general partner units, representing a 1.8% general partner interest in EQM; and all of EQM’s incentive distribution rights, or 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. The Company is the ultimate parent company of EQGP and EQM.

On May 15, 2015, EQGP completed an underwritten initial public offering (IPO) of 26,450,000 common units representing limited partner interests in EQGP, which represented 9.9% of EQGP’s outstanding limited partner interests. The Company retained 239,715,000 common units, which represented a 90.1% limited partner interest, and a non-economic general partner interest in EQGP. EQT Gathering Holdings, LLC, an indirect wholly owned subsidiary of the Company, was the selling unitholder and sold all of the EQGP common units in the offering. The IPO resulted in net proceeds to the Company of approximately $674.0 million after deducting the underwriters' discount of approximately $37.5 million and structuring fees of approximately $2.7 million. EQGP did not receive any of the proceeds from, or incur any expenses in connection with, the IPO.

9

EQT Corporation and Subsidiaries
Notes to the Condensed Consolidated Financial Statements (Unaudited) 


The Company continues to consolidate the results of EQGP, but records an income tax provision only as to its ownership percentage.  The Company records the noncontrolling interest of the EQGP and EQM public limited partners (i.e., the EQGP limited partner interests not owned by the Company and the EQM limited partner interests not owned by EQGP) in its financial statements.

On October 25, 2016, the Board of Directors of EQGP’s general partner declared a cash distribution to EQGP’s unitholders for the third quarter of 2016 of $0.165 per common unit, or approximately $43.9 million.  The distribution will be paid on November 22, 2016 to unitholders of record, including the Company, at the close of business on November 4, 2016.

C.                        EQT 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 other third parties. EQM is consolidated in the Company’s consolidated financial statements. The Company records the noncontrolling interest of the EQM public limited partners (i.e., the EQM limited partner interests not owned by EQGP) in its financial statements.

On March 30, 2015, the Company assigned 100% of the membership interest in MVP Holdco, LLC (MVP Holdco), which at the time was its indirect wholly owned subsidiary, to EQM and received $54.2 million, which represented EQM's reimbursement to EQT of 100% of the capital contributions made by EQT to Mountain Valley Pipeline, LLC (MVP Joint Venture) as of March 30, 2015. As of September 30, 2016, MVP Holdco owned a 45.5% interest (MVP Interest) in the MVP Joint Venture. The MVP Joint Venture plans to construct the Mountain Valley Pipeline (MVP), an estimated 300-mile natural gas interstate pipeline spanning from northern West Virginia to southern Virginia. The MVP Joint Venture has secured a total of  2.0 Bcf per day of 20-year firm capacity commitments, including a 1.29 Bcf per day firm capacity commitment by the Company. The MVP project is subject to Federal Energy Regulatory Commission (FERC) approval. The MVP Joint Venture submitted the MVP certificate application to the FERC in October 2015, and the FERC issued the Notice of Schedule for Environmental Review (NOS) and the Draft Environmental Impact Statement on June 28, 2016 and September 16, 2016, respectively.  Based on the schedule provided in the NOS, the MVP Joint Venture anticipates receiving the certificate in mid-year 2017. The pipeline is targeted to be in-service during the fourth quarter of 2018.

During 2015, EQM entered into an equity distribution agreement that established an “At the Market” (ATM) common unit offering program, pursuant to which a group of managers, acting as EQM’s sales agents, may sell EQM common units having an aggregate offering price of up to $750 million (the $750 million ATM Program). During the second quarter of 2016, EQM issued 2,949,309 common units at an average price per unit of $74.42 under this program and received net proceeds of $217.1 million after deducting commissions of $2.2 million and other offering expenses of $0.2 million. EQM used the net proceeds for general partnership purposes. In connection with the sales during the second quarter of 2016, the Company recorded a $24.9 million gain to additional paid-in-capital, a decrease in noncontrolling interest in consolidated subsidiary of $39.9 million and an increase to deferred tax liability of $15.0 million. No ATM sales occurred during the three months ended September 30, 2016.

On October 25, 2016, the Board of Directors of EQM’s general partner declared a cash distribution to EQM’s unitholders for the third quarter of 2016 of $0.815 per common unit. The cash distribution will be paid on November 14, 2016 to unitholders of record, including EQGP, at the close of business on November 4, 2016. Based on the 80,581,758 EQM common units outstanding on October 27, 2016, the aggregate cash distributions by EQM to EQGP will be approximately $44.3 million consisting of: $17.8 million in respect of its limited partner interest, $1.6 million in respect of its general partner interest and $24.9 million in respect of its IDRs. However, the distributions to EQGP in respect of 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 2016 distribution.


10

EQT Corporation and Subsidiaries
Notes to Condensed Consolidated Financial Statements (Unaudited)




D.        Equity in Nonconsolidated Investments

The Company, through its ownership interest in EQM, has a noncontrolling ownership interest in the MVP Joint Venture, a nonconsolidated investment that is accounted for under the equity method of accounting. The following table summarizes the Company's equity in the nonconsolidated investment:
 
 
 
 
Interest
 
Ownership % as of
 
Equity as of
 
Equity as of
Investee
 
Location
 
Type
 
September 30, 2016
 
September 30, 2016
 
December 31, 2015
 
 
 
 
 
 
 
 
(Thousands)
MVP Joint Venture
 
USA
 
Joint
 
45.5%
 
$
160,326

 
$
77,025


The Company’s ownership share of the earnings for the three months ended September 30, 2016 and 2015 related to the total investments accounted for under the equity method was $2.7 million and $0.7 million, respectively. The Company’s ownership share of the earnings for the nine months ended September 30, 2016 and 2015 related to the total investments accounted for under the equity method was $6.1 million and $1.3 million, respectively. These earnings are reported in other income on the Statements of Consolidated Operations for the periods presented.

The MVP Joint Venture has been determined to be a variable interest entity because the MVP Joint Venture has insufficient equity to finance 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, including, but not limited to: decisions with respect to operating and construction budgets, project construction schedule, material contracts or precedent agreements, indebtedness, significant acquisitions or dispositions, material regulatory filings and strategic 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.

On January 21, 2016, affiliates of Consolidated Edison, Inc. (ConEd) acquired a 12.5% interest in the MVP Joint Venture and entered into 20-year firm capacity commitments for approximately 0.25 Bcf per day on both the MVP and EQM’s transmission system (ConEd Transaction). As a result of the ConEd Transaction, EQM’s interest in the MVP Joint Venture decreased by 8.5% to 45.5%, and during the first quarter of 2016 ConEd reimbursed EQM $12.5 million, which represented EQM's proportional capital contributions to the MVP Joint Venture through the date of the transaction. ConEd has the right to terminate its purchase of the interest in the MVP Joint Venture and be reimbursed for the purchase price and all capital contributions made to the MVP Joint Venture for a period ending no later than December 31, 2016.

As of September 30, 2016, EQM had issued a $91 million performance guarantee in favor of the MVP Joint Venture to provide performance assurances for MVP Holdco's obligations to fund its proportionate share of the construction budget for the MVP. Upon the FERC’s initial release to begin construction of the MVP, EQM's guarantee will terminate; EQM will then be obligated to issue a new guarantee in an amount equal to 33% of MVP Holdco’s remaining obligations to make capital contributions to the MVP Joint Venture in connection with the then remaining construction budget, less, subject to certain limits, any credit assurances issued by any affiliate of EQM under such affiliate's precedent agreement with the MVP Joint Venture.

As of September 30, 2016, EQM's maximum financial statement exposure related to the MVP Joint Venture was approximately $251 million, which included the investment balance of $160 million on the Condensed Consolidated Balance Sheet as of September 30, 2016 and amounts which could have become due under the performance guarantee as of that date.

E.     Consolidated Variable Interest Entities

The Company adopted Accounting Standard Update (ASU) No. 2015-02, Consolidation in the first quarter of 2016 and, as a result, EQT determined EQGP and EQM to be variable interest entities. Through EQT's ownership and control of EQGP's general partner and control of EQM's general partner, EQT has the power to direct the activities that most significantly impact their economic performance. In addition, through EQT's general partner interest and 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. Therefore, EQT has a controlling financial interest in EQGP and EQM, is the primary beneficiary of EQGP and EQM and consolidates EQGP and EQM.


11

EQT Corporation and Subsidiaries
Notes to Condensed Consolidated Financial Statements (Unaudited)




The risks associated with the operations of EQGP and EQM are discussed in their respective Annual Reports on Form 10-K for the year ended December 31, 2015 and Quarterly Reports on Form 10-Q for the quarter ended September 30, 2016. See further discussion of the impact that EQT's involvement in EQGP and EQM have on EQT's financial position, results of operations and cash flows included in EQT's Annual Report on Form 10-K for the year ended December 31, 2015, including in the section captioned "Management's Discussion and Analysis of Financial Condition and Results of Operations" contained therein. See Notes B and C for further discussion of EQGP and EQM, 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, 2016 and December 31, 2015.

Classification
 
September 30, 2016
 
December 31, 2015
 
 
(Thousands)
Assets:
 
 

 
 

Cash and cash equivalents
 
$
263

 
$
350,815

Accounts receivable
 
14,752

 
17,131

Prepaid expenses and other
 
2,880

 
2,111

Property, plant and equipment, net
 
2,429,448

 
1,969,993

Other assets
 
180,447

 
91,975

Liabilities:
 
 
 
 
Accounts payable
 
$
71,600

 
$
35,909

Credit facility borrowings
 
91,000

 
299,000

Other current liabilities
 
23,641

 
15,722

Long-term debt
 
493,978

 
493,401

Other liabilities and credits
 
8,910

 
7,834


The following table summarizes EQGP's Statements of Consolidated Operations and Cash Flows for the three and nine months ended September 30, 2016 and 2015, inclusive of affiliate amounts.

 
Three Months Ended September 30,
 
Nine Months Ended September 30,
 
2016
 
2015
 
2016
 
2015
 
(Thousands)
Operating revenues
$
170,836

 
$
148,789

 
$
523,441

 
$
448,213

Operating expenses
(50,061
)
 
(46,212
)
 
(147,916
)
 
(132,526
)
Other income (expenses)
5,219

 
(8,797
)
 
2,568

 
(55,387
)
Net income
$
125,994

 
$
93,780

 
$
378,093

 
$
260,300

 
 
 
 
 
 
 
 
Net cash provided by operating activities
$
100,951

 
$
79,719

 
$
368,377

 
$
318,821

Net cash used in investing activities
$
(190,172
)
 
(125,829
)
 
$
(494,130
)
 
(891,712
)
Net cash provided by (used in) financing activities
$
5,128

 
$
46,342

 
$
(224,799
)
 
$
402,842


F.                        Financial Information by Business Segment
 
Operating segments are revenue-producing components of the enterprise for which separate financial information is produced internally and which are subject to evaluation by the Company’s chief operating decision maker in deciding how to allocate resources.
 
The Company reports its operations in two segments, which reflect its lines of business.  The EQT Production segment includes the Company’s exploration for, development and production of and sales of, natural gas and natural gas liquids (NGLs) in the Appalachian and Permian Basins.  The EQT Midstream segment’s operations include the natural gas gathering, transmission and storage activities of the Company, including ownership and operation of EQGP and EQM. EQT Midstream also provides marketing services for the benefit of EQT Production.


12

EQT Corporation and Subsidiaries
Notes to the Condensed Consolidated Financial Statements (Unaudited) 

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 an allocation of the headquarters’ annual operating budget.  Differences between budget and actual headquarters’ expenses are not allocated to the operating segments.
 
Substantially all of the Company’s operating revenues, income from operations and assets are generated or located in the United States.
Three Months Ended September 30, 2016
EQT
Production
 
EQT Midstream
 
Intersegment Eliminations
 
EQT Corporation
Revenues:
 
 
 
 
 
 
 
Sales of natural gas, oil and NGLs
$
403,939

 
$

 
$

 
$
403,939

Pipeline and marketing services
5,251

 
214,335

 
(160,155
)
 
59,431

Gain on derivatives not designated as hedges
93,356

 

 

 
93,356

Total operating revenues
$
502,546

 
$
214,335

 
$
(160,155
)
 
$
556,726


Three Months Ended September 30, 2015
EQT
Production (a)
 
EQT Midstream
 
Intersegment Eliminations (a)
 
EQT Corporation
Revenues:
 
 
 
 
 
 
 
Sales of natural gas, oil and NGLs
$
365,940

 
$

 
$

 
$
365,940

Pipeline and marketing services
4,886

 
197,774

 
(145,885
)
 
56,775

Gain on derivatives not designated as hedges
160,458

 
805

 

 
161,263

Total operating revenues
$
531,284

 
$
198,579

 
$
(145,885
)
 
$
583,978


Nine Months Ended September 30, 2016
EQT Production
 
EQT Midstream
 
Intersegment Eliminations
 
EQT Corporation
Revenues:
 
 
 
 
 
 
 
Sales of natural gas, oil and NGLs
$
1,072,898

 
$

 
$

 
$
1,072,898

Pipeline and marketing services
11,960

 
653,362

 
(476,552
)
 
188,770

Loss on derivatives not designated as hedges
(32,342
)
 

 

 
(32,342
)
Total operating revenues
$
1,052,516

 
$
653,362

 
$
(476,552
)
 
$
1,229,326


Nine Months Ended September 30, 2015
EQT
Production (a)
 
EQT Midstream
 
Intersegment Eliminations (a)
 
EQT Corporation
Revenues:
 
 
 
 
 
 
 
Sales of natural gas, oil and NGLs
$
1,326,104

 
$

 
$

 
$
1,326,104

Pipeline and marketing services
27,845

 
600,002

 
(424,683
)
 
203,164

Gain (loss) on derivatives not designated as hedges
209,881

 
(767
)
 

 
209,114

Total operating revenues
$
1,563,830

 
$
599,235

 
$
(424,683
)
 
$
1,738,382


(a)
For the three and nine months ended September 30, 2016,  EQT Production presented affiliated gathering and transmission costs as operating expenses for consistency with the presentation of third-party costs.  Historically, these affiliated costs have been presented as revenue deductions.  Certain previously reported amounts have been reclassified to conform with current year presentation.


13

EQT Corporation and Subsidiaries
Notes to the Condensed Consolidated Financial Statements (Unaudited) 

 
Three Months Ended September 30,
 
Nine Months Ended September 30,
 
2016
 
2015
 
2016
 
2015
 
(Thousands)
Operating income (loss):
 

 
 

 
 

 
 

EQT Production
$
(22,010
)
 
$
56,360

 
$
(477,264
)
 
$
175,317

EQT Midstream
132,727

 
113,010

 
399,114

 
350,942

Unallocated expenses (b)
(2,260
)
 
685

 
(10,684
)
 
(8,411
)
Total operating income (loss)
$
108,457

 
$
170,055

 
$
(88,834
)
 
$
517,848


(b)
Unallocated expenses consist primarily of incentive compensation expense and administrative costs.

Reconciliation of operating income (loss) to net income (loss):
Total operating income (loss)
$
108,457

 
$
170,055

 
$
(88,834
)
 
$
517,848

Other income
10,715

 
2,661

 
23,199

 
6,289

Interest expense
35,984

 
36,547

 
108,469

 
110,596

Income tax expense (benefit)
13,084

 
35,936

 
(151,826
)
 
28,393

Net income (loss)
$
70,104

 
$
100,233

 
$
(22,278
)
 
$
385,148

 
As of September 30, 2016
 
As of December 31, 2015
 
(Thousands)
Segment assets:
 

 
 

EQT Production
$
9,222,067

 
$
8,995,853

EQT Midstream
3,753,924

 
3,226,138

Total operating segments
12,975,991

 
12,221,991

Headquarters assets, including cash and short-term investments
1,913,993

 
1,754,181

Total assets
$
14,889,984

 
$
13,976,172

 
Three Months Ended September 30,
 
Nine Months Ended September 30,
 
2016
 
2015
 
2016
 
2015
 
(Thousands)
Depreciation, depletion and amortization:
 

 
 

 
 

 
 

EQT Production
$
210,066

 
$
184,277

 
$
602,766

 
$
529,071

EQT Midstream
26,937

 
23,830

 
79,948

 
70,417

Other
85

 
120

 
234

 
303

Total
$
237,088

 
$
208,227

 
$
682,948

 
$
599,791

 
 
 
 
 
 
 
 
Expenditures for segment assets (c):
 

 
 

 
 

 
 

EQT Production (d)
$
621,377

 
$
451,358

 
$
1,090,033

 
$
1,453,647

EQT Midstream
171,645

 
130,902

 
513,776

 
368,019

Other
857

 
437

 
3,045

 
2,046

Total
$
793,879

 
$
582,697

 
$
1,606,854

 
$
1,823,712

 
(c)
Includes the capitalized portion of non-cash stock-based compensation expense and the impact of capital accruals.
(d)
Expenditures for segment assets in the EQT Production segment include $448.7 million and $41.8 million for property acquisitions during the three months ended September 30, 2016 and 2015, respectively, and $516.8 million and $180.9 million for property acquisitions during the nine months ended September 30, 2016 and 2015, respectively.


14

EQT Corporation and Subsidiaries
Notes to the Condensed Consolidated Financial Statements (Unaudited) 

G.                        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 uses over the counter (OTC) derivative commodity instruments, primarily swap and collar agreements, that are primarily 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 also sells call options that require the Company to pay the counterparty 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 interest rate fluctuations on potential debt issuances.

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 accounting for the changes in fair value of the Company’s derivative instruments depends on the use of the derivative instruments.  To the extent that a derivative instrument had been designated and qualified as a cash flow hedge, the effective portion of the change in fair value of the derivative instrument is reported as a component of accumulated other comprehensive income (OCI), net of tax, and is subsequently reclassified into the Statements of Consolidated Operations in the same period or periods during which the forecasted transaction affects earnings. As a result of the discontinuance of cash flow hedge accounting, beginning in 2015, all changes in fair value of the Company’s derivative instruments are recognized within operating revenues in the Statements of Consolidated Operations.

In prior periods, derivative commodity instruments used by the Company to hedge its exposure to variability in expected future cash flows associated with the fluctuations in the price of natural gas related to the Company’s forecasted sale of EQT Production's produced volumes and forecasted natural gas purchases and sales were designated and qualified as cash flow hedges. As of September 30, 2016 and December 31, 2015, the Company deferred net gains of $21.7 million and $64.8 million, respectively, in accumulated OCI, net of tax, related to the effective portion of the change in fair value of its derivative commodity instruments designated as cash flow hedges. Effective December 31, 2014, the Company elected to de-designate all cash flow hedges and discontinue the use of cash flow hedge accounting. As of September 30, 2016 and December 31, 2015, the forecasted transactions that were hedged as of December 31, 2014 remained probable of occurring and as such, the amounts in accumulated OCI will continue to be reported in accumulated OCI and will be reclassified into earnings in future periods when the underlying hedged transactions occur. The forecasted transactions extend through December 2018. The Company estimates that approximately $15.6 million of net gains on its derivative commodity instruments reflected in accumulated OCI, net of tax, as of September 30, 2016 will be recognized in earnings during the next twelve months due to the settlement of hedged transactions.

The Company also enters into fixed price natural gas sales agreements that are satisfied by physical delivery.  These physical commodity contracts qualify for the normal purchases and sales exception and are not subject to derivative instrument accounting.
 
OTC arrangements require settlement in cash. Settlements of derivative commodity instruments are reported as a component of cash flows from operations in the accompanying Statements of Condensed Consolidated Cash Flows. 

15

EQT Corporation and Subsidiaries
Notes to the Condensed Consolidated Financial Statements (Unaudited) 

 
Three Months Ended September 30,
 
Nine Months Ended September 30,
 
2016
 
2015
 
2016
 
2015
 
(Thousands)
Commodity derivatives designated as cash flow hedges
 
Amount of gain reclassified from accumulated OCI, net of tax, into sales of natural gas, oil and NGLs (effective portion)
$
14,740

 
$
39,346

 
$
43,104

 
$
122,678

 
 
 
 
 
 
 
 
Interest rate derivatives designated as cash flow hedges
 

 
 

 
 

 
 

Amount of loss reclassified from accumulated OCI, net of tax, into interest expense (effective portion)
$
(36
)
 
$
(36
)
 
$
(108
)
 
$
(108
)
 
 
 
 
 
 
 
 
Derivatives not designated as hedging instruments
 

 
 

 
 

 
 

Amount recognized in gain (loss) on derivatives not designated as hedges
$
93,356

 
$
161,263

 
$
(32,342
)
 
$
209,114


The absolute quantities of the Company’s derivative commodity instruments totaled 677 Bcf and 676 Bcf as of September 30, 2016 and December 31, 2015, respectively, and were primarily related to natural gas swaps, basis swaps and collars. The open natural gas positions at September 30, 2016 and December 31, 2015 had maturities extending through December 2020 and December 2019, respectively. The Company also had 913 Mbbls of propane swaps as of September 30, 2016, which had maturities extending through December 2018.

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, 2016 and December 31, 2015
As of September 30, 2016
 
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
 
$
134,698

 
$
(63,823
)
 
$

 
$
70,875

 
 
 
 
 
 
 
 
 
Liability derivatives:
 
 
 
 

 
 

 
 

Derivative instruments, at fair value
 
$
67,871

 
$
(63,823
)
 
$

 
$
4,048

As of December 31, 2015
 
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
 
$
417,397

 
$
(19,909
)
 
$

 
$
397,488

 
 
 
 
 
 
 
 
 
Liability derivatives:
 
 

 
 

 
 

 
 

Derivative instruments, at fair value
 
$
23,434

 
$
(19,909
)
 
$

 
$
3,525

 

16

EQT Corporation and Subsidiaries
Notes to the Condensed Consolidated Financial Statements (Unaudited) 

Certain of the Company’s derivative instrument contracts provide that if the Company’s credit ratings by Standard & Poor’s Ratings Services (S&P) or Moody’s Investors Services (Moody’s) are lowered below investment grade, additional collateral may be required to be deposited with the counterparty.  The additional collateral can be up to 100% of the derivative liability.  As of September 30, 2016, the aggregate fair value of all derivative instruments with credit risk-related contingent features that were in a net liability position was $8.0 million, for which the Company had no collateral posted on September 30, 2016.  If the Company’s credit rating by S&P or Moody’s had been downgraded below investment grade on September 30, 2016, the Company would not have been required to post any additional collateral under the agreements with the respective counterparties.  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, 2016.  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. Having a non-investment grade rating would result in greater borrowing costs and collateral requirements than would be available if all credit ratings were 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."

H.            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 and collar agreements. There were no transfers between Levels 1, 2 and 3 during the periods presented. The Company recognizes transfers between Levels as of the actual date of the event or change in circumstances that caused the transfer.

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 New York Mercantile Exchange (NYMEX) forward curves, LIBOR-based discount rates, basis forward curves and propane forward curves.  The Company’s collars and options 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 forward curves, LIBOR-based discount rates, natural gas volatilities, basis forward curves and propane 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, 2016
 
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
 
$
134,698

 
$

 
$
134,698

 
$

 
 
 
 
 
 
 
 
 
Liabilities
 
 

 
 

 
 
 
 

Derivative instruments, at fair value
 
$
67,871

 
$

 
$
67,871

 
$



17

EQT Corporation and Subsidiaries
Notes to the Condensed Consolidated Financial Statements (Unaudited) 

 
 
 
 
Fair value measurements at reporting date using
Description
 
As of December 31, 2015
 
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
 
$
417,397

 
$

 
$
417,397

 
$

 
 
 
 
 
 
 
 
 
Liabilities
 
 

 
 

 
 

 
 

Derivative instruments, at fair value
 
$
23,434

 
$

 
$
23,434

 
$

 
The carrying value of cash equivalents, accounts receivable, amounts due to/from related parties and accounts payable approximate fair value due to the short-term maturity of the instruments. The carrying value of borrowings under EQM’s credit facility approximates fair value as the interest rates are based on prevailing market rates.
 
The Company estimates the fair value of its debt using its established fair value methodology.  Because not all of the Company’s debt is actively traded, the fair value of the debt is a Level 2 fair value measurement.  Fair value for non-traded debt obligations is estimated using a standard industry income approach model which utilizes a discount rate based on market rates for debt with similar remaining time to maturity and credit risk.  The estimated fair value of total debt (including EQM’s long-term debt) on the Condensed Consolidated Balance Sheets was approximately $3.1 billion at September 30, 2016 and $2.8 billion at December 31, 2015. The carrying value of total debt (including EQM’s long-term debt) on the Condensed Consolidated Balance Sheets was approximately $2.8 billion at September 30, 2016 and December 31, 2015.

I.                       Income Taxes
 
Prior to 2016, the Company had historically calculated the provision for income taxes during interim reporting periods by applying an estimate of the annual effective tax rate for the full fiscal year to “ordinary” income or loss (pretax income or loss excluding unusual or infrequently occurring items) for the reporting period. The Company determined that the historical method would not provide a reliable estimate for the nine month period ended September 30, 2016, as small fluctuations in estimated “ordinary” income would result in significant changes in the estimated annual effective tax rate. As a consequence, the Company used a discrete effective tax rate method to calculate taxes for the nine month period ended September 30, 2016.

All of EQGP’s income is included in the Company’s net income. However, the Company is not required to record income tax expense with respect to the portion of EQGP’s income allocated to the noncontrolling public limited partners of EQGP and EQM, which reduces the Company’s effective tax rate in periods when the Company has consolidated pretax income and increases the Company's effective tax rate in periods when the Company has consolidated pretax loss.
 
The Company’s effective income tax rate for the nine months ended September 30, 2016 was 87.2%, compared to 6.9% for the nine months ended September 30, 2015. The effective income tax rate for the nine months ended September 30, 2016 was higher than the U.S. federal statutory rate of 35% primarily driven by the effect of income allocated to the noncontrolling limited partners of EQGP and EQM. Due to the Company's consolidated pretax loss for the nine months ended September 30, 2016, primarily caused by lower realized commodity prices and losses on derivatives not designated as hedges at the EQT Production segment, EQGP's income allocated to the noncontrolling limited partners increased the effective income tax rate for the period. The increase in the effective income tax rate was also partly attributable to the tax benefit generated from a pre-tax loss on state income tax paying entities.

Excluding the impact of the Internal Revenue Service (IRS) guidance received by the Company (discussed below), the effective income tax rate for the nine months ended September 30, 2015 was 15.5%. The effective income tax rate differed from the U.S. federal statutory rate of 35% primarily as a result of income allocated to the noncontrolling limited partners of EQGP and EQM, a state income tax benefit as a result of lower pre-tax income on state tax paying entities and increased tax credits recorded in 2015. Noncontrolling limited partners income increased in 2015 primarily as a result of higher net income at EQM and increased noncontrolling interests as a result of sales of EQGP and EQM limited partner interests to the public.


18

EQT Corporation and Subsidiaries
Notes to the Condensed Consolidated Financial Statements (Unaudited) 

The Company’s income tax expense was lower for the three and nine months ended September 30, 2015 due to a $35.5 million tax benefit recorded in connection with IRS guidance received by the Company in 2015 regarding the Company’s sale of Equitable Gas Company, LLC, a regulated entity, in 2013. The transaction included a partial like-kind exchange of assets that resulted in tax deferral for the Company. However, in order to be in compliance with the normalization rules of the Internal Revenue Code, the IRS guidance held that the deferred tax liability associated with the exchanged regulatory assets should not be considered for ratemaking purposes. As a result, during the second quarter of 2015, the Company recorded a regulatory asset equal to the taxes deferred from the exchange and an associated income tax benefit. The regulatory asset and deferred tax benefit will reverse during the fourth quarter of 2016 as a result of the disposal of certain regulated assets as part of the October 2016 Sale discussed in Note O.

There were no material changes to the Company’s methodology for determining unrecognized tax benefits during the three months ended September 30, 2016.  The Company believes that it is appropriately reserved for uncertain tax positions. 

J.                       Revolving Credit Facilities

The Company has a $1.5 billion unsecured revolving credit facility that expires in February 2019. The Company had no borrowings or letters of credit outstanding under its revolving credit facility as of September 30, 2016 or December 31, 2015 or at any time during the three and nine months ended September 30, 2016 and 2015.
 
EQM has a $750 million credit facility that expires in February 2019, and EQM had $91 million of borrowings and no letters of credit outstanding under its revolving credit facility as of September 30, 2016. As of December 31, 2015, EQM had $299 million of borrowings and no letters of credit outstanding under its revolving credit facility. The maximum amount of outstanding borrowings under EQM’s revolving credit facility at any time during the three and nine months ended September 30, 2016 was $91 million and $299 million, respectively. The maximum amount of outstanding borrowings under EQM’s revolving credit facility at any time during the three and nine months ended September 30, 2015 was $404 million for both periods. The average daily balance of loans outstanding under EQM’s credit facility was approximately $34 million and $67 million at a weighted average annual interest rate of 2.0% and 1.9% for the three and nine months ended September 30, 2016, respectively. The average daily balance of loans outstanding under EQM’s credit facility was approximately $357 million and $241 million during the three and nine months ended September 30, 2015, respectively, at a weighted average annual interest rate of 1.7% for both periods.
 
The Company incurred commitment fees averaging approximately 6 basis points for each of the three months ended September 30, 2016 and 2015, and 17 basis points for each of the nine months ended September 30, 2016 and 2015, to maintain credit availability under its revolving credit facility. EQM incurred commitment fees averaging approximately 6 basis points for each of the three months ended September 30, 2016 and 2015, and 17 basis points for each of the nine months ended September 30, 2016 and 2015, to maintain credit availability under its revolving credit facility.

K.                            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, options and restricted stock totaling 1,712,527 and 1,812,142 shares were excluded from the calculation of diluted earnings per share for the three and nine months ended September 30, 2016, respectively. Potentially dilutive securities, consisting of options and restricted stock, which were included in the calculation of diluted earnings per share totaled 302,550 and 462,317 for the three and nine months ended September 30, 2015, respectively. Options to purchase common stock which were excluded from potentially dilutive securities because they were anti-dilutive totaled 291,700 and 133,500 for the three and nine months ended September 30, 2015, 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.


19

EQT Corporation and Subsidiaries
Notes to the Condensed Consolidated Financial Statements (Unaudited) 

L.         Changes in Accumulated Other Comprehensive Income by Component
 
The following tables explain the changes in accumulated OCI by component during the applicable period:
 
Three Months Ended September 30, 2016
 
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 June 30, 2016
$
36,398

 
$
(771
)
 
$
(7,706
)
 
$
27,921

(Gains) losses reclassified from accumulated OCI, net of tax
(14,740
)
(a)
36

(a)
82

(b)
(14,622
)
Accumulated OCI (loss), net of tax, as of
September 30, 2016
$
21,658

 
$
(735
)
 
$
(7,624
)
 
$
13,299

 
Three Months Ended September 30, 2015
 
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 June 30, 2015
$
133,789

 
$
(915
)
 
$
(16,236
)
 
$
116,638

(Gains) losses reclassified from accumulated OCI, net of tax
(39,346
)
(a)
36

(a)
202

(b)
(39,108
)
Accumulated OCI (loss), net of tax, as of
September 30, 2015
$
94,443

 
$
(879
)
 
$
(16,034
)
 
$
77,530

 
Nine Months Ended September 30, 2016
 
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
December 31, 2015
$
64,762

 
$
(843
)
 
$
(17,541
)
 
$
46,378

(Gains) losses reclassified from accumulated OCI, net of tax
(43,104
)
(a)
108

(a)
9,917

(b)
(33,079
)
Accumulated OCI (loss), net of tax, as of
September 30, 2016
$
21,658

 
$
(735
)
 
$
(7,624
)
 
$
13,299

 
Nine Months Ended September 30, 2015
 
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
December 31, 2014
$
217,121

 
$
(987
)
 
$
(16,640
)
 
$
199,494

(Gains) losses reclassified from accumulated OCI, net of tax
(122,678
)
(a)
108

(a)
606

(b)
(121,964
)
Accumulated OCI (loss), net of tax, as of
September 30, 2015
$
94,443

 
$
(879
)
 
$
(16,034
)
 
$
77,530

(a)   See Note G for additional information.
(b)   This accumulated OCI reclassification is attributable to the net actuarial loss and net prior service cost related to the Company’s defined benefit pension plans and other post-retirement benefit plans.  See Note 14 to the Consolidated Financial Statements in the Company’s Annual Report on Form 10-K for the year ended December 31, 2015 and Note M for additional information.

20

EQT Corporation and Subsidiaries
Notes to Condensed Consolidated Financial Statements (Unaudited)




M.         Pension Termination

The Company terminated the EQT Corporation Retirement Plan for Employees (Retirement Plan) effective December 31, 2014. On March 2, 2016, the IRS issued a favorable determination letter for the termination of the Retirement Plan. On June 28, 2016, the Company purchased annuities from, and transferred the Retirement Plan assets and liabilities to, American General Life Insurance Company (AGL). As a result, during the second quarter of 2016, the Company reclassified actuarial loss remaining in accumulated other comprehensive loss of approximately $9.4 million to earnings and approximately $5.1 million to a regulatory asset that will be amortized for rate recovery purposes over a period of 16 years. In connection with the purchase of annuities, the Company made a cash payment of approximately $5.4 million to fully fund the Retirement Plan upon liquidation during the second quarter of 2016.

N.         Statoil Acquisition

On July 8, 2016, the Company acquired approximately 62,500 net acres from Statoil USA Onshore Properties, Inc. (Statoil) which included current natural gas production of approximately 50 MMcfe per day (the Statoil Acquisition). The net acres acquired are primarily located in Wetzel, Tyler and Harrison Counties of West Virginia. The purchase and sale agreement included an economic adjustment to put the parties in the same economic position as if the closing date for the acquisition had occurred on December 1, 2015, and the Company paid $412.3 million in the third quarter of 2016, inclusive of an estimate for this adjustment.

The purchase and sale agreement also included provisions for potential title defects which result in a decrease to the aggregate purchase price at an agreed upon value per defected acre or allow Statoil to replace the defected acreage subject to acceptance by the Company. The Company is currently unable to determine the ultimate adjustments to the aggregate purchase price at September 30, 2016; however, the Company believes that such adjustments will not have a material effect on the Company's financial statements.

O.         Subsequent Events

October 2016 Sale

On October 13, 2016, EQT entered into a Purchase and Sale Agreement with EQM pursuant to which EQM acquired from EQT (i) 100% of the outstanding limited liability company interests of Allegheny Valley Connector, LLC and Rager Mountain Storage Company LLC and (ii) certain gathering assets located in southwestern Pennsylvania and West Virginia (collectively, the October 2016 Sale). The closing of the October 2016 Sale occurred on October 13, 2016 and was effective as of October 1, 2016. The aggregate consideration paid by EQM to EQT in connection with the October 2016 Sale was $275 million, which was funded with borrowings under EQM's $750 million revolving credit facility.

Trans Energy / Republic Energy Acquisitions

On October 24, 2016, the Company entered into a Purchase and Sale Agreement with Republic Energy Ventures, LLC and certain of its affiliates (collectively, the Republic Parties) pursuant to which the Company will acquire Marcellus acres from the Republic Parties for $319.8 million in cash, subject to purchase price adjustments and customary closing conditions (the Republic Transaction). 

Also on October 24, 2016, EQT and one of its wholly owned subsidiaries entered into an Agreement and Plan of Merger with Trans Energy, Inc. (the Merger Agreement). Under the terms of the Merger Agreement, the Company has agreed to commence a tender offer, through its wholly owned subsidiary, to acquire all of the outstanding shares of common stock of Trans Energy, Inc. (Trans Energy) for cash of $3.58 per share. The closing of the tender offer is subject to certain conditions, including the tender of a number of Trans Energy shares that, together with shares owned by the Company and its affiliates, represents at least a majority of the total number of Trans Energy outstanding shares. The closing is also subject to the consummation of the Republic Transaction and other customary conditions. The boards of directors of both the Company and Trans Energy have unanimously approved the terms of the Merger Agreement, and the board of directors of Trans Energy has resolved to recommend that Trans Energy’s stockholders accept the offer, once it is commenced. Following the completion of the tender offer, the Company will merge its wholly owned subsidiary into Trans Energy, and Trans Energy will survive as a wholly owned subsidiary of the Company (the Trans Energy Merger).


21

EQT Corporation and Subsidiaries
Notes to Condensed Consolidated Financial Statements (Unaudited)




The Republic Transaction and the Trans Energy Merger are expected to close during the fourth quarter of 2016. Through the Republic Transaction and the Trans Energy Merger, the Company will acquire approximately 42,600 net Marcellus acres and 42 Marcellus wells, 33 of which are currently producing, in Wetzel, Marshall and Marion Counties, West Virginia. The Company estimates that, as of October 25, 2016, production from the Marcellus wells was approximately 42 MMcfe per day.

Pennsylvania Acquisition

On October 25, 2016, the Company entered into a Purchase and Sale Agreement with a third party pursuant to which the Company will acquire approximately 17,000 net Marcellus acres located in Washington, Westmoreland and Greene Counties, Pennsylvania, and two related Marcellus producing wells, for $170 million in cash, subject to purchase price adjustments (the Pennsylvania Acquisition). The closing of the Pennsylvania Acquisition, which is subject to customary closing conditions, is also expected to occur during the fourth quarter 2016.

The Company will finance the Republic Transaction, the Trans Energy Merger and the Pennsylvania acquisition with cash on hand.

P.        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. ASU No. 2014-09 will supersede most of the existing revenue recognition requirements in United States GAAP when it becomes effective and is required to be adopted using one of two retrospective application methods. In August 2015, the FASB issued ASU No. 2015-14, Revenue from Contracts with Customers - Deferral of the Effective Date, which approved a one year deferral of ASU No. 2014-09 to annual reporting periods beginning after December 15, 2017, including interim periods within that reporting period. In March 2016, the FASB issued ASU No. 2016-08, Revenue from Contracts with Customers - Principal versus Agent Considerations (Reporting Revenue Gross versus Net), which improves the understandability of the implementation guidance on principal versus agent considerations. In March 2016, the FASB issued ASU No. 2016-10, Revenue from Contracts with Customers - Identifying Performance Obligations and Licensing, which clarifies guidance related to identifying performance obligations and licensing implementation guidance. Early application of these ASUs is permitted for annual reporting periods beginning after December 15, 2016, including interim reporting periods within that reporting period. The Company expects to adopt using the modified retrospective method of adoption on January 1, 2018 and is currently evaluating the impact this standard will have on its financial statements and related disclosures.

In January 2016, the FASB issued ASU No. 2016-01, Financial Instruments-Overall: Recognition and Measurement of Financial Assets and Financial Liabilities. The changes promulgated by this standard primarily affect the accounting for equity investments, financial liabilities under the fair value option and the presentation and disclosure requirements for financial instruments. The ASU will be effective for annual reporting periods beginning after December 15, 2017, including interim reporting periods within that reporting period, with early adoption of certain provisions permitted. The Company does not anticipate this standard will have a material impact on its financial statements and related disclosures.
 
In February 2016, the FASB issued ASU No. 2016-02, Leases. The ASU requires, among other things, that lessees recognize the following for all leases (with the exception of short-term leases) at the commencement date: (1) a lease liability, which is a lessee’s obligation to make lease payments arising from a lease, measured on a discounted basis; and (2) a right-of-use asset, which is an asset that represents the lessee’s right to use, or control the use of, a specified asset for the lease term. Lessees and lessors must apply a modified retrospective transition approach for leases existing at, or entered into after, the beginning of the earliest comparative period presented in the financial statements. 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. While the Company is currently evaluating the provisions of this ASU to determine the impact this standard will have on its financial statements and related disclosures, the primary effect of adopting the new standard will be to record assets and obligations for contracts currently recognized as operating leases.


22

EQT Corporation and Subsidiaries
Notes to Condensed Consolidated Financial Statements (Unaudited)




In March 2016, the FASB issued ASU No. 2016-09, Compensation-Stock Compensation: Improvements to Employee Share-Based Payment Accounting. This ASU is part of the initiative to reduce complexity in accounting standards. The areas for simplification in this ASU involve several aspects of the accounting for employee share-based payment transactions, including the income tax consequences, classification of awards as either equity or liabilities and classification on the statement of cash flows. The ASU will be effective for annual reporting periods beginning after December 15, 2016, including interim periods within that reporting period, with early adoption permitted. The Company does not anticipate this standard will have a material impact on its financial statements and related disclosures.

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, instead, 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 Company is currently evaluating the impact this standard will have on its financial statements and related disclosures.

In August 2016, the FASB issued ASU No. 2016-15, Statement of Cash Flows (Topic 230): Classification of Certain Cash Receipts and Cash Payments. This ASU addresses the presentation and classification of eight specific cash flow issues. The amendments in the ASU will be effective for public business entities for annual reporting periods beginning after December 15, 2017, including interim periods within that reporting period, with early adoption permitted. The Company does not anticipate this standard will have a material impact on its financial statements and related disclosures.
 

23

EQT Corporation and Subsidiaries
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
 
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 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 and other reserves; drilling plans and programs (including the number, type, feet of pay 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 and transmission volumes; infrastructure programs (including the timing, cost and capacity of the transmission and gathering expansion projects); the timing, cost, capacity and expected interconnects with facilities and pipelines of the Mountain Valley Pipeline (MVP) project; the ultimate terms, partners and structure of Mountain Valley Pipeline, LLC (the MVP Joint Venture); technology (including drilling techniques); monetization transactions, including midstream asset sales (dropdowns) to EQT Midstream Partners, LP (EQM) and other asset sales, joint ventures or other transactions involving the Company’s assets; acquisition transactions; natural gas prices and changes in basis; potential future impairments of the Company's assets; reserves; projected capital expenditures; the expected use of proceeds from equity offerings; the amount and timing of any repurchases under the Company’s share repurchase authorization; liquidity and financing requirements, including funding sources and availability; hedging strategy; the effects of government regulation and litigation; 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, 2015.
 
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 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. 

24

EQT Corporation and Subsidiaries
Management’s Discussion and Analysis of Financial Condition and Results of Operations

CORPORATE OVERVIEW
 
Three Months Ended September 30, 2016 vs. Three Months Ended September 30, 2015
 
Net loss attributable to EQT Corporation for the three months ended September 30, 2016 was $8.0 million, a loss of $0.05 per diluted share, compared with net income attributable to EQT Corporation of $40.8 million, $0.27 per diluted share, for the three months ended September 30, 2015. The $48.8 million decrease between periods was primarily attributable to a 14% decrease in the average realized price for production sales volumes, decreased gains on derivatives not designated as hedges, higher operating expenses and higher net income attributable to noncontrolling interests, partially offset by increased production sales volumes, lower income tax expense and increased gathering and transmission revenues.

The average realized price to EQT Corporation for production sales volumes was $2.20 per Mcfe for the three months ended September 30, 2016 compared to $2.55 per Mcfe for the three months ended September 30, 2015. The decrease in the average realized price was driven by lower cash settled derivatives net of an increase in average New York Mercantile Exchange (NYMEX) natural gas prices and a decrease in average differential to NYMEX partly offset by higher natural gas liquids (NGLs) prices.

The average NYMEX natural gas index price was $2.81 per MMBtu during the third quarter of 2016, 1% higher than the average index price of $2.77 per MMBtu during the third quarter of 2015. Cash settled derivatives decreased by $0.38 per Mcf as a result of lower average NYMEX hedge prices, and the average natural gas differential decreased $0.06 per Mcf between periods. The average NGL price was $17.13 per barrel for the three months ended September 30, 2016 compared to $11.12 per barrel for the three months ended September 30, 2015.

Gains on derivatives not designated as hedges were $93.4 million for the third quarter of 2016, a decrease of $67.9 million compared to the third quarter of 2015. The $93.4 million gain for 2016 primarily related to favorable changes in the fair market value of EQT Production's NYMEX and basis swaps due to a decrease in forward prices during the third quarter of 2016.

Net income attributable to noncontrolling interests of EQT GP Holdings, LP (EQGP) and EQM was $78.1 million for the three months ended September 30, 2016 compared to $59.4 million for the three months ended September 30, 2015. The $18.7 million increase was primarily the result of increased net income at EQM and increased noncontrolling interests as a result of EQM’s issuances of limited partner units to the public in 2015 and 2016.

Income tax expense was $13.1 million for the three months ended September 30, 2016, compared to income tax expense of $35.9 million for the three months ended September 30, 2015. The decrease in the income tax expense was primarily attributable to the reduction in EQT Production segment operating income resulting primarily from lower realized commodity prices, reduced gains on derivatives not designated as hedges and a pre-tax loss recorded on state income tax paying entities subject to higher state income tax rates. The Company’s effective income tax rate differed from the U.S. Federal statutory rate of 35% for both periods primarily because the Company consolidates 100% of the pre-tax income related to the noncontrolling public limited partners’ share of EQGP income, but is not required to record an income tax provision with respect to the portion of the income allocated to EQGP and EQM noncontrolling public limited partners.

Nine Months Ended September 30, 2016 vs. Nine Months Ended September 30, 2015
 
Net loss attributable to EQT Corporation for the nine months ended September 30, 2016 was $261.0 million, a loss of $1.58 per diluted share, compared with net income attributable to EQT Corporation for the nine months ended September 30, 2015 of $219.8 million, $1.44 per diluted share. The $480.8 million decrease between periods was primarily attributable to a 26% decrease in the average realized price for production sales volumes, losses on derivatives not designated as hedges in the current year compared to gains on derivatives not designated as hedges in the prior year, higher operating expenses and higher net income attributable to noncontrolling interests partially offset by increased production sales volumes, an income tax benefit in 2016 and higher gathering and transmission revenues.
 
The average realized price to EQT Corporation for production sales volumes was $2.31 per Mcfe for the nine months ended September 30, 2016 compared to $3.11 per Mcfe for the nine months ended September 30, 2015. The decrease in the average realized price was driven by lower NYMEX natural gas prices including the impact of cash settled derivatives, a lower average differential to NYMEX and lower NGL prices.


25

EQT Corporation and Subsidiaries
Management’s Discussion and Analysis of Financial Condition and Results of Operations

The average NYMEX natural gas index price was $2.29 per MMBtu during the nine months ended September 30, 2016, 18% lower than the average index price of $2.80 per MMBtu during the nine months ended September 30, 2015. In addition, the average natural gas differential decreased $0.09 per Mcf between periods. The average NGL price was $16.42 per barrel for the nine months ended September 30, 2016 compared to $18.11 per barrel for the nine months ended September 30, 2015.

Losses on derivatives not designated as hedges were $32.3 million for the nine months ended September 30, 2016, a decrease of $241.5 million compared to the nine months ended September 30, 2015. The $32.3 million loss for 2016 primarily related to unfavorable changes in the fair market value of EQT Production's NYMEX swaps partly offset by favorable changes in the fair market value of basis swaps. During the nine months ended September 30, 2016, forward NYMEX prices increased while basis prices decreased.

Net income attributable to noncontrolling interests of EQGP and EQM was $238.7 million for the nine months ended September 30, 2016 compared to $165.4 million for the nine months ended September 30, 2015. The $73.3 million increase was primarily the result of increased net income at EQM and increased noncontrolling interests as a result of EQM and EQGP issuances of common and limited partner units in 2015 and 2016.

Income tax benefit was $151.8 million for the nine months ended September 30, 2016, compared to income tax expense of $28.4 million for the nine months ended September 30, 2015. The Company’s effective income tax rate was 87.2% and 6.9% for the nine months ended September 30, 2016 and 2015, respectively. The increase in income tax benefit was primarily attributable to the effect of income allocated to the noncontrolling limited parters of EQGP and EQM, a reduction in EQT Production segment operating income primarily resulting from lower realized commodity prices and a loss on derivatives not designated as hedges. The Company’s effective tax rate differed from the U.S Federal statutory rate of 35% for both periods as the Company consolidates 100% of the pre-tax income related to the noncontrolling public limited partners’ share of EQGP income, but is not required to record an income tax provision with respect to the portion of the income allocated to EQGP and EQM noncontrolling public limited partners. A $35.5 million income tax benefit reduced income tax expense during the nine months ended September 30, 2015 related to Internal Revenue Service guidance received by the Company in 2015 in connection with the Company’s 2013 sale of Equitable Gas Company, LLC, a regulated entity. The deferred tax benefit will reverse during the fourth quarter of 2016 as a result of the disposal of certain regulated assets as part of the October 2016 Sale discussed in Note O.

On May 2, 2016, the Company entered into an Underwriting Agreement with Credit Suisse Securities (USA) LLC and J.P. Morgan Securities LLC, as representatives of the several underwriters named in the Underwriting Agreement (the Underwriters), under which the Company sold to the Underwriters 10,500,000 shares of the Company's common stock, no par value (common stock), at a price to the public of $67.00 per share (the May Offering). On May 3, 2016, the Underwriters exercised their option within the Underwriting Agreement to purchase an additional 1,575,000 shares of common stock on the same terms. The May Offering closed on May 6, 2016, and the Company received net proceeds of approximately $795.6 million, after deducting underwriting discounts and commissions and offering expenses. The Company used a portion of the net proceeds from the offering to fund the Statoil Acquisition (as defined in Note N to the Condensed Consolidated Financial Statements), and intends to use the remainder to fund the acquisitions discussed in Note O and for general corporate purposes.

On February 19, 2016, the Company entered into an Underwriting Agreement with Goldman, Sachs & Co. (Goldman), under which the Company sold to Goldman 6,500,000 shares of common stock, at a price to the public of $58.50 per share (the February Offering). On February 22, 2016, Goldman exercised its option within the Underwriting Agreement to purchase an additional 975,000 shares of common stock on the same terms. The February Offering closed on February 24, 2016, and the Company received net proceeds of approximately $430.4 million, after deducting underwriting discounts and commissions and offering expenses. The Company intends to use the net proceeds from the offering for general corporate purposes.

As a result of declining production volumes in the Company’s non-core Huron play and the depressed commodity price environment, the Company consolidated its Huron operations in Kentucky, Virginia, and southern West Virginia during the first quarter of 2016. The consolidation is expected to improve the Company’s cost structure for its Huron operations.  The Company recorded restructuring charges of $4.2 million related to the Huron operations consolidation in March 2016.

See “Business Segment Results of Operations” for a discussion of production sales volumes and gathering and transmission firm reservation revenues.

See “Investing Activities” under the caption “Capital Resources and Liquidity” for a discussion of capital expenditures.


26

EQT Corporation and Subsidiaries
Management’s Discussion and Analysis of Financial Condition and Results of Operations

Consolidated Operational Data
 
The following operational information presents detailed liquid and natural gas operational information to assist in the understanding of the Company’s consolidated operations. The operational information in the table below presents an 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 Corporation total operating revenues as reported in the Statements of Consolidated Operations, the most directly comparable GAAP financial measure. See “Reconciliation of Non-GAAP Financial Measures” for a reconciliation of EQT Production adjusted operating revenues to EQT Corporation total operating revenues.

27

EQT Corporation and Subsidiaries
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)
 
2016
 
2015
 
%
 
2016
 
2015
 
%
NATURAL GAS
 
 
 
 
 
 

 
 
 
 
 
 
Sales volume (MMcf)
 
175,191

 
141,367

 
23.9

 
508,206

 
405,743

 
25.3

NYMEX price ($/MMBtu) (a)
 
$
2.81

 
$
2.77

 
1.4

 
$
2.29

 
$
2.80

 
(18.2
)
Btu uplift
 
$
0.27

 
$
0.28

 
(3.6
)
 
$
0.21

 
$
0.26

 
(19.2
)
Natural gas price ($/Mcf)
 
$
3.08

 
$
3.05

 
1.0

 
$
2.50

 
$
3.06

 
(18.3
)
 
 
 
 
 
 
 
 
 
 
 
 
 
Basis ($/Mcf) (b)
 
$
(1.21
)
 
$
(1.16
)
 
4.3

 
$
(0.80
)
 
$
(0.64
)
 
25.0

Cash settled basis swaps (not designated as hedges)
($/Mcf)
 

 
0.01

 
(100.0
)
 
0.05

 
(0.02
)
 
(350.0
)
Average differential, including cash settled basis
swaps ($/Mcf)
 
$
(1.21
)
 
$
(1.15
)
 
5.2

 
$
(0.75
)
 
$
(0.66
)
 
13.6

 
 
 
 
 
 
 
 
 
 
 
 
 
Average adjusted price ($/Mcf)
 
$
1.87

 
$
1.91

 
(2.1
)
 
$
1.75

 
$
2.39

 
(26.8
)
Cash settled derivatives (cash flow hedges) ($/Mcf)
 
0.14

 
0.46

 
(69.6
)
 
0.14

 
0.50

 
(72.0
)
Cash settled derivatives (not designated as hedges)
($/Mcf)
 
0.15

 
0.21

 
(28.6
)
 
0.38

 
0.19

 
100.0

Average natural gas price, including cash settled derivatives ($/Mcf)
 
$
2.16

 
$
2.58

 
(16.3
)
 
$
2.27

 
$
3.08

 
(26.3
)
 
 
 
 
 
 
 
 
 
 
 
 
 
Natural gas sales, including cash settled derivatives
 
$
378,484

 
$
365,266

 
3.6

 
$
1,155,898

 
$
1,251,140

 
(7.6
)
 
 
 
 
 
 
 
 
 
 
 
 
 
LIQUIDS
 
 
 
 
 
 

 
 
 
 
 
 

NGLs (excluding ethane):
 
 
 
 
 
 

 
 
 
 
 
 

Sales volume (MMcfe) (c)
 
14,536

 
13,827

 
5.1

 
41,731

 
39,552

 
5.5

Sales volume (Mbbls)
 
2,422

 
2,305

 
5.1

 
6,955

 
6,592

 
5.5

Price ($/Bbl)
 
$
17.13

 
$
11.12

 
54.0

 
$
16.42

 
$
18.11

 
(9.3
)
NGL sales
 
$
41,508

 
$
25,628

 
62.0

 
$
114,188

 
$
119,403

 
(4.4
)
Ethane:
 
 
 
 
 
 
 
 
 
 
 
 
Sales volume (MMcfe) (c)
 
5,234

 

 
100.0

 
7,310

 

 
100.0

Sales volume (Mbbls)
 
872

 

 
100.0

 
1,218

 

 
100.0

Price ($/Bbl)
 
$
4.55

 
$

 
100.0

 
$
4.59

 
$

 
100.0

Ethane sales
 
$
3,966

 
$

 
100.0

 
$
5,590

 
$

 
100.0

Oil:
 
 
 
 
 
 

 
 
 
 
 
 

Sales volume (MMcfe) (c)
 
1,124

 
1,102

 
2.0

 
3,321

 
3,250

 
2.2

Sales volume (Mbbls)
 
188

 
184

 
2.2

 
554

 
542

 
2.2

Price ($/Bbl)
 
$
35.81

 
$
39.13

 
(8.5
)
 
$
32.81

 
$
41.02

 
(20.0
)
Oil sales
 
$
6,710

 
$
7,187

 
(6.6
)
 
$
18,164

 
$
22,221

 
(18.3
)
 
 
 
 
 
 
 
 
 
 
 
 
 
Total liquids sales volume (MMcfe) (c)
 
20,894

 
14,929

 
40.0

 
52,362

 
42,802

 
22.3

Total liquids sales volume (Mbbls)
 
3,482

 
2,489

 
39.9

 
8,727

 
7,134

 
22.3

 
 
 
 
 
 
 
 
 
 
 
 
 
Liquids sales
 
$
52,184

 
$
32,815

 
59.0

 
$
137,942

 
$
141,624

 
(2.6
)
 
 
 
 
 
 
 
 
 
 
 
 
 
TOTAL PRODUCTION
 
 
 
 
 
 
 
 
 
 
 
 
Total natural gas & liquids sales, including cash settled derivatives (d)
 
$
430,668

 
$
398,081

 
8.2

 
$
1,293,840

 
$
1,392,764

 
(7.1
)
Total sales volume (MMcfe)
 
196,085

 
156,296

 
25.5

 
560,568

 
448,545

 
25.0

 
 
 
 
 
 
 
 
 
 
 
 
 
Average realized price ($/Mcfe)
 
$
2.20

 
$
2.55

 
(13.7
)
 
$
2.31

 
$
3.11

 
(25.7
)

(a)
The Company’s volume weighted NYMEX natural gas price (actual average NYMEX natural gas price ($/MMBtu) was $2.81 and $2.77 for the three months ended September 30, 2016 and 2015, respectively, and $2.29 and $2.80 for the nine months ended September 30, 2016 and 2015, 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 financial measure.



28

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 Corporation total operating revenues as reported in the Statements of Consolidated Operations, its most directly comparable financial measure calculated in accordance with GAAP.

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 as presented excludes the revenue impact of changes in the fair value of derivative instruments prior to settlement and the revenue impact of certain 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 "Net marketing services" because management considers these revenues to be unrelated to the revenues for its natural gas and liquids production. "Net marketing services" includes 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 for investors for evaluating period-over-period earnings.

Calculation of EQT Production adjusted operating revenues
Three Months Ended September 30,
 
Nine Months Ended September 30,
$ in thousands (unless noted)
2016
 
2015
 
2016
 
2015
EQT Production total operating revenues
$
502,546

 
$
531,284

 
$
1,052,516

 
$
1,563,830

(Deduct) add back:
 
 
 
 
 
 
 
(Gain) loss on derivatives not designated as hedges
(93,356
)
 
(160,458
)
 
32,342

 
(209,881
)
Net cash settlements received on derivatives not designated as hedges
27,287

 
33,170

 
222,516

 
69,714

Premiums paid for derivatives that settled during the period
(558
)
 
(1,029
)
 
(1,574
)
 
(3,054
)
Net marketing services
(5,251
)
 
(4,886
)
 
(11,960
)
 
(27,845
)
EQT Production adjusted operating revenues, a non-GAAP financial measure
$
430,668

 
$
398,081

 
$
1,293,840

 
$
1,392,764

 
 
 
 
 
 
 
 
Total sales volumes (MMcfe)
196,085

 
156,296

 
560,568

 
448,545

 
 
 
 
 
 
 
 
Average realized price ($/Mcfe)
$
2.20

 
$
2.55

 
$
2.31

 
$
3.11

 
 
 
 
 
 
 
 
EQT Production total operating revenues
$
502,546

 
$
531,284

 
$
1,052,516

 
$
1,563,830

EQT Midstream total operating revenues
214,335

 
198,579

 
653,362

 
599,235

Less: intersegment revenues, net
(160,155
)
 
(145,885
)
 
(476,552
)
 
(424,683
)
EQT Corporation total operating revenues, as reported in accordance with GAAP
$
556,726

 
$
583,978

 
$
1,229,326

 
$
1,738,382


29

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 consist primarily of incentive compensation expense and administrative costs.

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 segment 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 F to the Condensed Consolidated Financial Statements in this Quarterly Report on Form 10-Q. 

30

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,
 
2016
 
2015
 
%
 
2016
 
2015
 
%
OPERATIONAL DATA
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Sales volume detail (MMcfe):
 

 
 

 
 

 
 

 
 

 
 

Marcellus (a)
171,468

 
129,645

 
32.3

 
486,439

 
373,522

 
30.2

Other (b)
24,617

 
26,651

 
(7.6
)
 
74,129

 
75,023

 
(1.2
)
Total production sales volumes (c)
196,085

 
156,296

 
25.5

 
560,568

 
448,545

 
25.0

 
 
 
 
 
 
 
 
 
 
 
 
Average daily sales volumes (MMcfe/d)
2,131

 
1,699

 
25.4

 
2,046

 
1,643

 
24.5

 
 
 
 
 
 
 
 
 
 
 
 
Average realized price ($/Mcfe)
$
2.20

 
$
2.55

 
(13.7
)
 
$
2.31

 
$
3.11

 
(25.7
)
 
 
 
 
 
 
 
 
 
 
 
 
Gathering to EQT Midstream ($/Mcfe)
$
0.62

 
$
0.72

 
(13.9
)
 
$
0.66

 
$
0.74

 
(10.8
)
Transmission to EQT Midstream ($/Mcfe)
$
0.19

 
$
0.19

 

 
$
0.19

 
$
0.19

 

Third-party gathering and transmission ($/Mcfe)
$
0.29

 
$
0.29

 

 
$
0.29

 
$
0.29

 

Processing ($/Mcfe)
$
0.17

 
$
0.17

 

 
$
0.16

 
$
0.17

 
(5.9
)
Lease operating expenses (LOE), excluding production taxes ($/Mcfe)
$
0.09

 
$
0.12

 
(25.0
)
 
$
0.09

 
$
0.12

 
(25.0
)
Production taxes ($/Mcfe)
$
0.05

 
$
0.09

 
(44.4
)
 
$
0.06

 
$
0.09

 
(33.3
)
Production depletion ($/Mcfe)
$
1.06

 
$
1.16

 
(8.6
)
 
$
1.06

 
$
1.16

 
(8.6
)
 
 
 
 
 
 
 
 
 
 
 
 
Depreciation, depletion and amortization (DD&A) (thousands):
 

 
 

 
 

 
 

 
 

 
 

Production depletion
$
207,120

 
$
181,857

 
13.9

 
$
594,408

 
$
521,741

 
13.9

Other DD&A
2,946

 
2,420

 
21.7

 
8,358

 
7,330

 
14.0

Total DD&A
$
210,066

 
$
184,277

 
14.0

 
$
602,766

 
$
529,071

 
13.9

 
 
 
 
 
 
 
 
 
 
 
 
Capital expenditures (thousands)
$
621,377

 
$
451,358

 
37.7

 
$
1,090,033

 
$
1,453,647

 
(25.0
)
 
 
 
 
 
 
 
 
 
 
 
 
FINANCIAL DATA (thousands)
 

 
 

 
 

 
 

 
 

 
 

 
 
 
 
 
 
 
 
 
 
 
 
Revenues:
 
 
 
 
 
 
 
 
 
 
 
Production sales
$
403,939

 
$
365,940

 
10.4

 
$
1,072,898

 
$
1,326,104

 
(19.1
)
Net marketing services
5,251

 
4,886

 
7.5

 
11,960

 
27,845

 
(57.0
)
Gain (loss) on derivatives not designated as hedges
93,356

 
160,458

 
(41.8
)
 
(32,342
)
 
209,881

 
(115.4
)
Total operating revenues
502,546

 
531,284

 
(5.4
)
 
1,052,516

 
1,563,830

 
(32.7
)
 
 
 
 
 
 
 
 
 
 
 
 
Operating expenses:
 

 
 

 
 

 
 

 
 

 
 

Gathering
135,113

 
119,507

 
13.1

 
403,514

 
348,317

 
15.8

Transmission
81,456

 
68,044

 
19.7

 
235,196

 
198,697

 
18.4

Processing
33,332

 
26,934

 
23.8

 
88,429

 
76,505

 
15.6

LOE, excluding production taxes
17,419

 
18,808

 
(7.4
)
 
50,127

 
53,615

 
(6.5
)
Production taxes
9,094

 
13,698

 
(33.6
)
 
36,326

 
41,739

 
(13.0
)
Exploration
2,670

 
8,163

 
(67.3
)
 
9,384

 
32,128

 
(70.8
)
Selling, general and administrative (SG&A)
35,406

 
35,493

 
(0.2
)
 
104,038

 
104,189

 
(0.1
)
DD&A
210,066

 
184,277

 
14.0

 
602,766

 
529,071

 
13.9

Impairment of long-lived assets

 

 

 

 
4,252

 
(100.0
)
Total operating expenses
524,556

 
474,924

 
10.5

 
1,529,780

 
1,388,513

 
10.2

Operating (loss) income
$
(22,010
)
 
$
56,360

 
(139.1
)
 
$
(477,264
)
 
$
175,317

 
(372.2
)
(a)
Includes Upper Devonian wells.
(b)
Includes 3,847 and 11,641 MMcfe of deep Utica sales volume for the three and nine months ended September 30, 2016, respectively, and 1,731 MMcfe of deep Utica sales volume for both the three and nine months ended September 30, 2015.
(c)
NGLs, ethane and crude oil were converted to Mcfe at the rate of six Mcfe per barrel for all periods.

31

EQT Corporation and Subsidiaries
Management’s Discussion and Analysis of Financial Condition and Results of Operations

Three Months Ended September 30, 2016 vs. Three Months Ended September 30, 2015
 
EQT Production’s operating loss totaled $22.0 million for the three months ended September 30, 2016 compared to operating income of $56.4 million for the three months ended September 30, 2015.  The $78.4 million decrease in operating income was primarily due to a lower average realized price, decreased gains on derivatives not designated as hedges and increased operating expenses, partly offset by increased sales of produced natural gas.
 
Total operating revenues were $502.5 million for the three months ended September 30, 2016 compared to $531.3 million for the three months ended September 30, 2015.  The decrease in operating revenues was primarily due to a 14% decrease in the average realized price and decreased gains on derivatives not designated as hedges, partly offset by a 26% increase in production sales volumes in the current year.
 
The components of average realized price, which includes the effects of cash settled derivatives, are outlined in the table on page 27. The $0.35 per Mcfe decrease in the average realized price for the three months ended September 30, 2016 was primarily due to the decrease in the average NYMEX natural gas price including the impact of cash settled derivatives of $0.35 per Mcf and a decrease in the average natural gas differential of $0.06 per Mcf, partly offset by higher NGL prices. The decrease in the average NYMEX natural gas price including the impact of cash settled derivatives between periods primarily related to lower average NYMEX hedge prices in the current year. The decrease in the average differential primarily related to the unfavorable impact of changes in natural gas prices on fixed price sales contracts and sales contracts with fixed differentials to NYMEX, partly offset by favorable Appalachian Basin basis.

The increase in production sales volumes was primarily the result of increased production from the 2014 and 2015 drilling programs, primarily in the Marcellus play. This increase was partially offset by the normal production decline in the Company’s producing wells.

Total operating revenues for the three months ended September 30, 2016 included a $93.4 million gain on derivatives not designated as hedges compared to a gain of $160.5 million for the three months ended September 30, 2015. The gains for the three months ended September 30, 2016 primarily related to favorable changes in the fair market value of EQT Production’s NYMEX and basis swaps due to a decrease in forward prices during the third quarter of 2016. EQT Production received $27.3 million and $33.2 million of net cash settlements for derivatives not designated as hedges for the three months ended September 30, 2016 and 2015, respectively. These net cash settlements are included in the above discussion of average realized price.
 
Operating expenses totaled $524.6 million for the three months ended September 30, 2016 compared to $474.9 million for the three months ended September 30, 2015. The increase in operating expenses was the result of increases in DD&A, gathering expense, transmission expense and processing expense, partly offset by decreases in exploration expense, production taxes and LOE. The increase in DD&A expense was the result of higher produced volumes partly offset by a lower overall depletion rate in the current year. Gathering expenses increased by $9.2 million due to increased affiliate firm capacity and volumetric charges and by $6.4 million due to increased third-party volumetric charges. Transmission expenses increased by $13.4 million primarily due to increased affiliate volumetric costs and increased third-party costs incurred to move EQT Production’s natural gas out of the Appalachian Basin. Processing expense increased by $6.4 million due to increased production volumes. Per unit gathering, transmission and processing expenses decreased as higher sales volumes more than offset the increased expenses. Exploration expense decreased by $5.5 million primarily due to decreased impairments of unproved lease acreage resulting from lease expirations during the third quarter 2016 compared to the third quarter 2015. The decrease in production taxes was primarily driven by a $2.6 million decrease in severance taxes due to the expiration of the West Virginia volume based tax in the current year and a $2.0 million decrease in property taxes primarily due to a change in assessment. The state of West Virginia previously imposed a $0.047 per Mcf additional volume based tax on severance that was terminated on July 1, 2016. The decrease in LOE was primarily due to lower personnel costs including incentive compensation. SG&A expense was flat quarter over quarter but included various offsetting items, including $2.8 million of increased legal reserves and a $1.2 million increase to the reserve for uncollectible accounts in 2016, offset by $3.5 million for rig release penalties incurred during the third quarter 2015.

Nine Months Ended September 30, 2016 vs. Nine Months Ended September 30, 2015
 
EQT Production’s operating loss totaled $477.3 million for the nine months ended September 30, 2016 compared to operating income of $175.3 million for the nine months ended September 30, 2015.  The decrease in operating income was primarily due to a lower average realized price, losses on derivatives not designated as hedges in the current year compared to gains on derivatives not designated as hedges in the prior year, increased operating expenses and decreased net marketing services revenue, partly offset by increased sales of produced natural gas.
 

32

EQT Corporation and Subsidiaries
Management’s Discussion and Analysis of Financial Condition and Results of Operations

Total operating revenues were $1,052.5 million for the nine months ended September 30, 2016 compared to $1,563.8 million for the nine months ended September 30, 2015.  Production sales decreased as a result of a lower average realized price, partly offset by a 25% increase in production sales volumes in the current year. EQT Production received $222.5 million and $69.7 million of net cash settlements for derivatives not designated as hedges for the nine months ended September 30, 2016 and 2015, respectively, that are included in the average realized price but not included in production sales. Changes in fair market value of derivative instruments prior to settlement are recognized in gain (loss) on derivatives not designated as hedges. The increase in production sales volumes was primarily the result of increased production from the 2014 and 2015 drilling programs, primarily in the Marcellus play. This increase was partially offset by the normal production decline in the Company’s producing wells.
 
The $0.80 per Mcfe decrease in the average realized price for the nine months ended September 30, 2016 was primarily due to the decrease in the average NYMEX natural gas price including the impact of cash settled derivatives of $0.73 per Mcf, a decrease in the average natural gas differential of $0.09 per Mcf and lower NGL prices. The decrease in the average differential primarily related to lower basis, partly offset by favorable cash settled basis swaps. While Appalachian Basin basis improved for the nine months ended September 30, 2016 compared to the same period in 2015, market prices in the United States Northeast region were significantly lower in the first quarter of 2016 compared to the first quarter of 2015 due to reduced demand attributable to warmer than normal weather conditions. Additionally, the impact of changes in natural gas prices on sales contracts with fixed differentials to NYMEX and fixed price sales contracts reduced basis period over period.

Net marketing services includes both the cost of and recoveries on third-party pipeline capacity not used to transport the Company's produced volumes. The $15.9 million decrease in these revenues primarily related to reduced spreads on the Company's Tennessee Gas Pipeline capacity, increased storage costs in the current year and the costs, net of recoveries, for the Company's Rockies Express Pipeline capacity contract that started in the third quarter of 2015.

Total operating revenues for the nine months ended September 30, 2016 included a $32.3 million loss on derivatives not designated as hedges compared to a gain of $209.9 million for the nine months ended September 30, 2015. The losses for the nine months ended September 30, 2016 primarily related to unfavorable changes in the fair market value of EQT Production’s NYMEX swaps, partially offset by favorable changes in the fair market value of basis swaps. During the nine months ended September 30, 2016, forward NYMEX prices increased while basis prices decreased.
 
Operating expenses totaled $1,529.8 million for the nine months ended September 30, 2016 compared to $1,388.5 million for the nine months ended September 30, 2015. The increase in operating expenses was the result of increases in DD&A, gathering expense, transmission expense and processing expense, partly offset by decreases in exploration expense, production taxes, impairment of long-lived assets and LOE. The increase in DD&A expense was the result of higher produced volumes partly offset by a lower overall depletion rate in the current year. Gathering expenses increased by $37.0 million due to increased affiliate firm capacity and volumetric costs and increased by $18.2 million due to increased third-party volumetric costs. Transmission expenses increased primarily due to $21.8 million of increased affiliate volumetric costs and increased third-party costs of $14.7 million incurred to move EQT Production’s natural gas out of the Appalachian Basin. Processing expense increased by $11.9 million as a result of the Company's production volume growth. Per unit gathering, transmission and processing expenses decreased as sales volumes increased more than these expenses. Exploration expense decreased by $22.7 million primarily due to decreased impairments of unproved lease acreage resulting from lease expirations during the nine months ended September 30, 2016 compared to the nine months ended September 30, 2015. The decrease in production taxes was primarily driven by lower property taxes of $2.9 million due to a change in the assessment during the nine months ended September 30, 2015 and a $2.8 million decrease as a result of lower commodity prices and expiration of the West Virginia volume based tax in the current year. The state of West Virginia previously imposed a $0.047 per Mcf additional volume based tax on severance that was terminated on July 1, 2016. Impairment of long-lived assets decreased due to a proved property impairment of the Utica Shale in Ohio of $4.3 million incurred during the nine months ended September 30, 2015. The decrease in LOE of $3.5 million was primarily due to decreased salt water disposal costs as a result of increased recycling in the Marcellus Shale. SG&A expense was flat year over year but included various offsetting items, including $8.7 million of increased legal reserves, a $3.0 million increase to the reserve for uncollectible accounts, $2.0 million of costs related to the consolidation of the Company's Huron operations and a charge of $1.7 million related to the termination of the EQT Corporation Retirement Plan for Employees (the Retirement Plan) incurred during the nine months ended September 30, 2016, offset by $10.4 million for drilling program reduction charges, including rig release penalties, incurred during the nine months ended September 30, 2015 and decreased personnel and professional services costs incurred during the nine months ended September 30, 2016.

33

EQT Corporation and Subsidiaries
Management’s Discussion and Analysis of Financial Condition and Results of Operations

EQT MIDSTREAM

RESULTS OF OPERATIONS
 
Three Months Ended September 30,
 
Nine Months Ended September 30,
 
2016
 
2015
 
%
 
2016
 
2015
 
%
OPERATIONAL DATA
 
 
 
 
 
 
 
 
 
 
 
Operating revenues (thousands):
 
 
 
 
 
 
 
 
 
 
 
Gathering
 
 
 
 
 
 
 
 
 
 
 
Firm reservation fee revenues
$
84,848

 
$
68,205

 
24.4

 
$
252,993

 
$
194,869

 
29.8

Volumetric based fee revenues:
 
 
 
 
 
 
 
 
 
 
 
Usage fees under firm contracts (a)
10,027

 
8,815

 
13.7

 
31,883

 
25,567

 
24.7

Usage fees under interruptible contracts
41,829

 
49,435

 
(15.4
)
 
125,192

 
158,288

 
(20.9
)
Total volumetric based fee revenues
51,856

 
58,250

 
(11.0
)
 
157,075

 
183,855

 
(14.6
)
Total gathering revenues
$
136,704

 
$
126,455

 
8.1

 
$
410,068

 
$
378,724

 
8.3

 
 
 
 
 
 
 
 
 
 
 
 
Transmission
 
 
 
 
 
 
 
 
 
 
 
Firm reservation fee revenues
$
52,655

 
$
50,657

 
3.9

 
$
169,325

 
$
162,602

 
4.1

Volumetric based fee revenues:
 
 
 
 
 
 
 
 
 
 
 
Usage fees under firm contracts (a)
14,470

 
11,129

 
30.0

 
41,803

 
29,706

 
40.7

Usage fees under interruptible contracts
2,340

 
897

 
160.9

 
7,214

 
3,422

 
110.8

Total volumetric based fee revenues
16,810

 
12,026

 
39.8

 
49,017

 
33,128

 
48.0

Total transmission revenues
$
69,465

 
$
62,683

 
10.8

 
$
218,342

 
$
195,730

 
11.6

 
 
 
 
 
 
 
 
 
 
 
 
Storage, marketing and other revenues
8,166

 
9,441

 
(13.5
)
 
24,952

 
24,781

 
0.7

Total operating revenues
$
214,335

 
$
198,579

 
7.9

 
$
653,362

 
$
599,235

 
9.0

 
 
 
 
 
 
 
 
 
 
 
 
Gathered volumes (BBtu per day):
 
 
 
 


 
 
 
 
 


Firm reservation
1,563

 
1,150

 
35.9

 
1,507

 
1,085

 
38.9

Volumetric based services (b)
855

 
947

 
(9.7
)
 
871

 
967

 
(9.9
)
Total gathered volumes
2,418

 
2,097

 
15.3

 
2,378

 
2,052

 
15.9

 
 
 
 
 
 
 
 
 
 
 
 
Gathering and compression expense ($/MMBtu)
$
0.10

 
$
0.12

 
(16.7
)
 
$
0.10

 
$
0.12

 
(16.7
)
 
 
 
 
 
 
 
 
 
 
 
 
Transmission pipeline throughput (BBtu per day):
 
 
 
 


 
 
 
 
 


Firm capacity reservation
1,440

 
1,751

 
(17.8
)
 
1,515

 
1,866

 
(18.8
)
Volumetric based services (b)
610

 
300

 
103.3

 
556

 
257

 
116.3

Total transmission pipeline throughput
2,050

 
2,051

 

 
2,071

 
2,123

 
(2.4
)
 
 
 
 
 
 
 
 
 
 
 
 
Average contracted firm transmission reservation commitments (BBtu per day)
2,365

 
2,390

 
(1.0
)
 
2,591

 
2,567

 
0.9

 
 
 
 
 
 
 
 
 
 
 
 
Capital expenditures (thousands)
$
171,645

 
$
130,902

 
31.1

 
$
513,776

 
$
368,019

 
39.6

 
 
 
 
 
 
 
 
 
 
 
 
FINANCIAL DATA (thousands)
 

 
 

 
 

 
 

 
 

 
 

Total operating revenues
$
214,335

 
$
198,579

 
7.9

 
$
653,362

 
$
599,235

 
9.0

Operating expenses:
 

 
 

 
 

 
 

 
 

 
 

Operation and maintenance (O&M)
30,867

 
35,691

 
(13.5
)
 
92,162

 
100,399

 
(8.2
)
SG&A
23,804

 
26,048

 
(8.6
)
 
82,138

 
77,477

 
6.0

DD&A
26,937

 
23,830

 
13.0

 
79,948

 
70,417

 
13.5

Total operating expenses
81,608

 
85,569

 
(4.6
)
 
254,248

 
248,293

 
2.4

Operating income
$
132,727

 
$
113,010

 
17.4

 
$
399,114

 
$
350,942

 
13.7


(a)
Includes commodity charges and fees on volumes gathered or transported in excess of firm contracted capacity.
(b)
Includes volumes gathered or transported under interruptible contracts and volumes in excess of firm contracted capacity. 

34

EQT Corporation and Subsidiaries
Management’s Discussion and Analysis of Financial Condition and Results of Operations

Three Months Ended September 30, 2016 vs. Three Months Ended September 30, 2015
 
EQT Midstream’s operating income totaled $132.7 million for the three months ended September 30, 2016 compared to $113.0 million for the three months ended September 30, 2015. The increase in operating income was primarily the result of increased gathering and transmission operating revenues and lower operating expenses, partly offset by lower storage, marketing and other operating revenues.

Gathering revenues increased by $10.2 million primarily as a result of higher affiliate and third-party volumes gathered for the three months ended September 30, 2016 compared to the three months ended September 30, 2015, driven by increased affiliate and third-party production development in the Marcellus Shale, partly offset by reduced affiliate volumes in the Huron shale. EQT Midstream increased firm reservation fee revenues for the three months ended September 30, 2016 compared to the three months ended September 30, 2015 as a result of increased capacity under firm contracts with affiliates and third-party producers. Higher volumes transported on these contracts also resulted in an increase in usage fees under firm contracts. The decrease in usage fees under interruptible contracts was primarily due to affiliates contracting for additional firm capacity and the reduced volumes in the Huron shale.

Transmission revenues increased by $6.8 million for the three months ended September 30, 2016 compared to the three months ended September 30, 2015. This was driven by higher usage fees under firm contracts as a result of an increase in affiliate volumes in excess of firm capacity associated with increased production development in the Marcellus Shale, partly offset by lower usage fees from third-party producers which is reflected in reduced firm capacity reservation throughput for the three months ended September 30, 2016 compared to the three months ended September 30, 2015. This reduction did not have a significant impact on firm reservation fee revenues. Firm reservation fees increased as a result of higher contractual rates on existing contracts in the current year. Usage fees under interruptible contracts for the three months ended September 30, 2016 increased as a result of higher affiliate and third-party volumes transported on an interruptible basis.

Total operating expenses decreased by $4.0 million for the three months ended September 30, 2016 compared to the three months ended September 30, 2015. O&M expense decreased $4.8 million primarily as a result of a $2.8 million decrease in purchased gas costs related to lower gas prices and $1.1 million of lower personnel costs. SG&A expense decreased $2.2 million primarily due to a $2.0 million decrease in incentive compensation. Increased allocated expenses from affiliates were partly offset by an environmental reserve recorded in the third quarter of 2015. These decreases were partly offset by an increase in DD&A of $3.1 million as a result of additional assets placed in-service.

Nine Months Ended September 30, 2016 vs. Nine Months Ended September 30, 2015
 
EQT Midstream’s operating income totaled $399.1 million for the nine months ended September 30, 2016 compared to $350.9 million for the nine months ended September 30, 2015. The increase in operating income was the result of increased gathering and transmission operating revenues, partly offset by increased operating expenses.
 
Gathering revenues increased by $31.3 million primarily as a result of higher affiliate and third-party volumes gathered for the nine months ended September 30, 2016 compared to the nine months ended September 30, 2015, driven by production development in the Marcellus Shale partly offset by reduced volumes in the Huron shale. EQT Midstream increased firm reservation fee revenues for the nine months ended September 30, 2016 compared to the nine months ended September 30, 2015 as a result of increased capacity under firm contracts with affiliates and third-party producers. Higher volumes transported on these contracts also resulted in an increase in usage fees under firm contracts. The decrease in usage fees under interruptible contracts was primarily due to affiliates contracting for additional firm capacity and the reduced volumes in the Huron shale.

Transmission revenues increased by $22.6 million for the nine months ended September 30, 2016 compared to the nine months ended September 30, 2015. This was driven by higher usage fees under firm contracts as a result of an increase in affiliate volumes in excess of firm capacity associated with increased production development in the Marcellus Shale, partly offset by lower usage fees from third-party producers which is reflected in reduced firm capacity reservation throughput for the nine months ended September 30, 2016 compared to the nine months ended September 30, 2015. These volumes also decreased as a result of warmer weather during the first quarter of 2016. This decrease in transported volumes did not have a significant impact on firm reservation fee revenues. Firm reservation fees increased as a result of higher contractual rates on existing contracts in the current year. Usage fees under interruptible contracts for the nine months ended September 30, 2016 increased as a result of higher affiliate and third-party volumes transported on an interruptible basis.


35

EQT Corporation and Subsidiaries
Management’s Discussion and Analysis of Financial Condition and Results of Operations

Total operating expenses increased by $6.0 million for the nine months ended September 30, 2016 compared to the nine months ended September 30, 2015. O&M expense decreased $8.2 million primarily as a result of a $5.9 million decrease in purchased gas costs related to reduced marketing activity, $1.5 million of lower property taxes due to a change in the assessment during the nine months ended September 30, 2015, lower pipeline operating costs and lower incentive compensation costs partly offset by $1.9 million of expense related to the consolidation of the Company’s Huron operations. SG&A expense increased $4.7 million primarily as a result of $7.7 million of expense recorded in connection with the termination of the Retirement Plan and increased allocated expenses from affiliates, partly offset by $1.9 million related to the impairment of certain expiring right of way options in 2015, $1.6 million of lower personnel costs primarily related to incentive compensation and an environmental reserve recorded in the third quarter of 2015. DD&A increased $9.5 million as a result of additional assets being placed in-service.

Other Income Statement Items

Other Income

Other income increased by $8.1 million for the three months ended September 30, 2016 compared to the three months ended September 30, 2015 primarily driven by increased Allowance for Funds Used During Construction (AFUDC) - equity of $6.1 million, mainly attributable to increased spending on the Ohio Valley Connector (OVC) project, and $2.0 million in higher equity income related to EQM's portion of the MVP Joint Venture's AFUDC on the MVP project.

Other income increased by $16.9 million for the nine months ended September 30, 2016 compared to the nine months ended September 30, 2015 primarily driven by increased AFUDC - equity of $12.9 million, mainly attributable to increased spending on the OVC project, and $4.8 million in higher equity income related to EQM's portion of the MVP Joint Venture's AFUDC on the MVP project.


36

EQT Corporation and Subsidiaries
Management’s Discussion and Analysis of Financial Condition and Results of Operations

OUTLOOK
 
The Company is committed to profitably developing its natural gas and NGL reserves through environmentally responsible, cost-effective and technologically advanced horizontal drilling. 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 as well as gathering and transmission revenues from third parties, which represented 10% of the Company's consolidated revenues for the nine months ended September 30, 2016. Despite the continued depressed price environment for natural gas and NGLs, the Company believes the long-term outlook for its business is favorable due to the Company’s large resource base, low cost structure, financial strength, risk management, including 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.

Total capital investment by EQT in 2016, excluding acquisitions, is expected to be approximately $1.8 billion (including EQM). Capital spending for well development (primarily drilling and completions) of approximately $1.0 billion in 2016 is expected to support the drilling of approximately 140 wells, including 135 Marcellus and Upper Devonian wells and 5 deep Utica wells. Estimated sales volumes are expected to be 750 - 755 Bcfe, for an anticipated production sales volume growth of approximately 25% in 2016 as compared to 2015, while total liquids sales volumes are expected to be 11,825 - 11,915 Mbbls. To support continued growth in production, the Company plans to invest approximately $0.8 billion on midstream infrastructure in 2016, primarily through EQM.

The market prices for natural gas in the Appalachian Basin and NGLs were depressed throughout 2015 and the nine months ended September 30, 2016. 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 basis, and NGLs and thus cannot predict the ultimate impact of prices on its operations. Low prices may signal a need to reduce capital spending, record non-cash impairments in the book value of the Company’s gas properties and midstream assets, and/or make 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 “Critical Accounting Policies and Estimates” included in the Company's Annual Report on Form 10-K for the year ended December 31, 2015 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. As a result of its third quarter 2016 evaluations, the Company did not recognize an impairment charge for proved properties. However, a further decline in the average five-year forward realized prices in a future period may cause the Company to recognize a significant impairment on the assets in the Huron play, which had a carrying value of approximately $3 billion at September 30, 2016. The Company anticipates an impairment on certain gathering assets as a result of the sale of these assets to EQM in October 2016.

The Company continues to focus on creating and maximizing shareholder value through the implementation of a strategy that economically monetizes its asset base and prudently pursues investment opportunities, all while maintaining a strong balance sheet with solid cash flow. The Company monitors current and expected market conditions, including the commodity price environment, and its liquidity needs and may adjust its capital investment plan accordingly. While the tactics continue to evolve based on market conditions, the Company periodically considers arrangements to monetize the value of certain mature assets for re-deployment into its highest value development opportunities. The Company continues to consider transactions that would add to its Marcellus and Utica positions with a focus on transactions that would add contiguous acreage or fill-in existing gaps.

37

EQT Corporation and Subsidiaries
Management’s Discussion and Analysis of Financial Condition and Results of Operations

CAPITAL RESOURCES AND LIQUIDITY
 
Overview
 
The Company’s primary sources of cash for the nine months ended September 30, 2016 were proceeds from the public offerings of EQT common stock and cash flows from operating activities, while the primary use of cash was for capital expenditures.
 
Operating Activities
 
Net cash flows provided by operating activities totaled $767.7 million for the nine months ended September 30, 2016 compared to $900.2 million for the nine months ended September 30, 2015.  The $132.5 million decrease in cash flows provided by operating activities was primarily the result of lower operating income, the reasons for which are discussed in the section captioned "Corporate Overview" in Item 2, "Management's Discussion and Analysis of Financial Condition and Results of Operations," partially offset by higher cash settlements on derivatives not designated as hedges and a decrease in cash paid for income taxes.

The Company's cash flows from operating activities will be impacted by future movements in the market price for commodities. The Company is unable to predict these future price movements.

Investing Activities
 
Net cash flows used in investing activities totaled $1,669.4 million for the nine months ended September 30, 2016 compared to $1,975.2 million for the nine months ended September 30, 2015. The $305.8 million decrease was primarily due to a decrease in capital expenditures of $706.0 million due to a reduction in the drilling and completions activity over the last twelve months, partly offset by $412.3 million of capital expenditures resulting from the Statoil acquisition in 2016 and an increase in capital expenditures related to the OVC project. The Company spud 68 gross wells in the first nine months of 2016, including 65 horizontal Marcellus and Upper Devonian wells and 3 horizontal Utica wells. The Company spud 134 gross wells in the first nine months of 2015, including 130 horizontal Marcellus and Upper Devonian wells, 2 horizontal Utica wells and 2 horizontal Permian Basin wells.

Capital expenditures as reported on the Statement of Condensed Consolidated Cash Flows for the nine months ended September 30, 2016 and 2015 excluded capitalized non-cash stock-based compensation expense and 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 impact of these non-cash items was $1.2 million and $(75.6) million for the nine months ended September 30, 2016 and 2015, respectively.

Financing Activities
 
Net cash flows provided by financing activities totaled $1,057.9 million for the nine months ended September 30, 2016 compared to $1,660.2 million for the nine months ended September 30, 2015, a decrease of $602.3 million between periods. During the first nine months of 2016, the Company's primary sources of financing cash flows were net proceeds from its public offerings of common stock and from EQM's public offerings of common units under the $750 million ATM Program. The primary financing uses of cash during this period were net credit facility repayments under the EQM credit facility, distributions to noncontrolling interests, and payment of taxes related to the vesting or exercise of equity awards. During the nine months ended September 30, 2015, financing cash flows were from EQM's public offering of common units, including sales under the $750 million ATM Program, net proceeds from EQGP's IPOs and net proceeds from borrowings on EQM's credit facility; the primary financing uses of cash were distributions to noncontrolling interests and income tax withholdings related to the vesting or exercise of equity awards.

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 and contractual and legal restrictions and other factors.


38

EQT Corporation and Subsidiaries
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, 2016.  Changes in credit ratings may affect the Company’s cost of short-term and long-term debt (including interest rates and fees under its lines of credit), collateral requirements under derivative instruments, pipeline capacity contracts, joint venture arrangements and subsidiary construction contracts, and access to the credit markets.
Rating Service
 
Senior Notes
 
Outlook
Moody’s Investors Service
 
Baa3
 
Stable
Standard & Poor’s Ratings Service
 
BBB
 
Stable
Fitch Ratings Service
 
BBB-
 
Stable
 
The table below reflects the credit ratings for debt instruments of EQM at September 30, 2016.  Changes in credit ratings may affect EQM’s cost of short-term and long-term debt (including interest rates and fees under its lines of credit); collateral requirements under joint venture arrangements and construction contracts; and access to the credit markets.
Rating Service
 

Senior Notes
 
Outlook
Moody’s Investors Service
 
Ba1
 
Stable
Standard & Poor’s Ratings Service
 
BBB-
 
Stable
Fitch Ratings Service
 
BBB-
 
Stable

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.  The required margin on the Company’s derivative instruments is also 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 a company's credit as assessed by one or more credit rating agencies. In order to be considered investment grade, a company must be rated BBB- or higher by Standard & Poor's Rating Service, Baa3 or higher by Moody's Investors Service, and BBB- or higher by Fitch Ratings Service. Anything below these ratings is considered non-investment grade.

The Company has a $1.5 billion unsecured credit facility that expires in February 2019; the Company had no amounts outstanding under the facility as of September 30, 2016. The Company’s debt agreements and other financial obligations contain various provisions that, if not complied with, could result in termination of the agreements, require early payment of amounts outstanding or similar actions.  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, 2016, the Company was in compliance with all debt provisions and covenants.

EQM has a $750 million credit facility that expires in February 2019, and EQM had $91 million in outstanding borrowings under the facility as of September 30, 2016. EQM’s debt agreements and other financial obligations contain various provisions that, if not complied with, could result in termination of the agreements, require early payment of amounts outstanding or similar actions.  The covenants and events of default under the debt agreements relate to maintenance of 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 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, 2016, EQM was in compliance with all debt provisions and covenants.


39

EQT Corporation and Subsidiaries
Management’s Discussion and Analysis of Financial Condition and Results of Operations

On October 26, 2016, EQM entered into a $500 million, 364-day, uncommitted revolving loan agreement with EQT (the 364-Day Facility). The 364-Day Facility will mature on October 25, 2017 and will automatically renew for successive 364-day periods unless EQT delivers a non-renewal notice at least 60 days prior to the then current maturity date. EQM may terminate the 364-Day Facility at any time by repaying in full the unpaid principal amount of all loans together with interest thereon. The 364-Day Facility is available for general partnership purposes and does not contain any covenants other than the obligation to pay accrued interest on outstanding borrowings. Interest will accrue on any outstanding borrowings at an interest rate equal to the rate then applicable to similar loans under EQM's $750 Million revolving credit facility, or a successor revolving credit facility, less the sum of (i) the then applicable commitment fee under EQM's $750 Million revolving credit facility and (ii) 10 basis points.

EQM ATM Program

During 2015, EQM entered into an equity distribution agreement that established an “At the Market” (ATM) common unit offering program, pursuant to which a group of managers acting as EQM’s sales agents may sell EQM common units having an aggregate offering price of up to $750 million. EQM had approximately $443 million in remaining capacity under the program as of October 27, 2016

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 and collars.

As of October 25, 2016, the approximate volumes and prices of the Company’s derivative commodity instruments hedging sales of produced gas for 2016 through 2018 were:
NYMEX Swaps
 
2016 (a)(b)
 
2017 (b)(c)
 
2018 (b)(c)
Total Volume (Bcf)
 
77

 
266

 
105

Average Price per Mcf (NYMEX) (d)
 
$
3.64

 
$
3.31

 
$
3.13

Collars
 
 

 
 

 
 

Total Volume (Bcf)
 
1

 
17

 

Average Floor Price per Mcf (NYMEX) (d)
 
$
2.84

 
$
2.98

 
$

Average Cap Price per Mcf (NYMEX) (d)
 
$
3.36

 
$
3.92

 
$


(a)     October through December 31.
(b)     The Company also sold calendar year 2016, 2017 and 2018 calls for approximately 11 Bcf, 32 Bcf and 16 Bcf at strike prices of $3.65 per Mcf, $3.53 per Mcf and $3.48 per Mcf, respectively.
(c)
For 2017 and 2018, the Company also sold puts for approximately 3 Bcf at a strike price of $2.63 per Mcf.
(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 are satisfied by physical delivery. The difference between these sales prices and NYMEX are included in average differential on the Company's Price Reconciliation. The Company has fixed price physical sales for the remainder of 2016 and 2017 of 9 Bcf and 24 Bcf at average prices of $3.09 per Mcf and $2.97 per Mcf, respectively. For 2016 through 2018, the Company has a natural gas sales agreement for approximately 35 Bcf per year that includes a NYMEX ceiling price of $4.88 per Mcf. For 2018, the Company has a natural gas sales agreement for approximately 7 Bcf per year that includes a NYMEX floor price of $2.16 per Mcf and a ceiling price of $4.47 per Mcf. The Company has also entered into derivative instruments to hedge basis and a limited number of contracts to hedge its NGL 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 G to the Company’s Condensed Consolidated Financial Statements for further discussion of the Company’s hedging program. 


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EQT Corporation and Subsidiaries
Management’s Discussion and Analysis of Financial Condition and Results of Operations

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.

Off-Balance Sheet Arrangements

As of September 30, 2016, EQM had issued a $91 million performance guarantee (the Initial Guarantee) in connection with the obligations of MVP Holdco, LLC (MVP Holdco) to fund its proportionate share of the construction budget for the MVP. Upon the Federal Energy Regulatory Commission’s initial release to begin construction of the MVP, the Initial Guarantee will terminate, and EQM will be obligated to issue a new guarantee in an amount equal to 33% of MVP Holdco’s remaining obligations to make capital contributions to the MVP Joint Venture in connection with the then remaining construction budget, less, subject to certain limits, any credit assurances issued by an affiliate of EQM under such affiliate's precedent agreement with the MVP Joint Venture.

Dividend
 
On October 12, 2016, the Board of Directors of the Company declared a regular quarterly cash dividend of three cents per share, payable December 1, 2016, to the Company’s shareholders of record at the close of business on November 11, 2016.

On October 25, 2016, the Board of Directors of EQGP’s general partner declared a cash distribution to EQGP’s unitholders for the third quarter of 2016 of $0.165 per common unit, or approximately $43.9 million.  The distribution will be paid on November 22, 2016 to unitholders of record, including the Company, at the close of business on November 4, 2016.

On October 25, 2016, the Board of Directors of EQM’s general partner declared a cash distribution to EQM’s unitholders for the third quarter of 2016 of $0.815 per common unit. The cash distribution will be paid on November 14, 2016 to unitholders of record, including EQGP, at the close of business on November 4, 2016. Based on the 80,581,758 EQM common units outstanding on October 27, 2016, the aggregate cash distributions by EQM to EQGP will be approximately $44.3 million consisting of: $17.8 million in respect of its limited partner interest, $1.6 million in respect of its general partner interest and $24.9 million in respect of its incentive distribution rights. The distributions to EQGP in respect of its general partner interest and incentive distribution rights in EQM are subject to change if EQM issues additional common units on or prior to the record date for the third quarter 2016 distribution.
 
Critical Accounting Policies
 
The Company’s critical accounting policies are described in Item 7, “Management’s Discussion and Analysis of Financial Condition and Results of Operations,” contained in the Company’s Annual Report on Form 10-K for the year ended December 31, 2015.  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 for the three and nine month periods ended September 30, 2016.  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. The market price for natural gas in the Appalachian Basin continues to be lower relative to NYMEX Henry Hub as a result of the significant increases in the supply of natural gas in the Northeast region in recent years. 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 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 NGL prices could adversely affect, among other things, the Company’s development plans, which could 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 a material non-cash impairment in the recorded value of the Company’s property, plant and equipment.

In addition to the ability to elect to slow capital spending in periods of prolonged low, and/or significant declines in, natural gas and NGL prices, the Company uses derivatives to reduce the effects of commodity price volatility. The Company’s use of derivatives is further described in Note G 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 and collar 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.

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 624 Bcf of natural gas and 913 Mbbls of NGLs as of September 30, 2016, and 664 Bcf of natural gas as of December 31, 2015. See 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, 2016 and December 31, 2015 levels would have increased the fair value of natural gas derivative instruments by approximately $146.3 million and $137.1 million, respectively. A hypothetical increase of 10% in the market price of natural gas from the September 30, 2016 and December 31, 2015 levels would have decreased the fair value of natural gas derivative instruments by approximately $148.4 million and $138.4 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 H to the Condensed Consolidated Financial Statements. The Company assumed a 10% change in the price of natural gas from its levels at September 30, 2016 and December 31, 2015. The price change was then applied to the natural gas derivative commodity instruments recorded on the Company’s Condensed 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

42


be offset by a favorable impact on the Company’s physical sales of natural gas, assuming the derivative commodity instruments are not closed out in advance of their expected term, the derivative commodity instruments continue to function effectively as hedges of the underlying risk, the anticipated transactions occur as expected and basis does not significantly change.

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. All of the Company’s and EQM’s long-term borrowings 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 J to the Condensed Consolidated Financial Statements for further discussion of the Company’s and EQM’s revolving credit facilities and Note H 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 or better, enters into netting agreements whenever possible and may obtain collateral or other security.

Approximately 66%, or $134.7 million, of the Company’s OTC derivative contracts outstanding at September 30, 2016 had a positive fair value. Approximately 95%, or $417.4 million, of the Company’s OTC derivative contracts outstanding at December 31, 2015 had a positive fair value.

As of September 30, 2016, 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 of EQT Production 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 the Northeastern United States as well as the Permian Basin of Texas and a gas processor in Kentucky and West Virginia. Additionally, a significant amount of revenues and related accounts receivable of EQT Midstream are generated from the transmission and gathering of natural gas in Kentucky, Virginia, Pennsylvania and West Virginia.

The Company has a $1.5 billion revolving credit facility that expires in February 2019. The credit facility is underwritten by a syndicate of financial institutions, each of which is obligated to fund its pro-rata portion of any borrowings by the Company. As of September 30, 2016, the Company had no borrowings or letters of credit outstanding under the facility. No one lender of the large group of financial institutions in the syndicate holds more than 10% of the facility. The Company’s large syndicate group and relatively low percentage of participation by each lender is expected to limit the Company’s exposure to problems or consolidation in the banking industry.

EQM has a $750 million revolving credit facility that expires in February 2019. The credit facility is underwritten by a syndicate of financial institutions, each of which is obligated to fund its pro-rata portion of any borrowings by EQM. As of September 30, 2016, EQM had $91.0 million in borrowings and no letters of credit outstanding under the credit facility. No one lender of the large group of financial institutions in the syndicate holds more than 10% of the facility. EQM’s large syndicate group and relatively low percentage of participation by each lender is expected to limit EQM’s exposure to problems 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
 
There were no changes in internal control over financial reporting (as such term is defined in Rule 13a-15(f) under the Exchange Act) that occurred during the third quarter of 2016 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.

Item 1A. Risk Factors
 
Information regarding risk factors is discussed in Item 1A, “Risk Factors” of the Company’s Annual Report on Form 10-K for the year ended December 31, 2015. There have been no material changes from the risk factors previously disclosed in the Company’s Form 10-K.

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, 2016:
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
 
Maximum number
of shares that may
yet be purchased
under the plans or
programs (b)
July 2016  (July 1 – July 31)
 

 
$

 

 
700,000

August 2016  (August 1 – August 31)
 
4,668

 
68.26

 

 
700,000

September 2016 (September 1 – September 30)
 
316

 
73.65

 

 
700,000

Total
 
4,984

 
$
68.60

 

 


 
(a)
Reflects shares withheld by the Company to pay taxes upon vesting of restricted stock.

(b)
During 2014, the Company’s Board of Directors approved a share repurchase authorization of up to 1,000,000 shares of the Company’s outstanding common stock.  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, 2016, the Company had repurchased 300,000 shares under this authorization since its inception.


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Item 6.  Exhibits
 
31.01

Rule 13(a)-14(a) Certification of Principal Executive Officer
 
 
31.02

Rule 13(a)-14(a) Certification of Principal Financial Officer
 
 
32

Section 1350 Certification of Principal Executive Officer and Principal Financial Officer
 
 
101

Interactive Data File


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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 27, 2016


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INDEX TO EXHIBITS
 
Exhibit No.
 
Description
 
Method of Filing
 
 
 
 
 
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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