Table of Contents

 

 

 

 

UNITED STATES
SECURITIES AND EXCHANGE COMMISSION

 

Washington, D.C. 20549

 


 

FORM 10-Q

 

(Mark One)

 

ý

QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934

 

 

 

FOR THE QUARTERLY PERIOD ENDED JUNE 30, 2014

 

or

 

o

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  ý  No  o

 

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 ý  No o

 

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  ý

 

Accelerated Filer                 o

 

 

 

Non-Accelerated Filer    o

 

Smaller reporting company o

 

Indicate by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the Exchange Act).  Yes o  No ý

 

As of June 30, 2014, 151,502 (in thousands) shares of common stock, no par value, of the registrant were outstanding.

 



Table of Contents

 

EQT CORPORATION AND SUBSIDIARIES

 

Index

 

 

 

Page No.

 

 

 

Part I.      Financial Information:

 

 

 

 

Item 1.

Financial Statements (Unaudited):

 

 

 

 

 

Statements of Consolidated Income for the Three and Six Months Ended June 30, 2014 and 2013

3

 

 

 

 

Statements of Consolidated Comprehensive Income for the Three and Six Months Ended June 30, 2014 and 2013

4

 

 

 

 

Statements of Condensed Consolidated Cash Flows for the Six Months Ended June 30, 2014 and 2013

5

 

 

 

 

Condensed Consolidated Balance Sheets as of June 30, 2014 and December 31, 2013

6 – 7

 

 

 

 

Statements of Condensed Consolidated Equity for the Six Months Ended June 30, 2014 and 2013

8

 

 

 

 

Notes to Condensed Consolidated Financial Statements

9 – 21

 

 

 

Item 2.

Management’s Discussion and Analysis of Financial Condition and Results of Operations

22 – 36

 

 

 

Item 3.

Quantitative and Qualitative Disclosures About Market Risk

37 – 39

 

 

 

Item 4.

Controls and Procedures

39

 

 

 

Part II.     Other Information:

 

 

 

 

Item 1.

Legal Proceedings

40

 

 

 

Item 1A.

Risk Factors

40

 

 

 

Item 2.

Unregistered Sales of Equity Securities and Use of Proceeds

41

 

 

 

Item 6.

Exhibits

42

 

 

 

Signature

43

 

 

 

Index to Exhibits

44

 

2



Table of Contents

 

PART I.  FINANCIAL INFORMATION

 

Item 1. Financial Statements

 

EQT CORPORATION AND SUBSIDIARIES

 

Statements of Consolidated Income (Unaudited)

 

 

 

Three Months Ended

 

Six Months Ended

 

 

 

June 30,

 

June 30,

 

 

 

2014

 

2013

 

2014

 

2013

 

 

 

(Thousands, except per share amounts)

 

Operating revenues

 

$

526,168

 

$

473,093

 

$

1,187,793

 

$

888,976

 

 

 

 

 

 

 

 

 

 

 

Operating expenses:

 

 

 

 

 

 

 

 

 

Transportation and processing

 

51,723

 

35,866

 

96,898

 

72,597

 

Operation and maintenance

 

27,587

 

24,067

 

52,808

 

47,300

 

Production

 

31,882

 

27,747

 

63,822

 

52,636

 

Exploration

 

7,452

 

6,138

 

8,871

 

9,868

 

Selling, general and administrative

 

63,283

 

54,822

 

112,251

 

94,607

 

Depreciation, depletion and amortization

 

157,219

 

162,473

 

309,330

 

305,509

 

Total operating expenses

 

339,146

 

311,113

 

643,980

 

582,517

 

 

 

 

 

 

 

 

 

 

 

Gain on sale / exchange of assets

 

37,749

 

 

37,749

 

 

Operating income

 

224,771

 

161,980

 

581,562

 

306,459

 

Other income

 

2,579

 

2,041

 

5,130

 

4,322

 

Interest expense

 

31,873

 

37,384

 

63,841

 

75,136

 

Income before income taxes

 

195,477

 

126,637

 

522,851

 

235,645

 

Income taxes

 

59,089

 

38,078

 

175,424

 

72,846

 

Income from continuing operations

 

136,388

 

88,559

 

347,427

 

162,799

 

Income from discontinued operations, net of tax

 

1,876

 

5,559

 

1,772

 

40,600

 

Net income

 

138,264

 

94,118

 

349,199

 

203,399

 

Less: Net income attributable to noncontrolling interests

 

27,343

 

7,262

 

46,085

 

16,288

 

Net income attributable to EQT Corporation

 

$

110,921

 

$

86,856

 

$

303,114

 

$

187,111

 

 

 

 

 

 

 

 

 

 

 

Amounts attributable to EQT Corporation:

 

 

 

 

 

 

 

 

 

Income from continuing operations

 

$

109,045

 

$

81,297

 

$

301,342

 

$

146,511

 

Income from discontinued operations

 

1,876

 

5,559

 

1,772

 

40,600

 

Net income

 

$

110,921

 

$

86,856

 

$

303,114

 

$

187,111

 

 

 

 

 

 

 

 

 

 

 

Earnings per share of common stock attributable to EQT Corporation:

 

 

 

 

 

 

 

 

 

Basic:

 

 

 

 

 

 

 

 

 

Weighted average common stock outstanding

 

151,744

 

150,525

 

151,522

 

150,425

 

Income from continuing operations

 

$

0.72

 

$

0.54

 

$

1.99

 

$

0.97

 

Income from discontinued operations

 

0.01

 

0.04

 

0.01

 

0.27

 

Net income

 

$

0.73

 

$

0.58

 

$

2.00

 

$

1.24

 

Diluted:

 

 

 

 

 

 

 

 

 

Weighted average common stock outstanding

 

152,570

 

151,393

 

152,537

 

151,191

 

Income from continuing operations

 

$

0.72

 

$

0.54

 

$

1.98

 

$

0.97

 

Income from discontinued operations

 

0.01

 

0.03

 

0.01

 

0.27

 

Net income

 

$

0.73

 

$

0.57

 

$

1.99

 

$

1.24

 

Dividends declared per common share

 

$

0.03

 

$

0.03

 

$

0.06

 

$

0.06

 

 

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

 

3



Table of Contents

 

EQT CORPORATION AND SUBSIDIARIES

 

Statements of Consolidated Comprehensive Income (Unaudited)

 

 

 

Three Months Ended

 

Six Months Ended

 

 

 

June 30,

 

June 30,

 

 

 

2014

 

2013

 

2014

 

2013

 

 

 

(Thousands)

 

 

 

 

 

 

 

 

 

 

 

Net income

 

$

138,264

 

$

94,118

 

$

349,199

 

$

203,399

 

 

 

 

 

 

 

 

 

 

 

Other comprehensive (loss) income, net of tax:

 

 

 

 

 

 

 

 

 

Net change in cash flow hedges:

 

 

 

 

 

 

 

 

 

Natural gas, net of tax (benefit) expense of $(12,984), $41,436, $(27,880) and $(10,147)

 

(19,307)

 

62,939

 

(41,238)

 

(15,495)

 

Interest rate, net of tax expense of $25, $25, $50 and $50

 

36

 

36

 

72

 

72

 

Pension and other post-retirement benefits liability adjustment, net of tax expense of $113, $306, $227 and $613

 

176

 

436

 

352

 

869

 

Other comprehensive (loss) income

 

(19,095)

 

63,411

 

(40,814)

 

(14,554)

 

Comprehensive income

 

119,169

 

157,529

 

308,385

 

188,845

 

Less: Comprehensive income attributable to noncontrolling interests

 

27,343

 

7,262

 

46,085

 

16,288

 

Comprehensive income attributable to EQT Corporation

 

$

91,826

 

$

150,267

 

$

262,300

 

$

172,557

 

 

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

 

4



Table of Contents

 

EQT CORPORATION AND SUBSIDIARIES

 

Statements of Condensed Consolidated Cash Flows (Unaudited)

 

 

 

Six Months Ended

 

 

June 30,

 

 

2014

 

 

2013

 

 

(Thousands)     

Cash flows from operating activities:

 

 

 

 

Net income

 

  $

349,199

 

  $

203,399

Adjustments to reconcile net income to net cash provided by operating activities:

 

 

 

 

Deferred income taxes

 

54,577

 

63,252

Depreciation, depletion, and amortization

 

309,330

 

317,693

Gain on sale / exchange of assets

 

(37,749)

 

Gain on dispositions

 

(3,598)

 

Provision for losses on accounts receivable

 

919

 

2,246

Other income

 

(5,130)

 

(4,441)

Stock-based compensation expense

 

20,810

 

27,480

Loss recognized in operating revenues for hedging ineffectiveness

 

21,273

 

7,954

Loss (gain) on derivatives not designated as hedges

 

17,879

 

(1,250)

Cash settlements on derivatives not designated as hedges

 

(10,836)

 

372

Lease impairment

 

6,519

 

8,133

Changes in other assets and liabilities:

 

 

 

 

Dividend from Nora Gathering, LLC

 

9,463

 

4,500

Excess tax benefits on stock-based compensation

 

(28,497)

 

Accounts receivable and unbilled revenues

 

(443)

 

(11,093)

Inventory

 

6,267

 

23,952

Accounts payable

 

50,952

 

(18,005)

Other items, net

 

33,712

 

(27,232)

Net cash provided by operating activities

 

794,647

 

596,960

 

 

 

 

 

Cash flows from investing activities:

 

 

 

 

Capital expenditures from continuing operations

 

(1,023,747)

 

(777,990)

Capital expenditures associated with Range asset exchange

 

(157,256)

 

Capital expenditures from discontinued operations

 

 

(15,163)

Restricted cash, net

 

(342,744)

 

Proceeds from sale of assets

 

7,444

 

Net cash used in investing activities

 

(1,516,303)

 

(793,153)

 

 

 

 

 

Cash flows from financing activities:

 

 

 

 

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

 

902,451

 

Increase in short-term loans

 

450,000

 

185,500

Decrease in short-term loans

 

(120,000)

 

(130,500)

Dividends paid

 

(9,101)

 

(9,038)

Distributions to noncontrolling interests

 

(25,674)

 

(10,350)

Repayments and retirements of long-term debt

 

(3,169)

 

(20,161)

Proceeds and tax benefits from exercises under employee compensation plans

 

42,042

 

15,387

Cash paid for taxes related to net settlement of share-based payment awards

 

(48,826)

 

Revolving credit facility origination fees

 

(5,075)

 

Repurchase and retirement of common stock

 

(32,368)

 

Net cash provided by financing activities

 

1,150,280

 

30,838

 

 

 

 

 

Net change in cash and cash equivalents

 

428,624

 

(165,355)

Cash and cash equivalents at beginning of period

 

845,641

 

182,055

Cash and cash equivalents at end of period

 

  $

1,274,265

 

  $

16,700

 

 

 

 

 

Cash paid during the period for:

 

 

 

 

Interest, net of amount capitalized

 

  $

62,519

 

  $

75,281

Income taxes, net

 

  $

89,050

 

  $

25,061

 

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

 

5



Table of Contents

 

EQT CORPORATION AND SUBSIDIARIES

 

Condensed Consolidated Balance Sheets (Unaudited)

 

 

 

June 30,

 

December 31,

 

 

 

2014

 

2013

 

 

 

(Thousands)

 

Assets

 

 

 

 

 

 

 

 

 

 

 

Current assets:

 

 

 

 

 

Cash and cash equivalents

 

  $

1,274,265

 

  $

845,641

 

Restricted cash

 

342,744

 

 

Accounts receivable (less accumulated provision for doubtful accounts: $6,139 at June 30, 2014 and $5,171 at December 31, 2013)

 

235,306

 

235,781

 

Inventory

 

13,389

 

19,656

 

Derivative instruments, at fair value

 

66,408

 

107,647

 

Prepaid expenses and other

 

32,065

 

46,700

 

Total current assets

 

1,964,177

 

1,255,425

 

 

 

 

 

 

 

Equity in nonconsolidated investments

 

 

128,983

 

 

 

 

 

 

 

Property, plant and equipment

 

12,372,135

 

11,062,136

 

Less: accumulated depreciation and depletion

 

3,024,600

 

2,728,374

 

Net property, plant and equipment

 

9,347,535

 

8,333,762

 

 

 

 

 

 

 

Other assets

 

74,224

 

73,883

 

Total assets

 

  $

11,385,936

 

  $

9,792,053

 

 

 

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

 

6



Table of Contents

 

EQT CORPORATION AND SUBSIDIARIES

 

Condensed Consolidated Balance Sheets (Unaudited)

 

 

 

June 30,

 

December 31,

 

 

2014

 

2013

 

 

(Thousands)

 

 

 

 

 

Liabilities and Stockholders’ Equity

 

 

 

 

 

 

 

 

 

Current liabilities:

 

 

 

 

Current portion of long-term debt

 

$

11,086

 

$

11,162

Short-term loans

 

330,000

 

Accounts payable

 

381,280

 

330,329

Derivative instruments, at fair value

 

58,116

 

29,651

Other current liabilities

 

168,483

 

152,268

Total current liabilities

 

948,965

 

523,410

 

 

 

 

 

Long-term debt

 

2,486,533

 

2,490,354

Deferred income taxes

 

1,654,506

 

1,655,765

Other liabilities and credits

 

265,999

 

258,396

Total liabilities

 

5,356,003

 

4,927,925

 

 

 

 

 

Equity:

 

 

 

 

Stockholders’ equity:

 

 

 

 

Common stock, no par value, authorized 320,000 shares, shares issued: 175,384 at June 30, 2014 and 175,684 at December 31, 2013

 

1,861,468

 

1,869,843

Treasury stock, shares at cost: 23,882 at June 30, 2014 and 24,800 at December 31, 2013

 

(431,149)

 

(447,738)

Retained earnings

 

2,842,384

 

2,567,980

Accumulated other comprehensive income

 

3,889

 

44,703

Total common stockholders’ equity

 

4,276,592

 

4,034,788

Noncontrolling interests in consolidated subsidiaries

 

1,753,341

 

829,340

Total equity

 

6,029,933

 

4,864,128

Total liabilities and equity

 

$

11,385,936

 

$

9,792,053

 

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

 

7



Table of Contents

 

EQT CORPORATION AND SUBSIDIARIES

 

Statements of Condensed Consolidated Equity (Unaudited)

 

 

 

Common Stock

 

 

 

Accumulated
Other

 

Noncontrolling
Interests in

 

 

 

 

Shares
Outstanding

 

No
Par Value

 

Retained
Earnings

 

Comprehensive
Income

 

Consolidated
Subsidiaries

 

Total
Equity

 

 

(Thousands)

 

 

 

 

 

 

 

 

 

 

 

 

 

Balance, January 1, 2013

 

150,109

 

$

1,308,771

 

$

2,195,502

 

  $

99,547

 

   $

284,982

 

$

3,888,802

Net income

 

 

 

 

 

187,111

 

 

 

16,288

 

203,399

Other comprehensive loss

 

 

 

 

 

 

 

(14,554)

 

 

 

(14,554)

Dividends ($0.06 per share)

 

 

 

 

 

(9,038)

 

 

 

 

 

(9,038)

Stock-based compensation plans, net

 

485

 

43,737

 

 

 

 

 

229

 

43,966

Distributions to noncontrolling interests ($0.72 per common unit)

 

 

 

 

 

 

 

 

 

(10,350)

 

(10,350)

Balance, June 30, 2013

 

150,594

 

$

1,352,508

 

$

2,373,575

 

  $

84,993

 

   $

291,149

 

$

4,102,225

 

 

 

 

 

 

 

 

 

 

 

 

 

Balance, January 1, 2014

 

150,884

 

$

1,422,105

 

$

2,567,980

 

  $

44,703

 

   $

829,340

 

$

4,864,128

Net income

 

 

 

 

 

303,114

 

 

 

46,085

 

349,199

Other comprehensive loss

 

 

 

 

 

 

 

(40,814)

 

 

 

(40,814)

Dividends ($0.06 per share)

 

 

 

 

 

(9,101)

 

 

 

 

 

(9,101)

Stock-based compensation plans, net

 

918

 

20,973

 

 

 

 

 

1,139

 

22,112

Distributions to noncontrolling interests ($0.95 per common unit)

 

 

 

 

 

 

 

 

 

(25,674)

 

(25,674)

Issuance of common units of EQT Midstream Partners, LP

 

 

 

 

 

 

 

 

 

902,451

 

902,451

Repurchase and retirement of common stock

 

(300)

 

(12,759)

 

(19,609)

 

 

 

 

 

(32,368)

Balance, June 30, 2014

 

151,502

 

$

1,430,319

 

$

2,842,384

 

  $

3,889

 

   $

1,753,341

 

$

6,029,933

 

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

 

8



Table of Contents

 

EQT Corporation and Subsidiaries

Notes to 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 June 30, 2014 and December 31, 2013, the results of its operations for the three and six month periods ended June 30, 2014 and 2013 and its cash flows for the six month periods ended June 30, 2014 and 2013.  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. Additionally, financial statements and notes to the financial statements previously reported in prior periods have been recast to reflect the presentation of discontinued operations as a result of the Equitable Gas Transaction. Refer to Note B for additional information regarding discontinued operations.

 

The balance sheet at December 31, 2013 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.

 

For further information, refer to the consolidated financial statements and footnotes thereto included in EQT Corporation’s Annual Report on Form 10-K for the year ended December 31, 2013 as well as “Management’s Discussion and Analysis of Financial Condition and Results of Operations” beginning on page 22 of this Quarterly Report on Form 10-Q.

 

B.                        Discontinued Operations

 

On December 17, 2013, the Company and its wholly-owned subsidiary Distribution Holdco, LLC (Holdco) completed the disposition of their ownership interests in Equitable Gas Company, LLC (Equitable Gas) and Equitable Homeworks, LLC (Homeworks) to PNG Companies LLC (the Equitable Gas Transaction). Equitable Gas and Homeworks comprised substantially all of the Company’s previously reported Distribution segment.  The financial information of Equitable Gas and Homeworks is reflected as discontinued operations for all periods presented in these financial statements.  Prior periods have been recast to reflect this presentation.

 

During the second quarter of 2014, the Company received additional cash proceeds of $7.4 million as a result of post-closing purchase price adjustments for the Equitable Gas Transaction. The Company recognized an additional gain of $3.6 million for the three and six months ended June 30, 2014, included in income from discontinued operations, net of tax, in the Statements of Consolidated Income. As consideration for the Equitable Gas Transaction, the Company received total cash proceeds of $748.0 million, select midstream assets (including the Allegheny Valley Connector) with a fair value of $140.3 million and other contractual assets with a fair value of $32.5 million.

 

The following table summarizes the components of discontinued operations activity:

 

 

 

Three Months Ended

 

Six Months Ended

 

 

 

June 30,

 

June 30,

 

 

 

2014

 

2013

 

2014

 

2013

 

 

 

(Thousands)  

 

 

 

 

 

Operating revenues

 

  $

 

  $

56,573

 

  $

 

  $

210,619

 

 

 

 

 

 

 

 

 

 

 

Income from discontinued operations before income taxes

 

3,258

 

9,384

 

3,077

 

63,590

 

Income tax expense

 

1,382

 

3,825

 

1,305

 

22,990

 

Income from discontinued operations, net of tax

 

  $

1,876

 

  $

5,559

 

  $

1,772

 

  $

40,600

 

 

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Table of Contents

 

EQT Corporation and Subsidiaries

Notes to Condensed Consolidated Financial Statements (Unaudited)

 

C.                        EQT Midstream Partners, LP

 

In 2012, the Company formed EQT Midstream Partners, LP (the Partnership) (NYSE: EQM) to own, operate, acquire and develop midstream assets in the Appalachian Basin. The Partnership provides midstream services to the Company and other third parties. The Partnership is consolidated in the Company’s consolidated financial statements. The Company records the noncontrolling interest of the public limited partners in its financial statements.

 

On May 7, 2014, a wholly-owned subsidiary of the Company contributed the Jupiter gathering system to EQM Gathering Opco, LLC (EQM Gathering), a wholly-owned subsidiary of the Partnership (the Jupiter Transaction) in exchange for $1.18 billion.  EQM Gathering is consolidated by the Company as it is still controlled by the Company.

 

On May 7, 2014, the Partnership completed an underwritten public offering of 12,362,500 common units, which included the full exercise of the underwriters’ overallotment option, representing Partnership limited partner interests. The Partnership received net proceeds of approximately $902.5 million from the offering, after deducting the underwriters’ discount and offering expenses of approximately $34 million. As of June 30, 2014, the Company held a 2% general partner interest, all incentive distribution rights and a 34.4% limited partner interest in the Partnership. The Company’s limited partner interest in the Partnership consists of 3,959,952 common units and 17,339,718 subordinated units.

 

While the Company did not record a gain for accounting purposes as a result of the Jupiter Transaction, the Company recognized a taxable gain for federal income tax purposes of approximately $569.3 million in 2014. In conjunction with the Jupiter Transaction, $500.0 million of the proceeds received were placed into a qualified trust account pursuant to a deferred exchange agreement, which allows for the use of the funds in a potential like-kind exchange for certain identified assets.  The Company utilized $157.3 million of these funds in connection with the exchange of certain assets with Range Resources Corporation (see Note K) and is evaluating the potential purchase of other eligible replacement properties within the statutory time period, which expires November 3, 2014.  As of June 30, 2014, the Company had restricted cash of $342.7 million in its Condensed Consolidated Balance Sheets.

 

D.                        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, and development and production of, natural gas, natural gas liquids (NGLs) and a limited amount of crude oil in the Appalachian and Permian Basins.  The EQT Midstream segment’s operations include the natural gas gathering, transportation, storage and marketing activities of the Company, including ownership and operation of the Partnership.

 

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.

 

The Company’s management reviews and reports the EQT Production segment results with third-party transportation and processing costs reflected as a deduction from operating revenues. Third-party costs incurred to gather, process and transport gas produced by EQT Production to market sales points are recorded as a portion of transportation and processing costs in the Statements of Consolidated Income. Some transportation costs incurred by the Company are marketed for resale and are not incurred to transport gas produced by EQT Production.  These transportation costs are reflected as a deduction from operating revenues.

 

Substantially all of the Company’s operating revenues, income from operations and assets are generated or located in the United States.

 

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EQT Corporation and Subsidiaries

Notes to Condensed Consolidated Financial Statements (Unaudited)

 

 

 

Three Months Ended

 

Six Months Ended

 

 

 

June 30,

 

June 30,

 

 

 

2014

 

2013

 

2014

 

2013

 

 

 

(Thousands)

Revenues from external customers:

 

 

 

 

 

 

 

 

 

EQT Production

 

  $

322,100

 

  $

306,132

 

  $

789,845

 

  $

556,643

 

EQT Midstream

 

162,345

 

150,366

 

328,571

 

297,054

 

Third-party transportation and processing costs (a)

 

51,432

 

34,827

 

96,061

 

70,568

 

Less intersegment revenues, net (b)

 

(9,709)

 

(18,232)

 

(26,684)

 

(35,289)

 

Total

 

  $

526,168

 

  $

473,093

 

  $

1,187,793

 

  $

888,976

 

 

 

 

 

 

 

 

 

 

 

Operating income:

 

 

 

 

 

 

 

 

 

EQT Production (c) 

 

  $

144,689

 

  $

105,056

 

  $

421,894

 

  $

179,153

 

EQT Midstream (c)

 

88,527

 

72,246

 

171,596

 

146,460

 

Unallocated expenses (d)

 

(8,445)

 

(15,322)

 

(11,928)

 

(19,154)

 

Total operating income

 

  $

224,771

 

  $

161,980

 

  $

581,562

 

  $

306,459

 

 

Reconciliation of operating income to income from continuing operations:

 

Other income

 

  $

2,579

 

  $

2,041

 

  $

5,130

 

  $

4,322

 

Interest expense

 

31,873

 

37,384

 

63,841

 

75,136

 

Income taxes

 

59,089

 

38,078

 

175,424

 

72,846

 

Income from continuing operations

 

  $

136,388

 

  $

88,559

 

  $

347,427

 

  $

162,799

 

 

 

 

As of
June 30,
2014

 

As of
December 31,
2013

 

 

 

(Thousands)

 

Segment assets:

 

 

 

 

 

EQT Production

 

  $

7,191,308

 

  $

6,359,065

 

EQT Midstream

 

2,486,643

 

2,514,429

 

Total operating segments

 

9,677,951

 

8,873,494

 

Headquarters assets, including cash and short-term investments

 

1,707,985

 

918,559

 

Total assets

 

  $

11,385,936

 

  $

9,792,053

 

 

(a)

 

This amount reflects the reclassification of third-party transportation and processing costs from operating revenues to transportation and processing costs at the consolidated level.

 

 

 

(b)

 

Includes entries to eliminate intercompany natural gas sales from EQT Production to EQT Midstream. The Company also had $9.1 million and $20.0 million for the three and six months ended June 30, 2013, respectively, of intercompany eliminations for transmission and storage services between EQT Midstream and the Company’s previously reported Distribution segment that were recast to discontinued operations as a result of the Equitable Gas Transaction. These recast adjustments had no impact on the Company’s net income for either of the three or six month periods ended June 30, 2013.

 

 

 

(c)

 

Gains on sales / exchanges of assets of $31.0 million and $6.8 million are included in EQT Production and EQT Midstream operating income, respectively, for the three and six months ended June 30, 2014.

 

 

 

(d)

 

Unallocated expenses consist primarily of incentive compensation expense, administrative costs and, for the three and six months ended June 30, 2013, corporate overhead charges previously allocated to the Distribution segment that were reclassified to Headquarters as part of the recast of the 2013 financial information in this Quarterly Report on Form 10-Q.

 

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EQT Corporation and Subsidiaries

Notes to Condensed Consolidated Financial Statements (Unaudited)

 

 

 

Three Months Ended

 

Six Months Ended

 

 

June 30,

 

June 30,

 

 

2014

 

2013

 

2014

 

2013

 

 

(Thousands)

Depreciation, depletion and amortization:

 

 

 

 

 

 

 

 

 

EQT Production

 

$

136,251

 

$

144,073

 

$

267,490

 

$

268,982

 

EQT Midstream

 

21,130

 

18,452

 

42,139

 

36,671

 

Other

 

(162)

 

(52)

 

(299)

 

(144)

 

Total

 

$

157,219

 

$

162,473

 

$

309,330

 

$

305,509

 

 

 

 

 

 

 

 

 

 

 

Expenditures for segment assets (e):

 

 

 

 

 

 

 

 

 

EQT Production (f)

 

$

930,228

 

$

394,391

 

$

1,338,559

 

$

637,566

 

EQT Midstream

 

110,913

 

89,060

 

194,126

 

138,204

 

Other

 

802

 

1,872

 

1,362

 

2,220

 

Total

 

$

1,041,943

 

$

485,323

 

$

1,534,047

 

$

777,990

 

 

(e)          Excludes non-cash capital expenditures of $3.6 million and $5.9 million for the three months ended June 30, 2014 and 2013, respectively, and $8.1 million and $11.9 million for the six months ended June 30, 2014 and 2013, respectively.  The Company capitalizes certain labor overhead costs including a portion of non-cash stock-based compensation expense.

 

(f)           Includes $157.3 million of cash capital expenditures and $353.0 million of non-cash capital expenditures for the exchange of assets with Range Resources Corporation (described in Note K) for the three and six months ended June 30, 2014. Expenditures for segment assets in the EQT Production segment include $550.5 million and $128.9 million for property acquisitions during the three months ended June 30, 2014 and 2013, respectively, and $609.7 million and $141.6 million for property acquisitions during the six months ended June 30, 2014 and 2013, respectively.

 

E.                        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 and the storage, marketing and other activities at EQT Midstream. 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 that are primarily placed with financial institutions, and the creditworthiness of these institutions is regularly monitored. The Company also uses exchange traded futures contracts that obligate the Company to buy or sell a designated commodity at a future date for a specified price and quantity at a specified location. 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 may also engage in a limited number of 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 assets and liabilities are reported in the Condensed Consolidated Balance Sheets as derivative instruments at fair value. 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 has been designated and qualifies 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 Income in the same period or periods during which the forecasted transaction affects earnings.  In conjunction with the exchange of assets with Range Resources Corporation that closed on June 16, 2014 (see Note K), the Company de-designated certain derivative instruments that were previously designated as cash flow hedges because it was probable that the forecasted transactions would not occur, resulting in a pre-tax gain of $28.0 million

 

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EQT Corporation and Subsidiaries

Notes to Condensed Consolidated Financial Statements (Unaudited)

 

recorded within gain on sale / exchange of assets in the Statements of Consolidated Income for the three and six months ended June 30, 2014.  Any subsequent changes in fair value of these derivative instruments are recognized within operating revenues in the Statements of Consolidated Income each period.

 

For a derivative instrument designated and qualified as a fair value hedge, the change in the fair value of the instrument is recognized as a portion of operating revenues in the Statements of Consolidated Income each period.  In addition, the change in the fair value of the hedged item (natural gas inventory) was recognized as a portion of operating revenues in the Statements of Consolidated Income. The Company elected to exclude the spot/forward differential for the assessment of effectiveness of the fair value hedges.

 

Most of the 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 equity production have been designated and qualify as cash flow hedges. Historically, some of the derivative commodity instruments used by the Company to hedge its exposure to adverse changes in the market price of natural gas stored in the ground were designated and qualified as fair value hedges. These positions were de-designated effective October 1, 2013. Basis swaps are not designated as cash flow hedges. Any hedging ineffectiveness and any change in fair value of derivative instruments that have not been designated as hedges are recognized in the Statements of Consolidated Income each period.

 

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.

 

Exchange-traded instruments are generally settled with offsetting positions. 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.

 

 

 

Three Months Ended

 

Six Months Ended

 

 

 

June 30,

 

June 30,

 

 

 

2014

 

2013

 

2014

 

2013

 

 

 

(Thousands)

Commodity derivatives designated as cash flow hedges

 

 

 

 

 

 

 

 

 

Amount of (loss) gain recognized in OCI (effective portion), net of tax

 

$

(13,455)

 

$

73,429

 

$

(52,649)

 

$

20,828

 

Amount of gain reclassified from accumulated OCI, net of tax, into gain on sale / exchange of assets due to forecasted transactions probable to not occur

 

16,735

 

 

16,735

 

 

Amount of (loss) gain reclassified from accumulated OCI into operating revenues (effective portion), net of tax

 

(10,883)

 

10,490

 

(28,146)

 

36,323

 

Amount of gain (loss) recognized in operating revenues (ineffective portion) (a)

 

987

 

(7,473)

 

(21,273)

 

(7,954)

 

 

 

 

 

 

 

 

 

 

 

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

 

$

72

 

$

72

 

 

 

 

 

 

 

 

 

 

 

Commodity derivatives designated as fair value hedges (b)

 

 

 

 

 

 

 

 

 

 

Amount of gain (loss) recognized in operating revenues for fair value commodity contracts

 

$

 

$

2,700

 

$

 

$

(839)

 

Fair value (loss) gain recognized in operating revenues for inventory designated as hedged item

 

 

(4,075)

 

 

 

462

 

 

 

 

 

 

 

 

 

 

 

Derivatives not designated as hedging instruments

 

 

 

 

 

 

 

 

 

Amount of (loss) gain recognized in operating revenues

 

$

(8,525)

 

$

1,512

 

$

(17,879)

 

$

1,250

 

 

(a)         No amounts have been excluded from effectiveness testing of cash flow hedges.

 

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EQT Corporation and Subsidiaries

Notes to Condensed Consolidated Financial Statements (Unaudited)

 

(b)         For the three months ended June 30, 2013, the net impact on operating revenues consisted of a $0.8 million gain due to the exclusion of the spot/forward differential from the assessment of effectiveness of the fair value hedges and a $2.2 million loss due to changes in basis. For the six months ended June 30, 2013, the net impact on operating revenues consisted of a $2.1 million gain due to the exclusion of the spot/forward differential from the assessment of effectiveness of the fair value hedges and a $2.5 million loss due to changes in basis.

 

 

 

As of
June 30,

 

As of
December 31,

 

 

 

2014

 

2013

 

 

 

(Thousands)  

 

Asset derivatives

 

 

 

 

 

Commodity derivatives designated as hedging instruments

 

$

33,942

 

$

104,430

 

Commodity derivatives not designated as hedging instruments

 

32,466

 

3,217

 

Total asset derivatives

 

$

66,408

 

$

107,647

 

 

 

 

 

 

 

Liability derivatives

 

 

 

 

 

Commodity derivatives designated as hedging instruments

 

$

47,713

 

$

27,618

 

Commodity derivatives not designated as hedging instruments

 

10,403

 

2,033

 

Total liability derivatives

 

$

58,116

 

$

29,651

 

 

The net fair value of derivative commodity instruments changed during the first half of 2014 primarily as a result of increased New York Mercantile Exchange (NYMEX) forward prices and settlements.  The absolute quantities of the Company’s derivative commodity instruments that have been designated and qualify as cash flow hedges totaled 307 Bcf and 398 Bcf as of June 30, 2014 and December 31, 2013, respectively, and are primarily related to natural gas swaps and collars. The open positions at June 30, 2014 and December 31, 2013 had maturities extending through December 2018 and December 2017, respectively.

 

The Company deferred net gains of $20.5 million and $61.7 million in accumulated OCI, net of tax, as of June 30, 2014 and December 31, 2013, respectively, associated with the effective portion of the change in fair value of its derivative commodity instruments designated as cash flow hedges. Assuming no change in price or new transactions, the Company estimates that approximately $8.5 million of net unrealized gains on its derivative commodity instruments reflected in accumulated OCI, net of tax, as of June 30, 2014 will be recognized in earnings during the next twelve months due to the settlement of hedged transactions.

 

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 believes that NYMEX traded futures contracts have limited credit risk because Commodity Futures Trading Commission regulations are in place to protect exchange participants, including the Company, from potential financial instability of the exchange members. The Company’s OTC swap and collar derivative instruments are primarily placed 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.

 

When the net fair value of any of the Company’s swap agreements represents a liability to the Company which is in excess of the agreed-upon threshold between the Company and the financial institution acting as counterparty, the counterparty requires the Company to remit funds to the counterparty as a margin deposit for the derivative liability which is in excess of the threshold amount.  The Company records these deposits as a current asset.  When the net fair value of any of the Company’s swap agreements represents an asset to the Company which is in excess of the agreed-upon threshold between the Company and the financial institution acting as counterparty, the Company requires the counterparty to remit funds as margin deposits in an amount equal to the portion of the derivative asset

 

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Table of Contents

 

EQT Corporation and Subsidiaries

Notes to Condensed Consolidated Financial Statements (Unaudited)

 

which is in excess of the threshold amount. The Company records a current liability for such amounts received.  The Company had no such deposits in its Condensed Consolidated Balance Sheets as of June 30, 2014 or December 31, 2013.

 

When the Company enters into exchange-traded natural gas contracts, exchanges may require the Company to remit funds to the corresponding broker as good-faith deposits to guard against the risks associated with changing market conditions.  The Company must make such deposits based on an established initial margin requirement as well as the net liability position, if any, of the fair value of the associated contracts.  The Company records these deposits as a current asset in the Condensed Consolidated Balance Sheets.  In the case where the fair value of such contracts is in a net asset position, the broker may remit funds to the Company, in which case the Company records a current liability for such amounts received. The initial margin requirements are established by the exchanges based on the price, volatility and the time to expiration of the related contract.  The margin requirements are subject to change at the exchanges’ discretion.  The Company recorded current assets of $0.1 million and $0.3 million as of June 30, 2014 and December 31, 2013, respectively, for such deposits in its Condensed Consolidated Balance Sheets.

 

The Company recognizes all derivative instruments as either assets or liabilities at fair value on a gross basis. Margin deposits remitted to financial counterparties or received from financial counterparties related to OTC natural gas swap agreements and options and any funds remitted to or deposits received from the Company’s brokers are recorded on a gross basis.  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 June 30, 2014 and December 31, 2013.

 

As of June 30, 2014

 

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

 

$

66,408

 

$

(26,331)

 

$

 

$

40,077

 

 

 

 

 

 

 

 

 

 

 

Liability derivatives:

 

 

 

 

 

 

 

 

 

Derivative instruments, at fair value

 

$

58,116

 

$

(26,331)

 

$

(103)

 

$

31,682

 

 

As of December 31, 2013

 

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

 

$

107,647

 

$

(20,843)

 

$

 

$

86,804

 

 

 

 

 

 

 

 

 

 

 

Liability derivatives:

 

 

 

 

 

 

 

 

 

Derivative instruments, at fair value

 

$

29,651

 

$

(20,843)

 

$

(266)

 

$

8,542

 

 

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 must be deposited with the counterparty.  The additional collateral can be up to 100% of the derivative liability.  As of June 30, 2014, the aggregate fair value of all derivative instruments with credit risk-related contingent features that were in a net liability position was $31.9 million, for which the Company had no collateral posted on June 30, 2014.  If the Company’s credit rating by S&P or Moody’s had been downgraded below investment grade on June 30, 2014, the Company would have been required to post $1.1 million of additional

 

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EQT Corporation and Subsidiaries

Notes to Condensed Consolidated Financial Statements (Unaudited)

 

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 June 30, 2014.  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.

 

F.            Fair Value Measurements

 

The Company records its financial instruments, principally derivative instruments, at fair value in its Condensed Consolidated Balance Sheets.  The Company has an established process for determining fair value which is based on quoted market prices, where available.  If quoted market prices are not available, fair value is based upon models that use as inputs market-based parameters, including but not limited to 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.  The Company also considers credit default swaps rates where applicable.

 

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 included in Level 1 include the Company’s futures contracts.  Assets and liabilities in Level 2 include the Company’s swap and collar agreements. As of December 31, 2013, the Company transferred $54.4 million of derivative instruments, primarily its collars, from Level 3 into Level 2.

 

The fair value of the assets and liabilities included in Level 2 is based on standard industry income approach models that use significant observable inputs, including NYMEX forward curves, LIBOR-based discount rates and basis forward curves.  The Company’s collars are valued using standard industry income approach models and were historically classified in Level 3 because the volatility assumption in the option pricing model was not observable over the full duration of the collars.  Effective December 31, 2013, the volatility assumption in the option pricing model is observable for the duration of the term of the collars outstanding. This change did not have a significant impact on the fair value of the derivative instruments previously included in Level 3. The significant observable inputs utilized by the option pricing model include NYMEX forward curves, natural gas volatilities and LIBOR-based discount rates.

 

The Company uses NYMEX forward curves to value futures, commodity swaps and collars. The NYMEX forward curves, LIBOR-based discount rates, natural gas volatilities and basis 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
June 30, 2014

 

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

 

$

66,408

 

$

123

 

$

66,285

 

$

 

 

 

 

 

 

 

 

 

 

 

Liabilities

 

 

 

 

 

 

 

 

 

Derivative instruments, at fair value

 

$

58,116

 

$

 

$

58,116

 

$

 

 

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Table of Contents

 

EQT Corporation and Subsidiaries

Notes to Condensed Consolidated Financial Statements (Unaudited)

 

 

 

 

 

Fair value measurements at reporting date using

Description

 

As of
December 31,
2013

 

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

 

  $

107,647

 

  $

240

 

  $

107,407

 

  $

 

 

 

 

 

 

 

 

 

 

 

Liabilities

 

 

 

 

 

 

 

 

 

Derivative instruments, at fair value

 

  $

29,651

 

  $

315

 

  $

29,336

 

  $

 

 

 

 

Fair value measurements using significant
unobservable inputs (Level 3)
Derivative instruments, at fair value, net

 

 

Three Months Ended
June 30,

 

Six Months Ended
June 30,

 

 

 

2014

 

2013

 

2014

 

2013

 

 

 

(Thousands)

Beginning of period

 

  $

 

$

69,865

 

  $

 

  $

90,714

 

Total gains or losses:

 

 

 

 

 

 

 

 

 

Included in earnings

 

 

(1,178)

 

 

(755)

 

Included in OCI

 

 

13,125

 

 

1,392

 

Purchases

 

 

 

 

72

 

Settlements

 

 

(7,124)

 

 

(16,735)

 

Transfers in and/or out of Level 3

 

 

 

 

 

End of period

 

  $

 

$

74,688

 

  $

 

  $

74,688

 

 

Losses of $1.2 million are included in earnings in the table above for the three and six months ended June 30, 2013, respectively, attributable to the change in unrealized gains or losses relating to assets held as of June 30, 2013.

 

The carrying value of cash equivalents approximates fair value due to the short maturity of the instruments; these are considered Level 1 fair values.

 

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 long-term debt on the Condensed Consolidated Balance Sheets at June 30, 2014 and December 31, 2013 was approximately $2.9 billion and $2.8 billion, respectively.

 

For information on the fair value of certain assets acquired from the exchange of properties with Range Resources Corporation, see Note K.

 

G.                       Income Taxes

 

The Company estimates an annual effective income tax rate based on projected results for the year and applies this rate to income before taxes to calculate income tax expense.  However, while all of the Partnership’s earnings are included in the Company’s net income, the Company is not required to record income tax expense with respect to the portion of the Partnership’s earnings allocated to its noncontrolling public limited partners, which reduces the Company’s effective tax rate.  Any refinements made due to subsequent information that affects the estimated annual effective income tax rate are reflected as adjustments in the current period.

 

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EQT Corporation and Subsidiaries

Notes to Condensed Consolidated Financial Statements (Unaudited)

 

The Company’s effective income tax rate for the six months ended June 30, 2014 was 33.6%, compared to 30.9% for the six months ended June 30, 2013.  The increase in the effective income tax rate from the first half of 2013 is primarily attributable to a reduction in a valuation allowance related to bonus depreciation for state tax purposes in 2013, increased state tax expense in 2014 due to higher natural gas prices and production sales volumes as well as increased tax reserves recorded in certain states in 2014, partially offset by the impact of the Partnership’s ownership structure.

 

There were no material changes to the Company’s methodology for determining unrecognized tax benefits during the three months ended June 30, 2014.  The Company believes that it is appropriately reserved for uncertain tax positions.

 

H.                       Revolving Credit Facilities

 

As of June 30, 2014 and December 31, 2013, the Company had no loans or letters of credit outstanding under its revolving credit facility. The Company did not have any short-term loans outstanding at any time during the three and six months ended June 30, 2014 under its revolving credit facility. The maximum amount of the Company’s outstanding short-term loans at any time was $178.5 million during the three and six months ended June 30, 2013. The average daily balance of short-term loans outstanding was approximately $26.7 million and $13.4 million during the three and six months ended June 30, 2013, respectively, at weighted average interest rates of 0.83% and 0.41%, respectively.

 

As of June 30, 2014, the Partnership had $330 million of loans and no letters of credit outstanding under its revolving credit facility. As of December 31, 2013, the Partnership had no loans or letters of credit outstanding under its revolving credit facility. The maximum amount of outstanding short-term loans at any time under the Partnership’s revolving credit facility was $450 million during the three and six months ended June 30, 2014. The average daily balance of short-term loans outstanding was approximately $252.2 million and $173.0 million during the three and six months ended June 30, 2014, respectively, at a weighted average annual interest rate of 1.66% and 1.68%, respectively. The Partnership had no short-term loans outstanding at any time during the three and six months ended June 30, 2013.

 

The Company incurred commitment fees averaging approximately 6 basis points for the three months ended June 30, 2014 and 2013, and 12 basis points and 11 basis points for the six months ended June 30, 2014 and 2013, respectively, to maintain credit availability under its revolving credit facility. The Partnership incurred commitment fees averaging approximately 6 basis points and 13 basis points for the three and six months ended June 30, 2014 and 2013, respectively, to maintain credit availability under its revolving credit facility.

 

I.                            Earnings Per Share

 

Potentially dilutive securities, consisting of options and restricted stock awards, which were included in the calculation of diluted earnings per share, totaled 825,907 and 867,373 for the three months ended June 30, 2014 and 2013, respectively, and 1,014,746 and 766,054 for the six months ended June 30, 2014 and 2013, respectively.  There were no options to purchase common stock which were excluded from potentially dilutive securities because they were anti-dilutive for the three and six months ended June 30, 2014 and 2013.  The impact of the Partnership’s dilutive units did not have a material impact on the Company’s earnings per share calculations for any of the periods presented.

 

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EQT Corporation and Subsidiaries

Notes to Condensed Consolidated Financial Statements (Unaudited)

 

J.         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 June 30, 2014

 

 

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 (loss), net
of tax

 

 

(Thousands)

Accumulated OCI (loss), net of tax, as of April 1, 2014

 

   $

39,768

 

   $

(1,096)

 

   $

(15,688)

 

   $

22,984

 

Losses recognized in accumulated OCI, net of tax

 

(13,455)

(a)

 

 

(13,455)

 

Gain reclassified from accumulated OCI, net of tax, into gain on sale / exchange of assets

 

(16,735)

(a)

 

 

(16,735)

 

Losses reclassified from accumulated OCI, net of tax

 

 

10,883

(a)

36

(a)

176

(b)

11,095

 

 

 

 

 

 

 

 

 

 

 

 

Change in accumulated other comprehensive (loss) income, net of tax

 

(19,307)

 

36

 

176

 

(19,095)

 

Accumulated OCI (loss), net of tax, as of June 30, 2014

 

   $

20,461

 

   $

(1,060)

 

   $

(15,512)

 

   $

3,889

 

 

 

 

 

 

 

 

 

 

 

 

 

Three Months Ended June 30, 2013

 

 

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 (loss), net
of tax

 

 

(Thousands)

Accumulated OCI (loss), net of tax, as of April 1, 2013

 

   $

59,754

 

   $

(1,240)

 

   $

(36,932)

 

   $

21,582

 

Gains recognized in accumulated OCI, net of tax

 

73,429

(a)

 

 

73,429

 

(Gains) losses reclassified from accumulated OCI, net of tax

 

 

(10,490)

(a)

36

(a)

436

(b)

(10,018)

 

 

 

 

 

 

 

 

 

 

 

 

Change in accumulated OCI, net of tax

 

62,939

 

36

 

436

 

63,411

 

Accumulated OCI (loss), net of tax, as of June 30, 2013

 

   $

122,693

 

   $

(1,204)

 

   $

(36,496)

 

   $

84,993

 

 

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Table of Contents

 

EQT Corporation and Subsidiaries

Notes to Condensed Consolidated Financial Statements (Unaudited)

 

 

 

Six Months Ended June 30, 2014

 

 

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 (loss), net
of tax

 

 

(Thousands)

Accumulated OCI (loss), net of tax, as of January 1, 2014

 

   $

61,699

 

   $

(1,132)

 

   $

(15,864)

 

   $

44,703

 

Losses recognized in accumulated OCI, net of tax

 

(52,649)

(a)

 

 

(52,649)

 

Gain reclassified from accumulated OCI, net of tax, into gain on sale / exchange of assets

 

(16,735)

(a)

 

 

(16,735)

 

Losses reclassified from accumulated OCI, net of tax

 

 

28,146

(a)

72

(a)

352

(b)

28,570

 

 

 

 

 

 

 

 

 

 

 

 

Change in accumulated other comprehensive (loss) income, net of tax

 

(41,238)

 

72

 

352

 

(40,814)

 

Accumulated OCI (loss), net of tax, as of June 30, 2014

 

   $

20,461

 

   $

(1,060)

 

   $

(15,512)

 

   $

3,889

 

 

 

 

 

 

 

 

 

 

 

 

 

Six Months Ended June 30, 2013

 

 

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 (loss), net
of tax

 

 

(Thousands)

Accumulated OCI (loss), net of tax, as of January 1, 2013

 

   $

138,188

 

   $

(1,276)

 

   $

(37,365)

 

   $

99,547

 

Gains recognized in accumulated OCI, net of tax

 

20,828

(a)

 

 

20,828

 

(Gains) losses reclassified from accumulated OCI, net of tax

 

 

(36,323)

(a)

72

(a)

869

(b)

(35,382)

 

 

 

 

 

 

 

 

 

 

 

 

Change in accumulated other comprehensive (loss) income, net of tax

 

(15,495)

 

72

 

869

 

(14,554)

 

Accumulated OCI (loss), net of tax, as of June 30, 2013

 

   $

122,693

 

   $

(1,204)

 

   $

(36,496)

 

   $

84,993

 

 

(a)         See Note E 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 13 to the Consolidated Financial Statements in the Company’s Annual Report on Form 10-K for the year ended December 31, 2013 for additional information.

 

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EQT Corporation and Subsidiaries

Notes to Condensed Consolidated Financial Statements (Unaudited)

 

K.        Sale and Exchange of Properties

 

In April 2014, the Company executed an agreement to exchange certain assets with Range Resources Corporation (Range).  The transaction closed on June 16, 2014.  The Company received approximately 73,000 net acres and approximately 900 producing wells, most of which are vertical wells, in the Permian Basin of Texas. In exchange, Range received  approximately 138,000 net acres in the Company’s Nora field of Virginia (Nora), the Company’s working interest in approximately 2,000 producing vertical wells in Nora, the Company’s remaining 50% ownership interest in Nora Gathering, LLC (Nora LLC), which owns the supporting gathering system in Nora, and $157.3 million in cash, subject to certain post-closing purchase price adjustments.  The Company previously recorded its 50% ownership interest in Nora LLC as a nonconsolidated investment in its consolidated financial statements. Portions of the exchange of assets with Range are intended to qualify as a tax free asset exchange.

 

The fair value of the assets exchanged by the Company was approximately $510.3 million. The Company is in the process of finalizing the allocation between the acquired acreage and the acquired wells. The Company recorded a pre-tax gain of $37.7 million, which is included in gain on sale / exchange of assets in the Statements of Consolidated Income. The gain on sale / exchange of assets includes a $28.0 million pre-tax gain related to the de-designation of certain derivative instruments that were previously designated as cash flow hedges because it was probable that the forecasted transactions would not occur.

 

As the asset exchange qualifies as a business combination under United States GAAP, the fair value of the acquired assets was determined using a discounted cash flow model under the market approach. Significant unobservable inputs used in the analysis included the determination of estimated developed reserves, NYMEX forward pricing and comparable sales transactions, which classify the acquired assets as a Level 3 measurement.

 

L.        Recently Issued Accounting Standards

 

In April 2014, the Financial Accounting Standards Board (FASB) issued an accounting standards update (ASU) that raised the threshold for a disposal to qualify as a discontinued operation and requires new disclosures for both discontinued operations and certain other material disposal transactions that do not meet the revised definition of a discontinued operation. Under the updated standard, a disposal of a component or group of components of an entity is required to be reported as discontinued operations if the disposal represents a strategic shift that has (or will have) a major effect on an entity’s operations and financial results when the component or group of components of the entity (1) has been disposed of by a sale, (2) has been disposed of other than by sale or (3) is classified as held for sale. This ASU is effective for annual periods beginning on or after December 15, 2014 and is applied prospectively. Early adoption is permitted but only for disposals (or classifications that are held for sale) that have not been reported in financial statements previously issued or available for use. The Company adopted this new standard in the second quarter of 2014. The sale of Nora LLC discussed in Note K did not meet the definition of a discontinued operation and was not deemed an individually material disposal transaction.

 

In May 2014, the 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 replace most of the existing revenue recognition requirements in United States GAAP when it becomes effective. The guidance in ASU No. 2014-09 is effective for public entities for annual reporting periods beginning after December 15, 2016, including interim periods therein.  Early adoption is not permitted.  The Company is currently evaluating the method of adoption and impact this standard will have on its financial statements and related disclosures.

 

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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 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; the timing of the Company’s operational capacity on third-party pipelines; gathering and transmission volumes; infrastructure programs (including the timing, cost and capacity of the transmission and gathering expansion projects); the timing, cost and capacity of the Ohio Valley Connector (OVC) and Mountain Valley Pipeline (MVP) projects; the expected terms and structure of the proposed joint venture related to the MVP project, including the Company affiliate(s) to own and operate the MVP; technology (including drilling techniques); monetization transactions, including midstream asset sales (dropdowns) to EQT Midstream Partners, LP (the Partnership) and other asset sales, joint ventures or other transactions involving the Company’s assets; natural gas prices and changes in basis; reserves; projected capital expenditures; 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 (including the Company’s ability to complete like-kind exchanges).  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, most of which are difficult to predict and many of which are beyond the Company’s control.  With respect to the proposed OVC and MVP projects, these risks and uncertainties include, among others, the ability to obtain regulatory permits and approvals, the ability to secure customer contracts, the availability of skilled labor, equipment and materials, and, with respect to the MVP project, the risk that the parties may not consummate the joint venture.  Additional risks and uncertainties that may affect the operations, performance and results of the Company’s business and forward-looking statements include, but are not limited to, those set forth under Item 1A, “Risk Factors” in the Company’s Annual Report on Form 10-K for the year ended December 31, 2013, as updated by Item 1A, “Risk Factors” in this Quarterly Report on Form 10-Q.

 

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

 

In reviewing any agreements incorporated by reference in or filed with this Quarterly Report on Form 10-Q, please remember such agreements are included to provide information regarding the terms of such agreements and are not intended to provide any other factual or disclosure information about the Company. The agreements may contain representations and warranties by the Company, which should not in all instances be treated as categorical statements of fact, but rather as a way of allocating the risk to one of the parties to such agreements should those statements prove to be inaccurate. The representations and warranties were made only as of the date of the relevant agreement or such other date or dates as may be specified in such agreement and are subject to more recent developments.  Accordingly, these representations and warranties alone may not describe the actual state of affairs of the Company or its affiliates as of the date they were made or at any other time.

 

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EQT Corporation and Subsidiaries

Management’s Discussion and Analysis of Financial Condition and Results of Operations

 

CORPORATE OVERVIEW

 

Three Months Ended June 30, 2014 vs. Three Months Ended June 30, 2013

 

Income from continuing operations attributable to EQT Corporation for the three months ended June 30, 2014 was $109.0 million, $0.72 per diluted share, compared with $81.3 million, $0.54 per diluted share, for the three months ended June 30, 2013. The $27.7 million increase in income from continuing operations attributable to EQT Corporation between periods was primarily attributable to a $37.7 million pre-tax gain recognized on the sale / exchange of assets with Range Resources Corporation (Range), a lower production depletion rate, a 17% increase in natural gas and natural gas liquid (NGL) volumes sold and increases in contracted transmission capacity and gathered volumes. These factors were partially offset by a 10% decrease in the average effective sales price for natural gas and NGLs, higher income tax expense, higher net income attributable to noncontrolling interests and higher selling, general and administrative (SG&A) expenses.

 

The average effective sales price to EQT Corporation for production sales volumes was $3.85 per Mcfe for the three months ended June 30, 2014 compared to $4.29 per Mcfe for the three months ended June 30, 2013.  The $0.44 per Mcfe decrease in the average effective sales price was primarily due to lower Appalachian Basin basis partially offset by a favorable average New York Mercantile Exchange (NYMEX) natural gas price net of hedging impacts compared to the same period of 2013. The average NYMEX natural gas index price was $4.67 per MMBtu during the second quarter of 2014, 14% higher than the average index price of $4.09 per MMBtu during the second quarter of 2013.

 

Interest expense decreased $5.5 million during the three months ended June 30, 2014 compared to the three months ended June 30, 2013 primarily as a result of higher capitalized interest of $11.0 million on increased Marcellus well development in the second quarter of 2014 compared to $5.2 million in the second quarter of 2013.

 

Income tax expense increased $21.0 million during the three months ended June 30, 2014 compared to the three months ended June 30, 2013 as a result of higher pre-tax income. The Company’s effective income tax rate was 30.2% for the second quarter of 2014 compared to 30.1% for the second quarter of 2013. The overall rate was lower for both periods as the Company consolidates 100% of the pre-tax income related to the noncontrolling public limited partners’ share of partnership earnings, but does not record an income tax provision with respect to the portion of the Partnership’s earnings allocated to its noncontrolling public limited partners.

 

Income from discontinued operations, net of tax, was $1.9 million for the three months ended June 30, 2014 compared to income from discontinued operations, net of tax, of $5.6 million for the three months ended June 30, 2013. On December 17, 2013, the Company and its wholly-owned subsidiary, Distribution Holdco, LLC (Holdco), transferred 100% of their ownership interests in Equitable Gas Company, LLC (Equitable Gas) and Equitable Homeworks, LLC (Homeworks) to PNG Companies LLC (PNG Companies).

 

Net income attributable to noncontrolling interests of the Partnership was $27.3 million for the three months ended June 30, 2014 compared to $7.3 million for the three months ended June 30, 2013. The $20.0 million increase was a result of increased noncontrolling interests and higher capacity reservation revenues in the Partnership. The Partnership completed underwritten public offerings of additional common units representing limited partner interests in the Partnership in May 2014 (in connection with the Jupiter Transaction described in Note C to the Condensed Consolidated Financial Statements) and in July 2013.

 

Six Months Ended June 30, 2014 vs. Six Months Ended June 30, 2013

 

Income from continuing operations attributable to EQT Corporation for the six months ended June 30, 2014 was $301.3 million, $1.98 per diluted share, compared with $146.5 million, $0.97 per diluted share, for the six months ended June 30, 2013. The $154.8 million increase in income from continuing operations attributable to EQT Corporation between periods was primarily attributable to a 9% higher average effective sales price for natural gas and NGLs, a lower production depletion rate, a 23% increase in natural gas and NGL volumes sold, a $37.7 million pre-tax gain recognized on the sale / exchange of assets with Range and increases in contracted transmission capacity and gathered volumes. These factors were partially offset by higher net income attributable to noncontrolling interests, higher SG&A expenses and higher income tax expense.

 

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EQT Corporation and Subsidiaries

Management’s Discussion and Analysis of Financial Condition and Results of Operations

 

The average effective sales price to EQT Corporation for production sales volumes was $4.59 per Mcfe for the six months ended June 30, 2014 compared to $4.23 per Mcfe for the six months ended June 30, 2013. The $0.36 per Mcfe increase in the average effective sales price was primarily due to an increase in the average NYMEX natural gas price net of hedging impacts and a $0.34 per Mcfe increase in third-party gathering and transmission recoveries from the utilization of existing and new third-party transportation capacity to reach higher priced markets during the unusually cold winter in the first quarter of 2014, partially offset by lower Appalachian Basin basis compared to the same period of 2013. The average NYMEX natural gas index price averaged $4.80 per MMBtu during the first half of 2014, 29% higher than the average index price of $3.71 per MMBtu during the first half of 2013.

 

Interest expense decreased $11.3 million during the six months ended June 30, 2014 compared to the six months ended June 30, 2013 primarily as a result of higher capitalized interest of $21.1 million on increased Marcellus well development in the first half of 2014 compared to $10.1 million in the first half of 2013.

 

Income tax expense increased $102.6 million in the six months ended June 30, 2014 compared to the six months ended June 30, 2013 primarily as a result of higher pre-tax income as well as a higher effective tax rate. The Company’s effective income tax rate increased to 33.6% from 30.9%.  The increase in the effective income tax rate from the first half of 2013 is primarily attributable to an increase in state tax due to increased earnings in states with higher tax rates as well as increased tax reserves recorded in certain states in 2014, and a reduction in a valuation allowance related to bonus depreciation for state tax purposes in 2013, partially offset by the impact of the Partnership’s ownership structure.  The overall rate was lower for both periods as the Company consolidates 100% of the pre-tax income related to the noncontrolling public limited partners’ share of partnership earnings, but does not record an income tax provision with respect to the portion of the Partnership’s earnings allocated to its noncontrolling public limited partners.

 

Income from discontinued operations, net of tax, was $1.8 million for the six months ended June 30, 2014 compared to income from discontinued operations, net of tax, of $40.6 million for the six months ended June 30, 2013. On December 17, 2013, the Company and its wholly-owned subsidiary Holdco transferred 100% of their ownership interests in Equitable Gas and Homeworks to PNG Companies.

 

Net income attributable to noncontrolling interests of the Partnership was $46.1 million for the six months ended June 30, 2014 compared to $16.3 million for the six months ended June 30, 2013. The $29.8 million increase was a result of increased noncontrolling interests and higher capacity reservation revenues in the Partnership. The Partnership completed underwritten public offerings of additional common units representing limited partner interests in the Partnership in May 2014 (in connection with the Jupiter Transaction described in Note C to the Condensed Consolidated Financial Statements) and in July 2013.

 

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

 

Consolidated Operational Data

 

Revenues earned by the Company at the wellhead from the sale of natural gas are split between EQT Production and EQT Midstream. The split is reflected in the calculation of EQT Production’s average effective sales price.  The following operational information presents detailed gross liquid and natural gas operational information as well as midstream deductions to assist in the understanding of the Company’s consolidated operations.

 

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Table of Contents

 

EQT Corporation and Subsidiaries

Management’s Discussion and Analysis of Financial Condition and Results of Operations

 

 

 

Three Months Ended

 

Six Months Ended

 

 

 

June 30,

 

June 30,

 

 

 

 

2014

 

2013

 

%

 

2014

 

2013

 

%

 

in thousands (unless noted)

 

 

 

 

 

 

 

 

 

 

 

 

 

LIQUIDS

 

 

 

 

 

 

 

 

 

 

 

 

 

NGLs:

 

 

 

 

 

 

 

 

 

 

 

 

 

Sales Volume (MMcfe) (a)

 

7,954

 

6,931

 

14.8 

 

15,721

 

13,623

 

15.4

 

Sales Volume (Mbbls)

 

1,326

 

1,155

 

14.8 

 

2,620

 

2,270

 

15.4

 

Gross Price ($/Bbl)

 

$

43.78

 

$

42.65

 

2.6 

 

$

49.67

 

$

44.35

 

12.0

 

Gross NGL Revenue

 

$

58,034

 

$

49,260

 

17.8 

 

$

130,148

 

$

100,683

 

29.3

 

Oil:

 

 

 

 

 

 

 

 

 

 

 

 

 

Sales Volume (MMcfe) (a)

 

395

 

327

 

20.8 

 

699

 

695

 

0.6

 

Sales Volume (Mbbls)

 

66

 

54

 

22.2 

 

116

 

116

 

 

Net Price ($/Bbl)

 

$

89.75

 

$

83.95

 

6.9 

 

$

86.85

 

$

82.55

 

5.2

 

Net Oil Revenue

 

$

5,903

 

$

4,575

 

29.0 

 

$

10,117

 

$

9,561

 

5.8

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Total Liquids Revenue

 

$

63,937

 

$

53,835

 

18.8 

 

$

140,265

 

$

110,244

 

27.2

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

GAS

 

 

 

 

 

 

 

 

 

 

 

 

 

Sales Volume – Natural Gas (MMBtu)

 

101,788

 

87,226

 

16.7 

 

199,839

 

161,880

 

23.4

 

Sales Volume – Ethane sold as natural gas (MMBtu)

 

8,234

 

6,962

 

18.3 

 

15,165

 

13,379

 

13.3

 

Sales Volume (MMBtu)

 

110,022

 

94,188

 

16.8 

 

215,004

 

175,259

 

22.7

 

NYMEX Price ($/MMBtu) (b)

 

$

4.67

 

$

4.09

 

14.2 

 

$

4.79

 

$

3.74

 

28.1

 

Gas Revenue

 

$

513,359

 

$

385,417

 

33.2 

 

$

1,029,995

 

$

655,843

 

57.0

 

Basis

 

(85,701)

 

(1,576)

 

5,337.9 

 

(109,370)

 

(3,118)

 

3,407.7

 

Gross Gas Revenue (unhedged)

 

$

427,658

 

$

383,841

 

11.4 

 

$

920,625

 

$

652,725

 

41.0

 

Sales Volume (MMcf)

 

101,788

 

87,226

 

16.7 

 

199,839

 

161,880

 

23.4

 

Gas Price ($/Mcf) (unhedged)

 

$

4.20

 

$

4.40

 

(4.5)

 

$

4.61

 

$

4.03

 

14.4

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Total Gross Gas & Liquids Revenue (unhedged)

 

$

491,595

 

$

437,676

 

12.3 

 

$

1,060,890

 

$

762,969

 

39.0

 

Hedge impact

 

(14,838)

 

9,728

 

(252.5)

 

(67,101)

 

53,226

 

(226.1)

 

Total Gross Gas & Liquids Revenue

 

$

476,757

 

$

447,404

 

6.6 

 

$

993,789

 

$

816,195

 

21.8

 

Total Sales Volume (MMcfe)

 

110,136

 

94,483

 

16.6 

 

216,259

 

176,198

 

22.7

 

Average hedge adjusted price ($/Mcfe)

 

$

4.33

 

$

4.74

 

(8.6)

 

$

4.60

 

$

4.63

 

(0.6)

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Midstream Revenue Deductions ($ / Mcfe)

 

 

 

 

 

 

 

 

 

 

 

 

 

Gathering to EQT Midstream

 

$

(0.74)

 

$

(0.81)

 

(8.6)

 

$

(0.74)

 

$

(0.84)

 

(11.9)

 

Transmission to EQT Midstream

 

(0.19)

 

(0.24)

 

(20.8)

 

(0.20)

 

(0.23)

 

(13.0)

 

Third-party gathering and transmission

 

(0.54)

 

(0.59)

 

(8.5)

 

(0.54)

 

(0.61)

 

(11.5)

 

Third-party gathering and transmission recoveries, net

 

0.20

 

0.25

 

(20.0)

 

0.66

 

0.32 

 

106.3

 

Third-party processing

 

(0.14)

 

(0.11)

 

27.3 

 

(0.13)

 

(0.11)

 

18.2

 

Total midstream revenue deductions

 

(1.41)

 

(1.50)

 

(6.0)

 

(0.95)

 

(1.47)

 

(35.4)

 

Average effective sales price to EQT Production

 

$

2.92

 

$

3.24

 

(9.9)

 

$

3.65

 

$

3.16

 

15.5

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

EQT Revenue ($ / Mcfe)

 

 

 

 

 

 

 

 

 

 

 

 

 

Revenues to EQT Midstream

 

$

0.93

 

$

1.05

 

(11.4)

 

$

0.94

 

$

1.07

 

(12.1)

 

Revenues to EQT Production

 

2.92

 

3.24

 

(9.9)

 

3.65

 

3.16

 

15.5

 

Average effective sales price to EQT Corporation

 

$

3.85

 

$

4.29

 

(10.3)

 

$

4.59

 

$

4.23

 

8.5

 

 

(a)

NGLs and crude oil were converted to Mcfe at the rate of six Mcfe per barrel for all periods. Information for the three and six months ended June 30, 2013 has been recast to reflect this conversion rate.

 

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EQT Corporation and Subsidiaries

Management’s Discussion and Analysis of Financial Condition and Results of Operations

 

(b)

The Company’s volume weighted NYMEX natural gas price (actual average NYMEX natural gas price ($/MMBtu) was $4.67 and $4.09 for the three months ended June 30, 2014 and 2013, respectively, and $4.80 and $3.71 for the six months ended June 30, 2014 and 2013, respectively).

 

Business Segment Results of Operations

 

The Company has reported the components of each segment’s operating income from continuing operations and various operational measures in the sections below and, where appropriate, has provided information describing how a measure was derived. EQT’s management believes that presentation of this information provides useful information to management and investors regarding the financial condition, operations and trends of each of EQT’s business segments without being obscured by the financial condition, operations and trends for the other segments or by the effects of corporate allocations of interest, income taxes and other income.  In addition, management uses these measures for budget planning purposes. The Company’s management reviews and reports the EQT Production segment results for operating revenues and transportation and processing costs with transportation and processing costs reflected as a deduction from operating revenues as management believes this presentation provides a more useful view of net effective sales price and is consistent with industry practices. Third-party costs incurred to gather, process and transport gas produced by EQT Production to market sales points are reported as a component of transportation and processing costs in the consolidated results. Purchased gas costs at EQT Midstream include natural gas purchases, including natural gas purchases from affiliates, purchased gas cost adjustments and other gas supply expenses. These purchased gas costs are primarily with affiliates and are eliminated in consolidation. Consistent with the consolidated results, energy trading contracts recorded within storage, marketing and other are reported net within operating revenues, regardless of whether the contracts are physically or financially settled. The Company has reconciled each segment’s operating income to the Company’s consolidated operating income and net income in Note D to the Condensed Consolidated Financial Statements in this Quarterly Report on Form 10-Q.

 

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EQT Corporation and Subsidiaries

Management’s Discussion and Analysis of Financial Condition and Results of Operations

 

EQT PRODUCTION

 

RESULTS OF OPERATIONS

 

 

 

Three Months Ended

 

Six Months Ended

 

 

 

June 30,

 

June 30,

 

 

 

2014

 

2013

 

%

 

2014

 

2013

 

%

 

OPERATIONAL DATA

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Sales volume detail (MMcfe):

 

 

 

 

 

 

 

 

 

 

 

 

 

Horizontal Marcellus Play (a)

 

85,848

 

68,882

 

24.6

 

168,974

 

124,334

 

35.9

 

Horizontal Huron Play

 

7,859

 

8,743

 

(10.1)

 

14,978

 

18,156

 

(17.5)

 

CBM Play

 

2,592

 

3,116

 

(16.8)

 

5,506

 

6,232

 

(11.6)

 

Other

 

13,837

 

13,743

 

0.7

 

26,801

 

27,476

 

(2.5)

 

Total production sales volumes (b)

 

110,136

 

94,484

 

16.6

 

216,259

 

176,198

 

22.7

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Average daily sales volumes (MMcfe/d)

 

1,210

 

1,038

 

16.6

 

1,195

 

973

 

22.8

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Average effective sales price to EQT

 

 

 

 

 

 

 

 

 

 

 

 

 

Production ($/Mcfe)

 

$

2.92

 

$

3.24

 

(9.9)

 

$

3.65

 

$

3.16

 

15.5

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Lease operating expenses (LOE), excluding

 

 

 

 

 

 

 

 

 

 

 

 

 

production taxes ($/Mcfe)

 

$

0.14

 

$

0.15

 

(6.7)

 

$

0.14

 

$

0.16

 

(12.5)

 

Production taxes ($/Mcfe)

 

$

0.15

 

$

0.14

 

7.1

 

$

0.15

 

$

0.14

 

7.1

 

Production depletion ($/Mcfe)

 

$

1.21

 

$

1.50

 

(19.3)

 

$

1.21

 

$

1.50

 

(19.3)

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

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

 

 

 

 

 

 

 

 

 

 

 

 

 

Production depletion

 

$

133,661

 

$

141,661

 

(5.6)

 

$

262,218

 

$

264,152

 

(0.7)

 

Other DD&A

 

2,590

 

2,412

 

7.4

 

5,272

 

4,830

 

9.2

 

Total DD&A (thousands)

 

$

136,251

 

$

144,073

 

(5.4)

 

$

267,490

 

$

268,982

 

(0.6)

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Capital expenditures (thousands) (c)

 

$

930,228

 

$

394,391

 

135.9

 

$

1,338,559

 

$

637,566

 

109.9

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

FINANCIAL DATA (thousands)

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Total net operating revenues

 

$

322,100

 

$

306,132

 

5.2

 

$

789,845

 

$

556,643

 

41.9

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Operating expenses:

 

 

 

 

 

 

 

 

 

 

 

 

 

LOE, excluding production taxes

 

15,513

 

14,612

 

6.2

 

30,360

 

27,651

 

9.8

 

Production taxes

 

16,369

 

13,134

 

24.6

 

33,462

 

24,985

 

33.9

 

Exploration expense

 

7,439

 

6,138

 

21.2

 

8,851

 

9,868

 

(10.3)

 

SG&A

 

32,825

 

23,119

 

42.0

 

58,774

 

46,004

 

27.8

 

DD&A

 

136,251

 

144,073

 

(5.4)

 

267,490

 

268,982

 

(0.6)

 

Total operating expenses

 

208,397

 

201,076

 

3.6

 

398,937

 

377,490

 

5.7

 

Gain on sale / exchange of assets

 

30,986

 

 

100.0

 

30,986

 

 

100.0

 

Operating income

 

$

144,689

 

$

105,056

 

37.7

 

$

421,894

 

$

179,153

 

135.5

 

 

(a)

Includes Upper Devonian wells.

 

 

(b)

NGLs and crude oil were converted to Mcfe at the rate of six Mcfe per barrel for all periods. Information for the three and six months ended June 30, 2013 has been recast to reflect this conversion rate.

 

 

(c)

Includes $157.3 million of cash capital expenditures and $353.0 million of non-cash capital expenditures for the exchange of assets with Range during the three and six months ended June 30, 2014 and $112.5 million of capital expenditures for the purchase of acreage and Marcellus wells from Chesapeake Energy Corporation and its partners during the three and six months ended June 30, 2013.

 

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EQT Corporation and Subsidiaries

Management’s Discussion and Analysis of Financial Condition and Results of Operations

 

Three Months Ended June 30, 2014 vs. Three Months Ended June 30, 2013

 

EQT Production’s operating income totaled $144.7 million for the three months ended June 30, 2014 compared to $105.1 million for the three months ended June 30, 2013.  The $39.6 million increase in operating income was primarily due to increased sales of produced natural gas and NGLs and a gain on the exchange of assets partially offset by a lower average effective sale price and an increase in operating expenses.

 

Total net operating revenues were $322.1 million for the three months ended June 30, 2014 compared to $306.1 million for the three months ended June 30, 2013.  The $16.0 million increase in operating revenues was primarily due to a 17% increase in production sales volumes partially offset by a 10% decrease in the average effective sales price to EQT Production. The increase in production sales volumes was the result of increased production from the 2012 and 2013 drilling programs, primarily in the Marcellus play. This increase was partially offset by the normal production decline in the Company’s producing wells.

 

The $0.32 per Mcfe decrease in the average effective sales price to EQT Production was primarily due to lower Appalachian Basin basis partly offset by an increase in the average NYMEX natural gas price net of hedging impacts and lower per unit midstream charges related to EQT Midstream compared to the same period of 2013.

 

Total net operating revenues for the second quarter of 2014 included a $1.0 million gain for hedging ineffectiveness of financial hedges compared to a $7.5 million loss in the second quarter of 2013. The second quarter of 2014 also included $8.7 million of derivative losses for derivative instruments not designated as hedging instruments compared to $0.4 million of derivative gains for the same period of 2013.  The losses in the second quarter of 2014 primarily relate to changes in fair market value of basis swaps.

 

As discussed in Note K to the Company’s Condensed Consolidated Financial Statements, in connection with an asset exchange with Range during the second quarter of 2014, the Company received acreage and producing wells in the Permian Basin of Texas in exchange for acreage, producing wells, the Company’s 50% ownership interest in a supporting gathering system in the Nora field of Virginia and cash of $157.3 million. In conjunction with this transaction, EQT Production recognized a pre-tax gain of $31.0 million in 2014, which is included in gain on sale / exchange of assets in the Statements of Consolidated Income.  The $31.0 million pre-tax gain includes a $28.0 million pre-tax gain related to the de-designation of certain derivative instruments that were previously designated as cash flow hedges because it was probable that the forecasted transactions would not occur. Any subsequent changes in fair value of these derivative instruments are recognized within the results of operations for EQT Production.

 

Operating expenses totaled $208.4 million for the three months ended June 30, 2014 compared to $201.1 million for the three months ended June 30, 2013. The increase in operating expenses was the result of increases in SG&A, production taxes, exploration expense and LOE partially offset by a decrease in DD&A.  SG&A expense increased in the second quarter of 2014 compared to the second quarter of 2013 primarily as a result of higher personnel costs of $3.2 million, including incentive compensation costs, and higher reserves for litigation and environmental remediation. The increase in production taxes was primarily due to a $2.3 million increase in severance taxes due to higher market sales prices and higher production sales volumes in certain jurisdictions subject to these taxes.  Production taxes also increased in the second quarter of 2014 compared to the second quarter of 2013 due to a $1.3 million increase in the Pennsylvania impact fee, primarily as a result of an increase in the number of wells drilled in Pennsylvania. The increase in exploration expense was due to increased impairments of unproved lease acreage resulting from more lease expirations during the second quarter of 2014 compared to the second quarter of 2013. The increase in LOE was mainly due to increased Marcellus activity. The decrease in DD&A expense was the result of a lower overall depletion rate partially offset by higher produced volumes in the current year.

 

Six Months Ended June 30, 2014 vs. Six Months Ended June 30, 2013

 

EQT Production’s operating income totaled $421.9 million for the six months ended June 30, 2014 compared to $179.2 million for the six months ended June 30, 2013. The $242.7 million increase in operating income was primarily due to an increase in sales of produced natural gas and NGLs, a higher average effective sale price and a gain on the exchange of assets partially offset by an increase in operating expenses.

 

Total net operating revenues were $789.8 million for the six months ended June 30, 2014 compared to $556.6 million for the six months ended June 30, 2013.  The $233.2 million increase in operating revenues was primarily due to a 23% increase in production sales volumes and a 16% increase in the average effective sales price to EQT

 

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Management’s Discussion and Analysis of Financial Condition and Results of Operations

 

Production. The increase in production sales volumes was the result of increased production from the 2012 and 2013 drilling programs, primarily in the Marcellus play. This increase was partially offset by the normal production decline in the Company’s producing wells.

 

The $0.49 per Mcfe increase in the average effective sales price to EQT Production was the net result of an increase in the average NYMEX natural gas price net of hedging impacts combined with a $0.34 per Mcfe increase in third-party gathering and transmission recoveries from the utilization of existing and new third-party transportation capacity to reach higher priced markets, partly offset by lower Appalachian Basin basis compared to the first half of 2013. Third-party gathering and transmission recoveries, net represent differences in natural gas prices between the Appalachian Basin and the sales points of other markets reached by utilizing this capacity, differences in natural gas prices between the Appalachian Basin and fixed price sales contracts and other marketing activity, including capacity releases. For the six months ended June 30, 2014, EQT Production recognized higher recoveries compared to the same period in 2013 primarily by using its capacity to sell gas in higher priced markets, particularly in the first quarter of 2014 when the weather was unusually cold and market prices in the United States Northeast region were significantly higher than the Appalachian Basin prices. Much of these higher revenues resulted from sales off of the Company’s Texas Eastern Transmission (TETCO) and Tennessee Gas Pipeline capacity, including additional TETCO capacity which the Company acquired effective February 2014.  This new capacity of 245,000 MMBtu per day enables the Company to reach markets in eastern Pennsylvania.

 

Total net operating revenues for the six months ended June 30, 2014 included a $21.3 million loss for hedging ineffectiveness of financial hedges compared to an $8.0 million loss for ineffectiveness of financial hedges in the six months ended June 30, 2013. This ineffectiveness was caused by the change in Appalachian basis since inception of the hedges. The six months ended June 30, 2014 also included $13.9 million of derivative losses for derivative instruments not designated as hedging instruments compared to $0.7 million of derivative gains for the same period of 2013.  The losses for the six months ended June 30, 2014 primarily relate to unfavorable settlements and changes in fair market value of basis swaps.

 

Operating expenses totaled $398.9 million for the six months ended June 30, 2014 compared to $377.5 million for the six months ended June 30, 2013.  The increase in operating expenses was the result of increases in SG&A, production taxes, and LOE partially offset by decreases in exploration expense and DD&A. SG&A expense increased in the first half of 2014 compared to the first half of 2013, primarily as a result of higher personnel costs of $6.8 million, including incentive compensation costs, a higher reserve for litigation and a higher allowance for doubtful accounts of $1.5 million, partially offset by lower environmental reserves for remediation.  Production taxes increased primarily due to a $6.0 million increase in severance taxes due to higher market sales prices and higher production sales volumes in certain jurisdictions subject to these taxes.  Production taxes also increased due to a $2.5 million increase in the Pennsylvania impact fee, primarily as a result of an increase in the number of wells drilled in Pennsylvania. The increase in LOE was mainly due to increased Marcellus activity. The decrease in exploration expense was due to decreased impairments of unproved lease acreage of $1.7 million resulting from fewer lease expirations during the first half of 2014 compared to the first half of 2013. DD&A expense decreased as a result of a lower overall depletion rate partially offset by higher produced volumes in the current year.

 

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Table of Contents

 

EQT Corporation and Subsidiaries

Management’s Discussion and Analysis of Financial Condition and Results of Operations

 

EQT MIDSTREAM

 

RESULTS OF OPERATIONS

 

 

 

Three Months Ended

 

Six Months Ended

 

 

 

June 30,

 

June 30,

 

 

 

2014

 

2013

 

%

 

2014

 

2013

 

%

 

OPERATIONAL DATA

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Gathered volumes (BBtu)

 

135,794

 

116,132

 

16.9

 

261,958

 

217,363

 

20.5

 

Average gathering fee ($/MMBtu)

 

$

0.67

 

$

0.75

 

(10.7)

 

$

0.69

 

$

0.78

 

(11.5)

 

Gathering and compression expense ($/MMBtu)

 

$

0.16

 

$

0.17

 

(5.9)

 

$

0.16

 

$

0.18

 

(11.1)

 

Transmission pipeline throughput (BBtu)

 

152,519

 

104,846

 

45.5

 

296,881

 

185,817

 

59.8

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Net operating revenues (thousands):

 

 

 

 

 

 

 

 

 

 

 

 

 

Gathering

 

$

91,204

 

$

86,992

 

4.8

 

$

180,580

 

$

168,806

 

7.0

 

Transmission

 

51,520

 

38,836

 

32.7

 

103,629

 

76,143

 

36.1

 

Storage, marketing and other

 

9,620

 

5,502

 

74.8

 

16,840

 

15,261

 

10.3

 

Total net operating revenues

 

$

152,344

 

$

131,330

 

16.0

 

$

301,049

 

$

260,210

 

15.7

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Capital expenditures (thousands)

 

$

110,913

 

$

89,060

 

24.5

 

$

194,126

 

$

138,204

 

40.5

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

FINANCIAL DATA (thousands)

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Total operating revenues

 

$

162,345

 

$

150,366

 

8.0

 

$

328,571

 

$

297,054

 

10.6

 

Purchased gas costs

 

10,001

 

19,036

 

(47.5)

 

27,522

 

36,844

 

(25.3)

 

Total net operating revenues

 

152,344

 

131,330

 

16.0

 

301,049

 

260,210

 

15.7

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Operating expenses:

 

 

 

 

 

 

 

 

 

 

 

 

 

Operating and maintenance (O&M)

 

27,444

 

23,936

 

14.7

 

52,598

 

46,609

 

12.8

 

SG&A

 

22,006

 

16,696

 

31.8

 

41,479

 

30,470

 

36.1

 

DD&A

 

21,130

 

18,452

 

14.5

 

42,139

 

36,671

 

14.9

 

Total operating expenses

 

70,580

 

59,084

 

19.5

 

136,216

 

113,750

 

19.8

 

Gain on sale / exchange of assets (a)

 

6,763

 

 

100.0

 

6,763

 

 

100.0

 

Operating income

 

$

88,527

 

$

72,246

 

22.5

 

$

171,596

 

$

146,460

 

17.2

 

 

(a)         As discussed in Note K to the Company’s Condensed Consolidated Financial Statements, in connection with an asset exchange with Range during the second quarter of 2014, the Company received acreage and producing wells in the Permian Basin of Texas in exchange for acreage, producing wells, the Company’s 50% ownership interest in a supporting gathering system in the Nora field of Virginia and cash of $157.3 million. In conjunction with this transaction, EQT Midstream recognized a pre-tax gain of $6.8 million, which is included in gain on sale / exchange of assets in the Statements of Consolidated Income.

 

Three Months Ended June 30, 2014 vs. Three Months Ended June 30, 2013

 

EQT Midstream’s operating income totaled $88.5 million for the three months ended June 30, 2014 compared to $72.2 million for the three months ended June 30, 2013. The increase in operating income was primarily the result of increased transmission and gathering net operating revenues, a gain on the sale / exchange of assets and increased storage, marketing and other net operating revenues partly offset by increased operating expenses.

 

Gathering net operating revenues increased due to a 17% increase in gathered volumes, partially offset by an 11% decrease in the average gathering fee.  The gathered volume increase was driven by higher volumes gathered for EQT Production in the Marcellus play.  The average gathering fee decreased due to the mix of gathered volumes as Marcellus volumes increased at a lower average fee while Huron and other volumes, which have a higher gathering fee, decreased.

 

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EQT Corporation and Subsidiaries

Management’s Discussion and Analysis of Financial Condition and Results of Operations

 

Transmission net operating revenues increased by $12.7 million as a result of higher third party and affiliate firm transmission contracted capacity of $11.9 million, including $2.5 million related to the Allegheny Valley Connector (AVC) facilities, and higher interruptible transmission service. The AVC facilities were acquired in the Equitable Gas Transaction (as defined and described in Note B to the Company’s Condensed Consolidated Financial Statements). The increase in transmission revenue is the result of increased production development in the Marcellus Shale.

 

Storage, marketing and other net operating revenues increased from the prior year primarily as a result of the storage revenues on the AVC facilities.

 

Operating expenses totaled $70.6 million for the three months ended June 30, 2014 compared to $59.1 million for the three months ended June 30, 2013. O&M expense increased $3.5 million as a result of higher personnel costs of $1.5 million and higher compressor operating expenses of $1.4 million related to the increase in Marcellus activity. SG&A expense increased $5.3 million, primarily due to higher personnel costs of $3.5 million including incentive compensation costs, $0.7 million of increased allocated expenses from affiliates, increased professional services of $0.4 million and increased franchise taxes of $0.4 million. DD&A increased $2.7 million as a result of additional assets placed in-service, including the AVC.

 

Total operating revenues increased $12.0 million primarily as a result of increased transmission revenues and increased gathered volumes partially offset by reduced total operating revenues for storage, marketing and other. Purchased gas costs decreased $9.0 million primarily as a result of reduced commercial activity.

 

Six Months Ended June 30, 2014 vs. Six Months Ended June 30, 2013

 

EQT Midstream’s operating income totaled $171.6 million for the six months ended June 30, 2014 compared to $146.5 million for the six months ended June 30, 2013. The increase in operating income was primarily the result of increased transmission and gathering net operating revenues and a gain on the sale / exchange of assets partly offset by increased operating expenses.

 

Gathering net operating revenues increased due to a 21% increase in gathered volumes, partially offset by a 12% decrease in the average gathering fee.  The gathered volume increase was driven by higher volumes gathered for EQT Production in the Marcellus play.  The average gathering fee decreased due to the mix of gathered volumes as Marcellus volumes increased at a lower average fee while Huron and other volumes, which have a higher gathering fee, decreased.

 

Transmission net operating revenues increased by $27.5 million as a result of higher third party and affiliate firm transmission contracted capacity of $26.7 million, including $7.7 million related to the AVC facilities, and higher interruptible transmission service. The increase in transmission revenue is the result of increased production development in the Marcellus Shale.

 

Storage, marketing and other net operating revenues increased from the prior year primarily due to increased storage revenues on the AVC, which was acquired in the Equitable Gas Transaction, partially offset by lower revenues on NGLs marketed for non-affiliated producers and reduced marketing revenues a result of the sale of certain energy marketing contracts on December 31, 2013.

 

Operating expenses totaled $136.2 million for the six months ended June 30, 2014 compared to $113.8 million for the six months ended June 30, 2013. O&M expense increased $6.0 million as a result of $3.6 million of higher compressor operating expenses related to an increase in Marcellus activity and additional compressors on the AVC and higher personnel costs of $2.6 million. SG&A expense increased $11.0 million primarily due to higher personnel costs of $6.4 million, including incentive compensation costs and increased allocated expenses from affiliates of $1.5 million. DD&A increased $5.5 million as a result of additional assets placed in-service, including the AVC.

 

Total operating revenues increased $31.5 million primarily as a result of increased transmission revenues and increased gathered volumes offset by reduced total operating revenues for storage, marketing and other. Purchased gas costs decreased $9.3 million primarily as a result of reduced commercial activity.

 

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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, NGL and oil reserves through environmentally responsible, cost-effective and technologically advanced horizontal drilling.  The market price for natural gas can be volatile and these fluctuations can impact the Company’s revenues, earnings and liquidity.  Due to the increased supply of natural gas in the Appalachian Basin, price differential at regional sales points in the basin have been negative relative to Henry Hub since mid-2013. While the Company is unable to predict future movements in the market price for natural gas, the Company expects this trend in Appalachian basis to continue.

 

On July 24, 2014, the Partnership announced that it will construct and own the Ohio Valley Connector (OVC) pipeline, which will be regulated by the Federal Energy Regulatory Commission (FERC). OVC will connect the Partnership’s transmission and storage system in northern West Virginia to Clarington, Ohio. At Clarington, OVC will interconnect with the Rockies Express Pipeline and the Texas Eastern Pipeline. In addition to providing Marcellus producers access to pipelines serving Midwest and Gulf Coast markets, OVC will provide Utica producers, located along the route, direct access to the Partnership’s extensive transmission system and is expected to be in-service by mid-year 2016. Subject to FERC approval, the 36 mile pipeline extension will provide approximately 1.0 Bcf per day of transmission capacity and is estimated to cost $300 million.  The Partnership has entered into a 20-year precedent agreement with EQT for a total of 650 MMcf per day of firm transmission capacity on OVC.

 

On July 10, 2014, EQT completed a non-binding open season for the proposed FERC regulated Mountain Valley Pipeline project. The open season resulted in significant interest from many potential shippers. EQT is working toward binding precedent agreements with shippers and expects to have an update on the project within the next several months.   EQT currently expects the 330-mile project, which is subject to Board and FERC approval, to extend from the Partnership’s transmission and storage system in West Virginia to southern Virginia, to provide approximately two billion cubic feet per day of firm transmission capacity and to be in-service by the end of 2018.  The pipeline is expected to be constructed and owned by a joint venture between EQT or the Partnership and NextEra Energy, Inc.

 

Total capital investment, excluding acquisitions, is expected to be approximately $2.4 billion in 2014. Capital investment for well development (primarily drilling) in 2014 is expected to be approximately $1.8 billion to support the drilling of approximately 361 gross wells, including 201 Marcellus wells, 120 Huron wells, 36 Upper Devonian wells and 4 Permian Basin wells. The Company will complete and evaluate 5 Utica wells drilled in 2013, but has decided to delay further drilling on its Ohio Utica acreage until after this year. Estimated sales volumes are expected to be 465 — 480 Bcfe for an anticipated production sales volume growth of approximately 25% in 2014, while NGL volumes are expected to be 6,500 — 6,600 Mbbls. To support continued growth in production, the Company plans to invest approximately $0.6 billion on midstream infrastructure in 2014, and expects to add approximately 440 MMcf per day of incremental gathering capacity and approximately 750 MMcf per day of transmission capacity.  The 2014 capital spending plan is expected to be funded by cash on hand, cash flow generated from operations and proceeds from equity and debt issuances by the Partnership.

 

The Company continues to focus on creating and maximizing shareholder value through the implementation of a strategy that economically accelerates the monetization of its asset base and prudently pursues investment opportunities, all while maintaining a strong balance sheet with solid cash flow.  While the tactics continue to evolve based on market conditions, the Company is considering arrangements, including asset sales and joint ventures, to monetize the value of certain mature assets for re-deployment into its highest value development opportunities.  In addition, EQT is evaluating options to realize the value of its general partner stake in the Partnership. The Company expects to decide its course of action by the end of 2014.

 

CAPITAL RESOURCES AND LIQUIDITY

 

Overview

 

The Company’s primary sources of cash for the six months ended June 30, 2014 were proceeds from the underwritten public offering of the Partnership’s common units, borrowings under the Partnership’s revolving credit facility and cash flows from operating activities, while the primary use of cash was for capital expenditures.

 

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EQT Corporation and Subsidiaries

Management’s Discussion and Analysis of Financial Condition and Results of Operations

 

Operating Activities

 

Net cash flows provided by operating activities totaled $794.6 million for the six months ended June 30, 2014 compared to $597.0 million for the six months ended June 30, 2013.  The $197.6 million increase in operating activities was primarily the result of a 23% increase in natural gas and NGL volumes sold, a 9% higher average effective sales price to EQT and increases in contracted transmission capacity and gathered volumes, partially offset by higher income tax payments and higher operating expenses.

 

Investing Activities

 

Net cash flows used in investing activities totaled $1,516.3 million for the first half of 2014 compared to $793.2 million for the first half of 2013. The $723.1 million increase was attributable to an increase of $387.9 million in cash capital expenditures, including cash paid as part of the asset exchange with Range, and an increase in restricted cash of $342.7 million in the first half of 2014 compared to 2013. During 2014, the Company placed $500.0 million of the proceeds received from the Partnership’s underwritten public offering in connection with the Jupiter Transaction into restricted cash for the use of the funds in a potential like-kind exchange for certain identified assets within a statutory time period. The Company used $157.3 million of the restricted cash in connection with the exchange of assets with Range, as discussed in Note K to the Company’s Condensed Consolidated Financial Statements.

 

Capital expenditures for EQT Production totaled $1,338.6 million for the six months ended June 30, 2014 compared to $637.6 million for the six months ended June 30, 2013. The $701.0 million increase in capital expenditures was primarily the result of an increase in property acquisitions and well development. Property acquisitions included $510.3 million of properties acquired as part of the asset exchange with Range, of which $353.0 million were non-cash capital expenditures. The increase in well development was driven by an increase in completed frac stages, an increase in wells spud and higher spending in the Huron play. The Company spud 153 gross wells in the first half of 2014, including 116 horizontal Marcellus and Upper Devonian wells, 36 horizontal Huron wells and 1 horizontal Permian Basin well. The Company spud 90 gross wells in the first half of 2013, including 88 horizontal Marcellus and Upper Devonian wells and 2 horizontal Utica wells.

 

Capital expenditures for EQT Midstream totaled $194.1 million for the first six months of 2014 compared to $138.2 million for the first six months of 2013.  The $55.9 million increase was primarily due to an increase in expenditures relating to gathering compression projects and land acquisitions.

 

Financing Activities

 

Cash flows provided by financing activities totaled $1,150.3 million for the six months ended June 30, 2014 compared to cash flows provided by financing activities of $30.8 million for the six months ended June 30, 2013, an increase of $1,119.5 million between periods. The Company received net proceeds of $902.5 million from the Partnership’s underwritten public offering of common units, received net proceeds from short-term loans of $330 million, paid distributions to noncontrolling interests of $25.7 million and used $32.4 million to repurchase and retire shares of the Company’s common stock during the six months ended June 30, 2014. The Company also paid $48.8 million for income tax withholdings related to the vesting of equity awards. As a part of a net settlement option, employees are able to elect to surrender a certain number of shares and in exchange, the Company assumes the income tax withholding obligations related to the vesting. The Company received net proceeds from short-term loans of $55.0 million, repaid maturing long-term debt of $20.2 million and paid distributions to noncontrolling interests of $10.4 million during the six months ended June 30, 2013.

 

On April 30, 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.  During the second quarter of 2014, the Company repurchased and retired 300,000 shares of common stock for $32.4 million under the authorization.

 

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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 June 30, 2014.  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 and access to the credit markets.

 

Rating Service

 

Senior
Notes

 

Outlook

 

Moody’s Investors Service

 

Baa3

 

Stable

 

Standard & Poor’s Ratings Services

 

BBB

 

Stable

 

Fitch Ratings

 

 BBB-

 

Stable

 

 

The Company’s credit ratings may be subject to revision or withdrawal at any time by the assigning rating organization, and each rating should be evaluated independently of any other rating.  The Company cannot ensure that a rating will remain in effect for any given period of time or that a rating will not be lowered or withdrawn entirely by a credit rating agency if, in its judgment, circumstances so warrant. If the credit rating agencies downgrade the Company’s ratings, particularly below investment grade, the Company’s access to the capital markets may be limited, borrowing costs and margin deposits on derivative contracts would increase, counterparties may request additional assurances and the potential pool of investors and funding sources may decrease.  The required margin on derivative instruments is also subject to significant change as a result of factors other than credit rating, such as natural gas prices and credit thresholds set forth in agreements between the hedging counterparties and the Company.

 

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. As of June 30, 2014, the Company was in compliance with all debt provisions and covenants.

 

The Partnership’s credit facility contains various provisions that, if not complied with, could result in termination of the credit facility, require early payment of amounts outstanding or similar actions.  The most significant covenants and events of default under the credit facility relate to maintenance of permitted leverage 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.  Under the credit facility, the Partnership is required to maintain a consolidated leverage ratio of not more than 5.00 to 1.00 (or, after the Partnership obtains an investment grade rating, not more than 5.50 to 1.00 for certain measurement periods following the consummation of certain acquisitions).  As of June 30, 2014, the Partnership was in compliance with all credit facility provisions and covenants.

 

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 Company’s risk management program may include the use of exchange-traded natural gas futures contracts and options and over the counter (OTC) natural gas swap agreements and options (collectively, derivative commodity instruments) to hedge exposures to fluctuations in natural gas prices.  The derivative commodity instruments currently utilized by the Company are primarily NYMEX swaps, collars and futures. The Company also enters into fixed price natural gas sales agreements that are satisfied by physical delivery. The Company’s fixed price natural gas sales agreements include contracts that fix only the NYMEX portion of the price and contracts that fix NYMEX and basis.

 

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EQT Corporation and Subsidiaries

Management’s Discussion and Analysis of Financial Condition and Results of Operations

 

As of July 23, 2014, the approximate volumes and prices of the Company’s total hedge position through December 2016 were:

 

 

 

2014 (b)

 

2015

 

2016 (c)

 

NYMEX swaps and fixed price sales

 

 

 

 

 

 

 

Total Volume (Bcf)

 

114

 

138

 

64

 

Average Price per Mcf (a)

 

$

4.36

 

$

4.33

 

$

4.45

 

 

 

 

 

 

 

 

 

Collars

 

 

 

 

 

 

 

Total Volume (Bcf)

 

12

 

23

 

 

Average Floor Price per Mcf (NYMEX) (a)

 

$

5.05

 

$

5.03

 

$

 

Average Cap Price per Mcf (NYMEX) (a)

 

$

8.85

 

$

8.97

 

$

 

 

(a)         The average price is based on a conversion rate of 1.05 MMBtu/Mcf.

(b)         July through December

(c)          For 2016, the Company also has a natural gas sales agreement for approximately 35 Bcf that includes a NYMEX ceiling price of $4.88 per Mcf.

 

See Item 3, “Quantitative and Qualitative Disclosures About Market Risk,” and Note E to the Company’s Condensed Consolidated Financial Statements for further discussion of the Company’s hedging program.

 

Commitments and Contingencies

 

In the ordinary course of business, various legal and regulatory claims and proceedings are pending or threatened against the Company.  While the amounts claimed may be substantial, the Company is unable to predict with certainty the ultimate outcome of such claims and proceedings.  The Company accrues legal and other direct costs related to loss contingencies when actually incurred.  The Company has established reserves it believes to be appropriate for pending matters and, after consultation with counsel and giving appropriate consideration to available insurance, the Company believes that the ultimate outcome of any matter currently pending against the Company will not materially affect the financial position, results of operations or liquidity of the Company.

 

During 2014, the Company increased its contractual commitments by entering into additional third-party pipeline capacity through its wholly-owned gas marketing subsidiary, EQT Energy, LLC (EQT Energy).  The most significant additions include additional TETCO capacity of 245,000 dth per day that enables the Company to reach markets in eastern Pennsylvania.  This capacity has a term of approximately seven years.  In addition, EQT Energy executed a binding precedent agreement with Rockies Express Pipeline, LLC for 300,000 dth per day of pipeline capacity from Clarington, Ohio to various delivery points in the Midwest. This binding precedent agreement has a 20-year term, and the capacity is expected to be operational beginning in the second half of 2015.

 

Dividend

 

On July 9, 2014, the Board of Directors of the Company declared a regular quarterly cash dividend of three cents per share, payable September 1, 2014, to the Company’s shareholders of record at the close of business on August 15, 2014.

 

On July 22, 2014, the Board of Directors of the Partnership’s general partner declared a cash distribution to the Partnership’s common and subordinated unitholders of $0.52 per unit for the second quarter of 2014, together with the corresponding distribution to the general partner of $0.7 million related to its 2% general partner interest and $1.9 million related to its incentive distribution rights. The cash distribution is payable on August 14, 2014, to unitholders of record at the close of business on August 5, 2014, and to the general partner.

 

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” for the year ended December 31, 2013 contained in the Company’s Annual Report on Form 10-K.  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 six month periods ended

 

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EQT Corporation and Subsidiaries

Management’s Discussion and Analysis of Financial Condition and Results of Operations

 

June 30, 2014.  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

 

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 and the storage, marketing and other activities at EQT Midstream.  The Company’s use of derivatives to reduce the effect of this volatility is described in Note E 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 also enters into derivative instruments to hedge other forecasted natural gas purchases and sales, to hedge natural gas inventory, to hedge basis and to hedge 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 Corporate Risk Committee and reviewed by the Audit Committee of the Board of Directors.

 

Commodity Price Risk

 

For the derivative commodity instruments used to hedge the Company’s forecasted production, most of which is 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.  For the derivative commodity instruments used to hedge forecasted natural gas purchases and sales which are exposed to price risk and to hedge natural gas inventory which is exposed to changes in fair value, the Company sets limits related to acceptable exposure levels. The Company does not enter into natural gas derivative commodity instruments for trading purposes.

 

The financial instruments currently utilized by the Company are primarily fixed price futures contracts, 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 also considers 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 cash flows from undue exposure to the risk of changing commodity prices.

 

With respect to the derivative commodity instruments held by the Company as of June 30, 2014 and December 31, 2013, the Company hedged portions of expected equity production, portions of forecasted purchases and sales, portions of natural gas inventory and portions of its basis exposure by utilizing futures contracts, swap agreements and collar agreements covering approximately 296 Bcf and 388 Bcf of natural gas, respectively.  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 June 30, 2014 and December 31, 2013 levels would increase the fair value of natural gas derivative instruments by approximately $128.1 million and $151.7 million, respectively.  A hypothetical increase of 10% in the market price of natural gas from the June 30, 2014 and December 31, 2013 levels would decrease the fair value of natural gas derivative instruments by approximately $128.3 million and $151.6 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 E to the Condensed Consolidated Financial Statements. The Company assumed a 10% change in the price of natural gas from its levels at June 30, 2014 and December 31, 2013. 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 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 production approximates a

 

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portion of the Company’s expected physical sales of natural gas.  Therefore, an adverse impact to the fair value of the portfolio of derivative commodity instruments held to hedge the Company’s forecasted production associated with the hypothetical changes in commodity prices referenced above should be offset by a favorable impact on the Company’s physical sales of natural gas, assuming the derivative commodity instruments 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 and the Partnership earn on cash, cash equivalents and short-term investments and the interest rates the Company and the Partnership pay on borrowings under their respective revolving credit facilities. All of the Company’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 fixed rate debt. See Note H to the Condensed Consolidated Financial Statements for further discussion of the Company’s borrowings and Note F 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 believes that NYMEX-traded futures contracts have limited credit risk because Commodity Futures Trading Commission regulations are in place to protect exchange participants, including the Company, from potential financial instability of the exchange members. The Company’s OTC swap and collar 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 53%, or $66.3 million, of the Company’s OTC derivative contracts at June 30, 2014 had a positive fair value. Approximately 79%, or $107.4 million, of the Company’s OTC derivative contracts at December 31, 2013 had a positive fair value.

 

As of June 30, 2014, the Company was not in default under any derivative contracts and had no knowledge of default by any counterparty to 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 of natural gas.  A significant amount of revenues and related accounts receivable from EQT Production are generated from the sale of produced natural gas, NGLs and crude oil to certain marketers, utility and industrial customers located mainly in the Appalachian Basin and a gas processor in Kentucky and West Virginia. Additionally, a significant amount of revenues and related accounts receivable from EQT Midstream are generated from the gathering and transporting of natural gas in Kentucky, Virginia, Pennsylvania and West Virginia.

 

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The Company has a $1.5 billion revolving credit facility that expires on February 18, 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 June 30, 2014, the Company had no loans 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.

 

The Partnership has a $750 million revolving credit facility that matures on February 18, 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 Partnership. As of June 30, 2014, the Partnership had $330 million of loans outstanding and no letters of credit outstanding under its credit facility. No one lender of the large group of financial institutions in the syndicate holds more than 10% of the facility. The Partnership’s large syndicate group and relatively low percentage of participation by each lender is expected to limit the Partnership’s exposure to problems or consolidation in the banking industry. The Company is not a guarantor of the Partnership’s obligations under the credit facility.

 

Item 4.   Controls and Procedures

 

Evaluation of Disclosure Controls and Procedures

 

Under the supervision and with the participation of management, including the Company’s Principal Executive Officer and Principal Financial Officer, an evaluation of the Company’s disclosure controls and procedures (as defined in Rule 13a-15(e) under the 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 second quarter of 2014 that have materially affected, or are reasonably likely to materially affect, the Company’s internal control over financial reporting.

 

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PART II.  OTHER INFORMATION

 

Item 1.  Legal Proceedings

 

In the ordinary course of business, various legal and regulatory claims and proceedings are pending or threatened against the Company. While the amounts claimed may be substantial, the Company is unable to predict with certainty the ultimate outcome of such claims and proceedings. The Company accrues legal and other direct costs related to loss contingencies when actually incurred. The Company has established reserves it believes to be appropriate for pending matters and, after consultation with counsel and giving appropriate consideration to available insurance, the Company believes that the ultimate outcome of any matter currently pending against the Company will not materially affect the financial position, results of operations or liquidity of the Company.

 

Environmental Proceedings

 

In June and August 2012, the Company received three Notices of Violation (NOVs) from the Pennsylvania Department of Environmental Protection (the PADEP).  The NOVs alleged violations of the Pennsylvania Oil and Gas Act and Clean Streams Law in connection with the unintentional release in May 2012, by a Company vendor, of water from an impaired water pit at a Company well location in Tioga County, Pennsylvania.  Since confirming the release, the Company has cooperated with the PADEP in remediating the affected areas.

 

During the second quarter of 2014, the Company received a proposed consent assessment of civil penalty (CACP) from the PADEP and the Pennsylvania Fish and Boat Commission (the PFBC).  Under the CACP, the PADEP proposed a civil penalty related to the NOVs and the PFBC proposed a civil penalty related to possible violations of the Pennsylvania Fish and Boat Code.  The Company is in continuing settlement discussions with the PADEP and the PFBC. While the Company expects the CACP to result in civil penalties that exceed $100,000, the Company expects the resolution of these matters, individually or in the aggregate, will not have a material impact on the financial position, results of operations or liquidity of the Company.

 

Item 1A. Risk Factors

 

While cyber security threats are embedded in a number of the Company’s risk factors discussed in Item 1A, “Risk Factors” of the Company’s Annual Report on Form 10-K for the year ended December 31, 2013, in light of externalities, including the increase in cyber crime and cyber terrorism, the Company determined to add a standalone risk factor relating to cyber incidents:

 

Cyber incidents may adversely impact our operations.

 

Our business has become increasingly dependent upon digital technologies, including information systems, infrastructure and cloud applications, to operate our production and midstream businesses, and the maintenance of our financial and other records has long been dependent upon such technologies. The U.S. government has issued public warnings that indicate that energy assets might be specific targets of cyber security threats. Deliberate attacks on, or unintentional events affecting, our systems or infrastructure, the systems or infrastructure of third parties or the cloud could lead to corruption or loss of our proprietary data and potentially sensitive data, delays in production or delivery of natural gas and NGLs, difficulty in completing and settling transactions, challenges in maintaining our books and records, environmental damage, communication interruptions, other operational disruptions and third party liability.  Further, as cyber incidents continue to evolve, we may be required to expend additional resources to continue to modify or enhance our protective measures or to investigate and remediate any vulnerability to cyber incidents.

 

Information regarding additional 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, 2013.

 

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Item 2.  Unregistered Sales of Equity Securities and Use of Proceeds

 

The following table sets forth the Company’s repurchases of equity securities registered under Section 12 of the Exchange Act that have occurred during the three months ended June 30, 2014:

 

 

 

 

 

 

 

Total number

 

 

 

Period

 

Total
number
of shares
purchased

 

Average
price
paid per
share

 

of shares
purchased as
part of publicly
announced
plans or
programs (b)

 

Maximum number
of shares that may
yet be purchased
under the plans or
programs (b)

 

 

 

 

 

 

 

 

 

 

 

April 2014  (April  1 – April 30)

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

May  2014  (May 1 – May 31) (a)

 

747

 

$

102.56

 

 

 

 

 

 

 

 

 

 

 

 

 

June 2014 (June 1 – June 30)

 

300,000

 

107.89

 

300,000

 

700,000

 

 

 

 

 

 

 

 

 

 

 

Total

 

300,747

 

$

107.88

 

300,000

 

700,000

 

 

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

 

(b)                                 On April 30, 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.

 

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Table of Contents

 

Item 6.  Exhibits

 

10.01

2014 Long-Term Incentive Plan

 

 

10.02

2006 Payroll Deduction and Contribution Program (as amended and restated November 20, 2013)

 

 

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/ Philip P. Conti

 

 

    Philip P. Conti

 

Senior Vice President and Chief Financial Officer

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Date:  July 24, 2014

 

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Table of Contents

 

INDEX TO EXHIBITS

 

Exhibit No.

 

Description

 

Method of Filing

 

 

 

 

 

10.01

 

2014 Long-Term Incentive Plan

 

Filed as Exhibit 10.1 to Form 8-K filed on May 1, 2014

 

 

 

 

 

10.02

 

2006 Payroll Deduction and Contribution Program (as amended and restated November 20, 2013)

 

Filed herewith as Exhibit 10.02

 

 

 

 

 

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

 

Filed herewith as Exhibit 32

 

 

 

 

 

101

 

Interactive Data File

 

Filed herewith as Exhibit 101

 

44