10-Q

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 March 31, 2016



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	Exact Name of Each Registrant as specified in its charter; State of Incorporation; Address; and Telephone Number	IRS Employer Identification No.
1-8962	PINNACLE WEST CAPITAL CORPORATION (an Arizona corporation) 400 North Fifth Street, P.O. Box 53999 Phoenix, Arizona 85072-3999 (602) 250-1000	86-0512431
1-4473	ARIZONA PUBLIC SERVICE COMPANY (an Arizona corporation) 400 North Fifth Street, P.O. Box 53999 Phoenix, Arizona 85072-3999 (602) 250-1000	86-0011170

Indicate by check mark whether each 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.



PINNACLE WEST CAPITAL CORPORATION	Yes x No o
ARIZONA PUBLIC SERVICE COMPANY	Yes x 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 during the preceding 12 months (or for such shorter period that the registrant was required to submit and post such files).



PINNACLE WEST CAPITAL CORPORATION	Yes x No o
ARIZONA PUBLIC SERVICE COMPANY	Yes x 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.

PINNACLE WEST CAPITAL CORPORATION



Large accelerated filer x	Accelerated filer o	Non-accelerated filer o	Smaller reporting company o

ARIZONA PUBLIC SERVICE COMPANY



Large accelerated filer o	Accelerated filer o	Non-accelerated filer x	Smaller reporting company o

Indicate by check mark whether each registrant is a shell company (as defined in Rule 12b-2 of the Exchange Act).



PINNACLE WEST CAPITAL CORPORATION	Yes o No x
ARIZONA PUBLIC SERVICE COMPANY	Yes o No x

Indicate the number of shares outstanding of each of the issuer’s classes of common stock, as of the latest practicable date.



PINNACLE WEST CAPITAL CORPORATION	Number of shares of common stock, no par value, outstanding as of April 22, 2016: 111,139,995
ARIZONA PUBLIC SERVICE COMPANY	Number of shares of common stock, $2.50 par value, outstanding as of April 22, 2016: 71,264,947

Arizona Public Service Company meets the conditions set forth in General Instruction H(1)(a) and (b) of Form 10-Q and is therefore filing this form with the reduced disclosure format allowed under that General Instruction.

TABLE OF CONTENTS



		Page

Forward-Looking Statements		2
Part I		3
Item 1.	Financial Statements	3
	Pinnacle West Capital Corporation	4
	Arizona Public Service Company	10
Item 2.	Management’s Discussion and Analysis of Financial Condition and Results of Operations	52
Item 3.	Quantitative and Qualitative Disclosures About Market Risk	69
Item 4.	Controls and Procedures	69

Part II		71
Item 1.	Legal Proceedings	71
Item 1A.	Risk Factors	71
Item 2.	Unregistered Sales of Equity Securities and Use of Proceeds	71
Item 5.	Other Information	71
Item 6.	Exhibits	72
Signatures		74

This combined Form 10-Q is separately provided by Pinnacle West Capital Corporation ("Pinnacle West") and Arizona Public Service Company ("APS"). Any use of the words "Company," "we," and "our" refer to Pinnacle West. Each registrant is providing on its own behalf all of the information contained in this Form 10-Q that relates to such registrant and, where required, its subsidiaries. Except as stated in the preceding sentence, neither registrant is providing any information that does not relate to such registrant, and therefore makes no representation as to any such information. The information required with respect to each company is set forth within the applicable items. Item 1 of this report includes Condensed Consolidated Financial Statements of Pinnacle West and Condensed Consolidated Financial Statements of APS. Item 1 also includes Combined Notes to Condensed Consolidated Financial Statements.

FORWARD-LOOKING STATEMENTS

This document contains forward-looking statements based on current expectations. These forward-looking statements are often identified by words such as "estimate," "predict," "may," "believe," "plan," "expect," "require," "intend," "assume" and similar words. Because actual results may differ materially from expectations, we caution readers not to place undue reliance on these statements. A number of factors could cause future results to differ materially from historical results, or from outcomes currently expected or sought by Pinnacle West or APS. In addition to the Risk Factors described in Part I, Item 1A of the Pinnacle West/APS Annual Report on Form 10-K for the fiscal year ended December 31, 2015 ("2015 Form 10-K"), Part II, Item 1A of this report and in Part I, Item 2 — "Management’s Discussion and Analysis of Financial Condition and Results of Operations" of this report, these factors include, but are not limited to:


•	our ability to manage capital expenditures and operations and maintenance costs while maintaining reliability and customer service levels;


•	variations in demand for electricity, including those due to weather, seasonality, the general economy, customer and sales growth (or decline), and the effects of energy conservation measures and distributed generation;


•	power plant and transmission system performance and outages;


•	competition in retail and wholesale power markets;


•	regulatory and judicial decisions, developments and proceedings;


•	new legislation, ballot initiatives and regulation, including those relating to environmental requirements, regulatory policy, nuclear plant operations and potential deregulation of retail electric markets;


•	fuel and water supply availability;


•	our ability to achieve timely and adequate rate recovery of our costs, including returns on and of debt and equity capital investment;


•	our ability to meet renewable energy and energy efficiency mandates and recover related costs;


•	risks inherent in the operation of nuclear facilities, including spent fuel disposal uncertainty;


•	current and future economic conditions in Arizona, including in real estate markets;


•	the development of new technologies which may affect electric sales or delivery;


•	the cost of debt and equity capital and the ability to access capital markets when required;


•	environmental and other concerns surrounding coal-fired generation, including regulation of greenhouse gas emissions;


•	volatile fuel and purchased power costs;


•	the investment performance of the assets of our nuclear decommissioning trust, pension, and other postretirement benefit plans and the resulting impact on future funding requirements;


•	the liquidity of wholesale power markets and the use of derivative contracts in our business;


•	potential shortfalls in insurance coverage;


•	new accounting requirements or new interpretations of existing requirements;


•	generation, transmission and distribution facility and system conditions and operating costs;


•	the ability to meet the anticipated future need for additional generation and associated transmission facilities in our region;


•	the willingness or ability of our counterparties, power plant participants and power plant land owners to meet contractual or other obligations or extend the rights for continued power plant operations; and


•	restrictions on dividends or other provisions in our credit agreements and Arizona Corporation Commission ("ACC") orders.

These and other factors are discussed in the Risk Factors described in Part I, Item 1A of our 2015 Form 10-K and in Part II, Item 1A of this report, which readers should review carefully before placing any reliance on our financial statements or disclosures. Neither Pinnacle West nor APS assumes any obligation to update these statements, even if our internal estimates change, except as required by law.

PART I — FINANCIAL INFORMATION

ITEM 1. FINANCIAL STATEMENTS

INDEX TO FINANCIAL STATEMENTS AND FINANCIAL STATEMENT SCHEDULES



	Page

Pinnacle West Condensed Consolidated Statements of Income for Three Months Ended March 31, 2016 and 2015	4
Pinnacle West Condensed Consolidated Statements of Comprehensive Income for Three Months Ended March 31, 2016 and 2015	5
Pinnacle West Condensed Consolidated Balance Sheets as of March 31, 2016 and December 31, 2015	6
Pinnacle West Condensed Consolidated Statements of Cash Flows for Three Months Ended March 31, 2016 and 2015	8
Pinnacle West Condensed Consolidated Statements of Changes in Equity for Three Months Ended March 31, 2016 and 2015	9

APS Condensed Consolidated Statements of Income for Three Months Ended March 31, 2016 and 2015	10
APS Condensed Consolidated Statements of Comprehensive Income for Three Months Ended March 31, 2016 and 2015	11
APS Condensed Consolidated Balance Sheets as of March 31, 2016 and December 31, 2015	12
APS Condensed Consolidated Statements of Cash Flows for Three Months Ended March 31, 2016 and 2015	14
APS Condensed Consolidated Statements of Changes in Equity for Three Months Ended March 31, 2016 and 2015	15

Combined Notes to Condensed Consolidated Financial Statements	16
Note 1. Consolidation and Nature of Operations	16
Note 2. Long-Term Debt and Liquidity Matters	16
Note 3. Regulatory Matters	18
Note 4. Retirement Plans and Other Postretirement Benefits	26
Note 5. Palo Verde Sale Leaseback Variable Interest Entities	27
Note 6. Derivative Accounting	28
Note 7. Commitments and Contingencies	32
Note 8. Other Income and Other Expense	40
Note 9. Earnings Per Share	41
Note 10. Fair Value Measurements	41
Note 11. Nuclear Decommissioning Trusts	48
Note 12. New Accounting Standards	49
Note 13. Changes in Accumulated Other Comprehensive Loss	50

PINNACLE WEST CAPITAL CORPORATION

CONDENSED CONSOLIDATED STATEMENTS OF INCOME

(unaudited)

(dollars and shares in thousands, except per share amounts)



	Three Months Ended March 31,
	2016			2015

OPERATING REVENUES	$	677,167		$	671,219

OPERATING EXPENSES
Fuel and purchased power	221,285			223,237
Operations and maintenance	243,195			214,944
Depreciation and amortization	119,476			120,949
Taxes other than income taxes	42,501			43,216
Other expenses	548			1,189
Total	627,005			603,535
OPERATING INCOME	50,162			67,684
OTHER INCOME (DEDUCTIONS)
Allowance for equity funds used during construction	10,516			9,224
Other income (Note 8)	117			235
Other expense (Note 8)	(4,038		)	(4,286		)
Total	6,595			5,173
INTEREST EXPENSE
Interest charges	50,744			48,399
Allowance for borrowed funds used during construction	(5,227		)	(4,216		)
Total	45,517			44,183
INCOME BEFORE INCOME TAXES	11,240			28,674
INCOME TAXES	1,914			7,947
NET INCOME	9,326			20,727
Less: Net income attributable to noncontrolling interests (Note 5)	4,873			4,605
NET INCOME ATTRIBUTABLE TO COMMON SHAREHOLDERS	$	4,453		$	16,122

WEIGHTED-AVERAGE COMMON SHARES OUTSTANDING — BASIC	111,296			110,916
WEIGHTED-AVERAGE COMMON SHARES OUTSTANDING — DILUTED	111,847			111,377

EARNINGS PER WEIGHTED-AVERAGE COMMON SHARE OUTSTANDING
Net income attributable to common shareholders — basic	$	0.04		$	0.15
Net income attributable to common shareholders — diluted	$	0.04		$	0.14

The accompanying notes are an integral part of the financial statements.

PINNACLE WEST CAPITAL CORPORATION

CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME

(unaudited)

(dollars in thousands)



	Three Months Ended March 31,
	2016			2015

NET INCOME	$	9,326		$	20,727

OTHER COMPREHENSIVE INCOME, NET OF TAX
Derivative instruments:
Net unrealized loss, net of tax expense of $546 and $473	(693		)	(800		)
Reclassification of realized loss, net of tax (expense) benefit of ($200) and $367	1,141			1,976
Pension and other postretirement benefits activity, net of tax expense of $645 and $867	530			583
Total other comprehensive income	978			1,759

COMPREHENSIVE INCOME	10,304			22,486
Less: Comprehensive income attributable to noncontrolling interests	4,873			4,605

COMPREHENSIVE INCOME ATTRIBUTABLE TO COMMON SHAREHOLDERS	$	5,431		$	17,881

The accompanying notes are an integral part of the financial statements.

PINNACLE WEST CAPITAL CORPORATION

CONDENSED CONSOLIDATED BALANCE SHEETS

(unaudited)

(dollars in thousands)



	March 31, 2016			December 31, 2015
ASSETS

CURRENT ASSETS
Cash and cash equivalents	$	14,484		$	39,488
Customer and other receivables	215,808			274,691
Accrued unbilled revenues	89,795			96,240
Allowance for doubtful accounts	(2,427		)	(3,125		)
Materials and supplies (at average cost)	234,179			234,234
Fossil fuel (at average cost)	44,227			45,697
Income tax receivable	4,637			589
Assets from risk management activities (Note 6)	16,089			15,905
Regulatory assets (Note 3)	168,753			149,555
Other current assets	40,480			37,242
Total current assets	826,025			890,516
INVESTMENTS AND OTHER ASSETS
Assets from risk management activities (Note 6)	8,612			12,106
Nuclear decommissioning trust (Note 11)	751,954			735,196
Other assets	52,679			52,518
Total investments and other assets	813,245			799,820
PROPERTY, PLANT AND EQUIPMENT
Plant in service and held for future use	16,285,916			16,222,232
Accumulated depreciation and amortization	(5,670,884		)	(5,594,094		)
Net	10,615,032			10,628,138
Construction work in progress	1,038,046			816,307
Palo Verde sale leaseback, net of accumulated depreciation (Note 5)	116,418			117,385
Intangible assets, net of accumulated amortization	116,014			123,975
Nuclear fuel, net of accumulated amortization	138,424			123,139
Total property, plant and equipment	12,023,934			11,808,944
DEFERRED DEBITS
Regulatory assets (Note 3)	1,203,474			1,214,146
Assets for other postretirement benefits (Note 4)	190,458			185,997
Other	127,965			128,835
Total deferred debits	1,521,897			1,528,978

TOTAL ASSETS	$	15,185,101		$	15,028,258

The accompanying notes are an integral part of the financial statements.

PINNACLE WEST CAPITAL CORPORATION

CONDENSED CONSOLIDATED BALANCE SHEETS

(unaudited)

(dollars in thousands)



	March 31, 2016			December 31, 2015
LIABILITIES AND EQUITY

CURRENT LIABILITIES
Accounts payable	$	234,946		$	297,480
Accrued taxes	181,889			138,600
Accrued interest	44,489			56,305
Common dividends payable	—			69,363
Short-term borrowings (Note 2)	261,800			—
Current maturities of long-term debt (Note 2)	357,580			357,580
Customer deposits	78,825			73,073
Liabilities from risk management activities (Note 6)	93,283			77,716
Liabilities for asset retirements	17,217			28,573
Deferred fuel and purchased power regulatory liability (Note 3)	13,083			9,688
Other regulatory liabilities (Note 3)	122,471			136,078
Other current liabilities	180,319			197,861
Total current liabilities	1,585,902			1,442,317
LONG-TERM DEBT LESS CURRENT MATURITIES (Note 2)	3,463,032			3,462,391
DEFERRED CREDITS AND OTHER
Deferred income taxes	2,726,220			2,723,425
Regulatory liabilities (Note 3)	1,009,418			994,152
Liabilities for asset retirements	429,626			415,003
Liabilities for pension benefits (Note 4)	441,605			480,998
Liabilities from risk management activities (Note 6)	85,603			89,973
Customer advances	110,056			115,609
Coal mine reclamation	202,069			201,984
Deferred investment tax credit	186,966			187,080
Unrecognized tax benefits	9,631			9,524
Other	194,560			186,345
Total deferred credits and other	5,395,754			5,404,093
COMMITMENTS AND CONTINGENCIES (SEE NOTES)
EQUITY
Common stock, no par value; authorized 150,000,000 shares, 111,147,524 and 111,095,402 issued at respective dates	2,547,065			2,541,668
Treasury stock at cost; 7,936 and 115,030 shares at respective dates	(542		)	(5,806		)
Total common stock	2,546,523			2,535,862
Retained earnings	2,097,246			2,092,803
Accumulated other comprehensive loss:
Pension and other postretirement benefits	(37,063		)	(37,593		)
Derivative instruments	(6,707		)	(7,155		)
Total accumulated other comprehensive loss	(43,770		)	(44,748		)
Total shareholders’ equity	4,599,999			4,583,917
Noncontrolling interests (Note 5)	140,414			135,540
Total equity	4,740,413			4,719,457

TOTAL LIABILITIES AND EQUITY	$	15,185,101		$	15,028,258

The accompanying notes are an integral part of the financial statements.

PINNACLE WEST CAPITAL CORPORATION

CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS

(unaudited)

(dollars in thousands)



	Three Months Ended March 31,
	2016			2015
CASH FLOWS FROM OPERATING ACTIVITIES
Net income	$	9,326		$	20,727
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation and amortization including nuclear fuel	140,759			141,494
Deferred fuel and purchased power	1,007			17,671
Deferred fuel and purchased power amortization	2,388			5,614
Allowance for equity funds used during construction	(10,516		)	(9,224		)
Deferred income taxes	3,468			6,978
Deferred investment tax credit	(114		)	(294		)
Change in derivative instruments fair value	(111		)	(104		)
Changes in current assets and liabilities:
Customer and other receivables	47,282			39,174
Accrued unbilled revenues	6,445			6,133
Materials, supplies and fossil fuel	1,525			(9,995		)
Income tax receivable	(4,048		)	(219		)
Other current assets	(8,131		)	(9,631		)
Accounts payable	(38,443		)	(35,673		)
Accrued taxes	43,289			48,111
Other current liabilities	(38,040		)	(56,747		)
Change in margin and collateral accounts — assets	681			(276		)
Change in margin and collateral accounts — liabilities	410			(13,420		)
Change in other long-term assets	(17,504		)	(13,126		)
Change in other long-term liabilities	4,536			6,955
Net cash flow provided by operating activities	144,209			144,148
CASH FLOWS FROM INVESTING ACTIVITIES
Capital expenditures	(378,500		)	(251,041		)
Contributions in aid of construction	12,464			27,222
Allowance for borrowed funds used during construction	(5,227		)	(4,216		)
Proceeds from nuclear decommissioning trust sales	141,809			115,282
Investment in nuclear decommissioning trust	(142,379		)	(119,594		)
Other	(472		)	(470		)
Net cash flow used for investing activities	(372,305		)	(232,817		)
CASH FLOWS FROM FINANCING ACTIVITIES
Issuance of long-term debt	—			250,000
Short-term borrowings and payments — net	261,800			(102,900		)
Dividends paid on common stock	(67,611		)	(64,061		)
Common stock equity issuance - net of purchases	8,902			9,690
Other	1			—
Net cash flow provided by financing activities	203,092			92,729

NET INCREASE (DECREASE) IN CASH AND CASH EQUIVALENTS	(25,004		)	4,060

CASH AND CASH EQUIVALENTS AT BEGINNING OF PERIOD	39,488			7,604

CASH AND CASH EQUIVALENTS AT END OF PERIOD	$	14,484		$	11,664

The accompanying notes are an integral part of the financial statements.

PINNACLE WEST CAPITAL CORPORATION

CONDENSED CONSOLIDATED STATEMENTS OF CHANGES IN EQUITY

(unaudited)

(dollars in thousands)



	Common Stock			Treasury Stock					Retained Earnings			Accumulated Other Comprehensive Income (Loss)			Noncontrolling Interests		Total
	Shares	Amount		Shares		Amount
Balance, January 1, 2015	110,649,762	$	2,512,970	(78,400	)	$	(3,401	)	$	1,926,065		$	(68,141	)	$	151,609	$	4,519,102
Net income		—				—			16,122			—			4,605		20,727
Other comprehensive income		—				—			—			1,759			—		1,759
Issuance of common stock	159,730	10,277				—			—			—			—		10,277
Purchase of treasury stock (a)		—		(93,280	)	(6,095		)	—			—			—		(6,095		)
Reissuance of treasury stock for stock-based compensation and other		—		109,896		7,230			7			—			—		7,237
Balance, March 31, 2015	110,809,492	$	2,523,247	(61,784	)	$	(2,266	)	$	1,942,194		$	(66,382	)	$	156,214	$	4,553,007

Balance, January 1, 2016	111,095,402	$	2,541,668	(115,030	)	$	(5,806	)	$	2,092,803		$	(44,748	)	$	135,540	$	4,719,457
Net income		—				—			4,453			—			4,873		9,326
Other comprehensive income		—				—			—			978			—		978
Issuance of common stock	52,122	5,397				—			—			—			—		5,397
Purchase of treasury stock (a)		—		(71,962	)	(4,880		)	—			—			—		(4,880		)
Reissuance of treasury stock for stock-based compensation and other		—		179,056		10,144			(10		)	—			1		10,135
Balance, March 31, 2016	111,147,524	$	2,547,065	(7,936	)	$	(542	)	$	2,097,246		$	(43,770	)	$	140,414	$	4,740,413

(a) Primarily represents shares of common stock withheld from certain stock awards for tax purposes.

The accompanying notes are an integral part of the financial statements.

ARIZONA PUBLIC SERVICE COMPANY

CONDENSED CONSOLIDATED STATEMENTS OF INCOME

(unaudited)

(dollars in thousands)



	Three Months Ended March 31,
	2016			2015

ELECTRIC OPERATING REVENUES	$	676,632		$	670,668

OPERATING EXPENSES
Fuel and purchased power	221,285			223,237
Operations and maintenance	238,711			209,947
Depreciation and amortization	119,446			120,926
Income taxes	5,850			12,239
Taxes other than income taxes	42,410			42,986
Total	627,702			609,335
OPERATING INCOME	48,930			61,333

OTHER INCOME (DEDUCTIONS)
Income taxes	1,815			2,151
Allowance for equity funds used during construction	10,516			9,224
Other income (Note 8)	610			639
Other expense (Note 8)	(4,750		)	(5,354		)
Total	8,191			6,660

INTEREST EXPENSE
Interest on long-term debt	46,819			45,428
Interest on short-term borrowings	2,077			1,174
Debt discount, premium and expense	1,139			1,134
Allowance for borrowed funds used during construction	(5,040		)	(4,216		)
Total	44,995			43,520

NET INCOME	12,126			24,473

Less: Net income attributable to noncontrolling interests (Note 5)	4,873			4,605

NET INCOME ATTRIBUTABLE TO COMMON SHAREHOLDER	$	7,253		$	19,868

The accompanying notes are an integral part of the financial statements.

ARIZONA PUBLIC SERVICE COMPANY

CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME

(unaudited)

(dollars in thousands)



	Three Months Ended March 31,
	2016			2015

NET INCOME	$	12,126		$	24,473

OTHER COMPREHENSIVE INCOME, NET OF TAX
Derivative instruments:
Net unrealized loss, net of tax expense of $546 and $473	(693		)	(800		)
Reclassification of realized loss, net of tax (expense) benefit of ($200) and $367	1,141			1,976
Pension and other postretirement benefits activity, net of tax expense of $558 and $769	611			681
Total other comprehensive income	1,059			1,857

COMPREHENSIVE INCOME	13,185			26,330
Less: Comprehensive income attributable to noncontrolling interests	4,873			4,605

COMPREHENSIVE INCOME ATTRIBUTABLE TO COMMON SHAREHOLDER	$	8,312		$	21,725

The accompanying notes are an integral part of the financial statements.

ARIZONA PUBLIC SERVICE COMPANY

CONDENSED CONSOLIDATED BALANCE SHEETS

(unaudited)

(dollars in thousands)



	March 31, 2016			December 31, 2015
ASSETS

PROPERTY, PLANT AND EQUIPMENT
Plant in service and held for future use	$	16,282,405		$	16,218,724
Accumulated depreciation and amortization	(5,667,713		)	(5,590,937		)
Net	10,614,692			10,627,787

Construction work in progress	1,025,868			812,845
Palo Verde sale leaseback, net of accumulated depreciation (Note 5)	116,418			117,385
Intangible assets, net of accumulated amortization	115,859			123,820
Nuclear fuel, net of accumulated amortization	138,424			123,139
Total property, plant and equipment	12,011,261			11,804,976

INVESTMENTS AND OTHER ASSETS
Nuclear decommissioning trust (Note 11)	751,954			735,196
Assets from risk management activities (Note 6)	8,612			12,106
Other assets	34,927			34,455
Total investments and other assets	795,493			781,757

CURRENT ASSETS
Cash and cash equivalents	4,904			22,056
Customer and other receivables	215,351			274,428
Accrued unbilled revenues	89,795			96,240
Allowance for doubtful accounts	(2,427		)	(3,125		)
Materials and supplies (at average cost)	234,179			234,234
Fossil fuel (at average cost)	44,227			45,697
Assets from risk management activities (Note 6)	16,089			15,905
Regulatory assets (Note 3)	168,753			149,555
Other current assets	39,043			35,765
Total current assets	809,914			870,755

DEFERRED DEBITS
Regulatory assets (Note 3)	1,203,474			1,214,146
Assets for other postretirement benefits (Note 4)	187,069			182,625
Other	127,086			127,923
Total deferred debits	1,517,629			1,524,694

TOTAL ASSETS	$	15,134,297		$	14,982,182

The accompanying notes are an integral part of the financial statements.

ARIZONA PUBLIC SERVICE COMPANY

CONDENSED CONSOLIDATED BALANCE SHEETS

(unaudited)

(dollars in thousands)



	March 31, 2016			December 31, 2015
LIABILITIES AND EQUITY

CAPITALIZATION
Common stock	$	178,162		$	178,162
Additional paid-in capital	2,379,696			2,379,696
Retained earnings	2,155,746			2,148,493
Accumulated other comprehensive (loss):
Pension and other postretirement benefits	(19,331		)	(19,942		)
Derivative instruments	(6,707		)	(7,155		)
Total shareholder equity	4,687,566			4,679,254
Noncontrolling interests (Note 5)	140,414			135,540
Total equity	4,827,980			4,814,794
Long-term debt less current maturities (Note 2)	3,338,032			3,337,391
Total capitalization	8,166,012			8,152,185
CURRENT LIABILITIES
Short-term borrowings (Note 2)	261,800			—
Current maturities of long-term debt (Note 2)	357,580			357,580
Accounts payable	232,484			291,574
Accrued taxes	183,272			144,488
Accrued interest	44,224			56,003
Common dividends payable	—			69,400
Customer deposits	78,825			73,073
Liabilities from risk management activities (Note 6)	93,283			77,716
Liabilities for asset retirements	17,217			28,573
Deferred fuel and purchased power regulatory liability (Note 3)	13,083			9,688
Other regulatory liabilities (Note 3)	122,471			136,078
Other current liabilities	172,249			180,535
Total current liabilities	1,576,488			1,424,708
DEFERRED CREDITS AND OTHER
Deferred income taxes	2,767,124			2,764,489
Regulatory liabilities (Note 3)	1,009,418			994,152
Liabilities for asset retirements	429,626			415,003
Liabilities for pension benefits (Note 4)	420,110			459,065
Liabilities from risk management activities (Note 6)	85,603			89,973
Customer advances	110,056			115,609
Coal mine reclamation	202,069			201,984
Deferred investment tax credit	186,966			187,080
Unrecognized tax benefits	35,356			35,251
Other	145,469			142,683
Total deferred credits and other	5,391,797			5,405,289
COMMITMENTS AND CONTINGENCIES (SEE NOTES)

TOTAL LIABILITIES AND EQUITY	$	15,134,297		$	14,982,182

The accompanying notes are an integral part of the financial statements.

ARIZONA PUBLIC SERVICE COMPANY

CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS

(unaudited)

(dollars in thousands)



	Three Months Ended March 31,
	2016			2015
CASH FLOWS FROM OPERATING ACTIVITIES
Net income	$	12,126		$	24,473
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation and amortization including nuclear fuel	140,729			141,471
Deferred fuel and purchased power	1,007			17,671
Deferred fuel and purchased power amortization	2,388			5,614
Allowance for equity funds used during construction	(10,516		)	(9,224		)
Deferred income taxes	3,394			2,427
Deferred investment tax credit	(114		)	(294		)
Change in derivative instruments fair value	(111		)	(104		)
Changes in current assets and liabilities:
Customer and other receivables	47,575			43,070
Accrued unbilled revenues	6,445			6,133
Materials, supplies and fossil fuel	1,525			(9,995		)
Other current assets	(8,172		)	(9,116		)
Accounts payable	(34,999		)	(35,604		)
Accrued taxes	38,784			59,057
Other current liabilities	(28,748		)	(65,290		)
Change in margin and collateral accounts — assets	681			(276		)
Change in margin and collateral accounts — liabilities	410			(13,421		)
Change in other long-term assets	(17,375		)	(16,253		)
Change in other long-term liabilities	(1,102		)	12,635
Net cash flow provided by operating activities	153,927			152,974
CASH FLOWS FROM INVESTING ACTIVITIES
Capital expenditures	(369,861		)	(250,930		)
Contributions in aid of construction	12,464			27,222
Allowance for borrowed funds used during construction	(5,040		)	(4,216		)
Proceeds from nuclear decommissioning trust sales	141,809			115,282
Investment in nuclear decommissioning trust	(142,379		)	(119,594		)
Other	(472		)	(470		)
Net cash flow used for investing activities	(363,479		)	(232,706		)
CASH FLOWS FROM FINANCING ACTIVITIES
Issuance of long-term debt	—			250,000
Short-term borrowings and payments — net	261,800			(102,900		)
Dividends paid on common stock	(69,400		)	(65,800		)
Net cash flow provided by financing activities	192,400			81,300
NET INCREASE (DECREASE) IN CASH AND CASH EQUIVALENTS	(17,152		)	1,568
CASH AND CASH EQUIVALENTS AT BEGINNING OF PERIOD	22,056			4,515
CASH AND CASH EQUIVALENTS AT END OF PERIOD	$	4,904		$	6,083
Supplemental disclosure of cash flow information
Cash paid during the period for:
Income taxes, net of refunds	$	8,772		$	184
Interest, net of amounts capitalized	$	55,580		$	52,825
Significant non-cash investing and financing activities:
Accrued capital expenditures	$	59,707		$	56,165

The accompanying notes are an integral part of the financial statements.

ARIZONA PUBLIC SERVICE COMPANY

CONDENSED CONSOLIDATED STATEMENTS OF CHANGES IN EQUITY

(unaudited)

(dollars in thousands)



	Common Stock			Additional Paid-In Capital		Retained Earnings		Accumulated Other Comprehensive Income (Loss)			Noncontrolling Interests		Total
	Shares	Amount
Balance, January 1, 2015	71,264,947	$	178,162	$	2,379,696	$	1,968,718	$	(48,333	)	$	151,609	$	4,629,852
Net income		—		—		19,868		—			4,605		24,473
Other comprehensive income		—		—		—		1,857			—		1,857
Other		—		—		1		—			—		1
Balance, March 31, 2015	71,264,947	$	178,162	$	2,379,696	$	1,988,587	$	(46,476	)	$	156,214	$	4,656,183

Balance, January 1, 2016	71,264,947	$	178,162	$	2,379,696	$	2,148,493	$	(27,097	)	$	135,540	$	4,814,794
Net income		—		—		7,253		—			4,873		12,126
Other comprehensive income		—		—		—		1,059			—		1,059
Other		—		—		—		—			1		1
Balance, March 31, 2016	71,264,947	$	178,162	$	2,379,696	$	2,155,746	$	(26,038	)	$	140,414	$	4,827,980

The accompanying notes are an integral part of the financial statements.

COMBINED NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS


1.	Consolidation and Nature of Operations

The unaudited condensed consolidated financial statements include the accounts of Pinnacle West and our subsidiaries: APS, Bright Canyon Energy Corporation ("BCE") and El Dorado Investment Company ("El Dorado"). Intercompany accounts and transactions between the consolidated companies have been eliminated. The unaudited condensed consolidated financial statements for APS include the accounts of APS and the Palo Verde Nuclear Generating Station ("Palo Verde") sale leaseback variable interest entities ("VIEs") (see Note 5 for further discussion). Our accounting records are maintained in accordance with accounting principles generally accepted in the United States of America ("GAAP"). The preparation of financial statements in accordance with GAAP requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities, disclosure of contingent assets and liabilities at the date of the financial statements and reported amounts of revenues and expenses during the reporting period. Actual results could differ from those estimates.

Amounts reported in our interim Condensed Consolidated Statements of Income are not necessarily indicative of amounts expected for the respective annual periods, due to the effects of seasonal temperature variations on energy consumption, timing of maintenance on electric generating units, and other factors.

Our condensed consolidated financial statements reflect all adjustments (consisting only of normal recurring adjustments except as otherwise disclosed in the notes) that we believe are necessary for the fair presentation of our financial position, results of operations, and cash flows for the periods presented. Certain information and footnote disclosures normally included in financial statements prepared in conformity with GAAP have been condensed or omitted pursuant to such regulations, although we believe that the disclosures provided are adequate to make the interim information presented not misleading. The accompanying condensed consolidated financial statements and these notes should be read in conjunction with the audited consolidated financial statements and notes included in our 2015 Form 10-K.

Supplemental Cash Flow Information

The following table summarizes supplemental Pinnacle West cash flow information (dollars in thousands):



	Three Months Ended March 31,
	2016		2015
Cash paid during the period for:
Income taxes, net of refunds	$	2,502	$	1,832
Interest, net of amounts capitalized	56,139		53,555
Significant non-cash investing and financing activities:
Accrued capital expenditures	$	59,707	$	56,165


2.	Long-Term Debt and Liquidity Matters

Pinnacle West and APS maintain committed revolving credit facilities in order to enhance liquidity and provide credit support for their commercial paper programs, to refinance indebtedness, and for other general corporate purposes.

COMBINED NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

Pinnacle West

At March 31, 2016, Pinnacle West had a $200 million revolving credit facility that matures in May 2019. Pinnacle West has the option to increase the amount of the facility up to a maximum of $300 million upon the satisfaction of certain conditions and with the consent of the lenders. At March 31, 2016, Pinnacle West had no outstanding borrowings under its credit facility, no letters of credit outstanding and no commercial paper borrowings.

APS

During the first quarter of 2016, APS increased its commercial paper program from $250 million to $500 million.

On April 22, 2016, APS entered into a $100 million term loan facility that matures April 22, 2019. Interest rates are based on APS's senior unsecured debt credit ratings. APS used the proceeds to repay and refinance existing short-term indebtedness.

At March 31, 2016, APS had two revolving credit facilities totaling $1 billion, including a $500 million credit facility that matures in September 2020 and a $500 million facility that matures in May 2019. APS may increase the amount of each facility up to a maximum of $700 million, for a total of $1.4 billion, upon the satisfaction of certain conditions and with the consent of the lenders. Interest rates are based on APS’s senior unsecured debt credit ratings. These facilities are available to support APS’s $500 million commercial paper program, for bank borrowings or for issuances of letters of credit. At March 31, 2016, APS had $262 million of commercial paper outstanding and no outstanding borrowings or letters of credit under its revolving credit facilities.

See "Financial Assurances" in Note 7 for a discussion of APS’s separate outstanding letters of credit.

Debt Fair Value

Our long-term debt fair value estimates are based on quoted market prices for the same or similar issues, and are classified within Level 2 of the fair value hierarchy. Certain of our debt instruments contain third-party credit enhancements and, in accordance with GAAP, we do not consider the effect of these credit enhancements when determining fair value. The following table presents the estimated fair value of our long-term debt, including current maturities (dollars in thousands):



	As of March 31, 2016				As of December 31, 2015
	Carrying Amount		Fair Value		Carrying Amount		Fair Value
Pinnacle West	$	125,000	$	125,000	$	125,000	$	125,000
APS	3,695,612		4,136,022		3,694,971		3,981,367
Total	$	3,820,612	$	4,261,022	$	3,819,971	$	4,106,367

Debt Provisions

COMBINED NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

compliance with this common equity ratio requirement. Its total shareholder equity was approximately $4.7 billion, and total capitalization was approximately $8.6 billion. APS would be prohibited from paying dividends if the payment would reduce its total shareholder equity below approximately $3.4 billion, assuming APS’s total capitalization remains the same.


3.	Regulatory Matters

Retail Rate Case Filings with the Arizona Corporation Commission

Upcoming Rate Case Filing

On January 29, 2016, APS filed a notice of its intent to file a rate case ("NOI") informing the ACC that APS intends to submit a rate case application in June 2016 using an adjusted test year ending December 31, 2015. The NOI provides an overview of the key issues APS expects to address in its formal request such as rate design changes (residential, commercial and industrial), permission to defer for potential future recovery costs associated with the Ocotillo Modernization Project, permission to defer for potential future recovery costs associated with environmental standards compliance, inclusion of post-test year plant and modifications to certain adjustor mechanisms, among other items. In its rate application, APS will request that its proposed pricing changes take effect in July 2017. APS is still developing the exact amount of the request.

Prior Rate Case Filing

On June 1, 2011, APS filed an application with the ACC for a net retail base rate increase of $95.5 million. APS requested that the increase become effective July 1, 2012. The request would have increased the average retail customer bill by approximately 6.6%. On January 6, 2012, APS and other parties to the general retail rate case entered into an agreement (the "2012 Settlement Agreement") detailing the terms upon which the parties agreed to settle the rate case. On May 15, 2012, the ACC approved the 2012 Settlement Agreement without material modifications.

Settlement Agreement

The 2012 Settlement Agreement provides for a zero net change in base rates, consisting of: (1) a non-fuel base rate increase of $116.3 million; (2) a fuel-related base rate decrease of $153.1 million (to be implemented by a change in the base fuel rate for fuel and purchased power costs ("Base Fuel Rate") from $0.03757 to $0.03207 per kilowatt hour ("kWh"); and (3) the transfer of cost recovery for certain renewable energy projects from the Arizona Renewable Energy Standard and Tariff ("RES") surcharge to base rates in an estimated amount of $36.8 million.

Other key provisions of the 2012 Settlement Agreement include the following:


•	An authorized return on common equity of 10.0%;


•	A capital structure comprised of 46.1% debt and 53.9% common equity;


•	A test year ended December 31, 2010, adjusted to include plant that is in service as of March 31, 2012;


•	Deferral for future recovery or refund of property taxes above or below a specified 2010 test year level caused by changes to the Arizona property tax rate as follows:

COMBINED NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS


•	Deferral of increases in property taxes of 25% in 2012, 50% in 2013 and 75% for 2014 and subsequent years if Arizona property tax rates increase; and


•	Deferral of 100% in all years if Arizona property tax rates decrease;


•	A procedure to allow APS to request rate adjustments prior to its next general rate case related to APS’s acquisition of additional interests in Units 4 and 5 and the related closure of Units 1-3 of the Four Corners Power Plant ("Four Corners") (APS made its filing under this provision on December 30, 2013, see "Four Corners" below);


•	Implementation of a Lost Fixed Cost Recovery ("LFCR") rate mechanism to support energy efficiency and distributed renewable generation;


•	Modifications to the Environmental Improvement Surcharge ("EIS") to allow for the recovery of carrying costs for capital expenditures associated with government-mandated environmental controls, subject to an existing cents per kWh cap on cost recovery that could produce up to approximately $5 million in revenues annually;


•	Modifications to the Power Supply Adjustor ("PSA"), including the elimination of the 90/10 sharing provision;


•	A limitation on the use of the RES surcharge and the Demand Side Management Adjustor Charge ("DSMAC") to recoup capital expenditures not required under the terms of APS’s 2009 retail rate case settlement agreement (the "2009 Settlement Agreement");


•	Modification of the Transmission Cost Adjustor ("TCA") to streamline the process for future transmission-related rate changes; and


•	Implementation of various changes to rate schedules, including the adoption of an experimental "buy-through" rate that could allow certain large commercial and industrial customers to select alternative sources of generation to be supplied by APS.

The 2012 Settlement Agreement was approved by the ACC on May 15, 2012, with new rates effective on July 1, 2012. This accomplished a goal set by the parties to the 2009 Settlement Agreement to process subsequent rate cases within twelve months of sufficiency findings from the ACC staff, which generally occurs within 30 days after the filing of a rate case.

Cost Recovery Mechanisms

APS has received regulatory decisions that allow for more timely recovery of certain costs through the following recovery mechanisms.

Renewable Energy Standard. In 2006, the ACC approved the RES. Under the RES, electric utilities that are regulated by the ACC must supply an increasing percentage of their retail electric energy sales from eligible renewable resources, including solar, wind, biomass, biogas and geothermal technologies. In order to achieve these requirements, the ACC allows APS to include a RES surcharge as part of customer bills to recover the approved amounts for use on renewable energy projects. Each year APS is required to file a five-year implementation plan with the ACC and seek approval for funding the upcoming year’s RES budget.

COMBINED NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

In accordance with the ACC's decision on APS's 2014 RES plan, on April 15, 2014, APS filed an application with the ACC requesting permission to build an additional 20 megawatts ("MW") of APS-owned grid scale solar under the AZ Sun Program. In a subsequent filing, APS also offered an alternative proposal to replace the 20 MW of grid scale solar with 10 MW (approximately 1,500 customers) of APS-owned residential solar that will not be under the AZ Sun Program. On December 19, 2014, the ACC voted that it had no objection to APS implementing its residential rooftop solar program. The first stage of the residential rooftop solar program, called the "Solar Partner Program", is to be 8 MW followed by a 2 MW second stage that will only be deployed if coupled with distributed storage. The program will target specific distribution feeders in an effort to maximize potential system benefits, as well as make systems available to limited-income customers who cannot easily install solar through transactions with third parties. The ACC expressly reserved that any determination of prudency of the residential rooftop solar program for rate making purposes shall not be made until the project is fully in service and APS requests cost recovery in a future rate case.

On July 1, 2014, APS filed its 2015 RES implementation plan and proposed a RES budget of approximately $154 million. On December 31, 2014, the ACC issued a decision approving the 2015 RES implementation plan with minor modifications, including reducing the requested budget to approximately $152 million.

On July 1, 2015, APS filed its 2016 RES implementation plan and proposed a RES budget of approximately $148 million. On January 12, 2016, the ACC approved APS’s plan and requested budget.

Demand Side Management Adjustor Charge. The ACC Electric Energy Efficiency Standards require APS to submit a Demand Side Management Implementation Plan ("DSM Plan") for review by and approval of the ACC. In March 2014, the ACC approved a Resource Savings Initiative that allows APS to count towards compliance with the ACC Electric Energy Efficiency Standards, savings from improvements to APS’s transmission and delivery system, generation and facilities that have been approved through a DSM Plan.

On March 20, 2015, APS filed an application with the ACC requesting a budget of $68.9 million for 2015 and minor modifications to its DSM portfolio going forward, including for the first time three resource savings projects which reflect energy savings on APS's system. The ACC approved APS’s 2015 DSM budget on November 25, 2015. In its decision, the ACC also approved that verified energy savings from APS's resource savings projects could be counted toward compliance with the Electric Energy Efficiency Standard, however, the ACC ruled that APS was not allowed to count savings from systems savings projects toward determination of its achievement tier level for its performance incentive, nor may APS include savings from conservation voltage reduction in the calculation of its LFCR mechanism.

On June 1, 2015, APS filed its 2016 DSM Plan requesting a budget of $68.9 million and minor modifications to its DSM portfolio to increase energy savings and cost effectiveness of the programs. On April 1, 2016, APS filed an Amended DSM Plan that sought minor modifications to its 2015 DSM Plan and requested to continue the current DSMAC and current budget of $68.9 million.

Electric Energy Efficiency. On June 27, 2013, the ACC voted to open a new docket investigating whether the Electric Energy Efficiency Standards should be modified. The ACC held a series of three workshops in March and April 2014 to investigate methodologies used to determine cost effective energy efficiency programs, cost recovery mechanisms, incentives, and potential changes to the Electric Energy Efficiency and Resource Planning Rules.

COMBINED NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

On November 4, 2014, the ACC staff issued a request for informal comment on a draft of possible amendments to Arizona’s Electric Energy Efficiency Standards. The draft proposed substantial changes to the rules and energy efficiency standards. The ACC accepted written comments and took public comment regarding the possible amendments on December 19, 2014. A formal rulemaking has not been initiated and there has been no additional action on the draft to date.

PSA Mechanism and Balance. The PSA provides for the adjustment of retail rates to reflect variations in retail fuel and purchased power costs. The following table shows the changes in the deferred fuel and purchased power regulatory asset (liability) for 2016 and 2015 (dollars in thousands):



	Three Months Ended March 31,
	2016			2015
Beginning balance	$	(9,688	)	$	6,925
Deferred fuel and purchased power costs — current period	(1,007		)	(17,671		)
Amounts charged to customers	(2,388		)	(5,614		)
Ending balance	$	(13,083	)	$	(16,360	)

The PSA rate for the PSA year beginning February 1, 2016 is $0.001678 per kWh, as compared to $0.000887 per kWh for the prior year. This new rate is comprised of a forward component of $0.001975 per kWh and a historical component of $(0.000297) per kWh. On October 15, 2015, APS notified the ACC that it was initiating a PSA transition component of $(0.004936) per kWh for the months of November 2015, December 2015, and January 2016. The PSA transition component is a mid-year adjustment to the PSA rate that may be established when conditions change sufficiently to cause high balances to accrue in the PSA balancing account. The transition component expired on February 1, 2016. Any uncollected (overcollected) deferrals during the PSA year, after accounting for the transition component, will be included in the calculation of the PSA rate for the PSA year beginning February 1, 2017.

Transmission Rates, Transmission Cost Adjustor and Other Transmission Matters. In July 2008, the United States Federal Energy Regulatory Commission ("FERC") approved an Open Access Transmission Tariff for APS to move from fixed rates to a formula rate-setting methodology in order to more accurately reflect and recover the costs that APS incurs in providing transmission services. A large portion of the rate represents charges for transmission services to serve APS's retail customers ("Retail Transmission Charges"). In order to recover the Retail Transmission Charges, APS was previously required to file an application with, and obtain approval from, the ACC to reflect changes in Retail Transmission Charges through the TCA. Under the terms of the 2012 Settlement Agreement, however, an adjustment to rates to recover the Retail Transmission Charges will be made annually each June 1 and will go into effect automatically unless suspended by the ACC.

The formula rate is updated each year effective June 1 on the basis of APS's actual cost of service, as disclosed in APS's FERC Form 1 report for the previous fiscal year. Items to be updated include actual capital expenditures made as compared with previous projections, transmission revenue credits and other items. The resolution of proposed adjustments can result in significant volatility in the revenues to be collected. APS reviews the proposed formula rate filing amounts with the ACC staff. Any items or adjustments which are not agreed to by APS and the ACC staff can remain in dispute until settled or litigated at FERC. Settlement or litigated resolution of disputed issues could require an extended period of time and could have a significant

COMBINED NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

effect on the Retail Transmission Charges because any adjustment, though applied prospectively, may be calculated to account for previously over- or under-collected amounts.

Effective June 1, 2015, APS's annual wholesale transmission rates for all users of its transmission system decreased by approximately $17.6 million in accordance with the FERC-approved formula. An adjustment to APS’s retail rates to recover FERC-approved transmission charges went into effect automatically on June 1, 2015.

APS's formula rate protocols have been in effect since 2008. Recent FERC orders suggest that FERC is examining the structure of formula rate protocols and may require companies such as APS to make changes to their protocols in the future.

Lost Fixed Cost Recovery Mechanism. The LFCR mechanism permits APS to recover on an after-the-fact basis a portion of its fixed costs that would otherwise have been collected by APS in the kWh sales lost due to APS energy efficiency programs and to distributed generation such as rooftop solar arrays. The fixed costs recoverable by the LFCR mechanism were established in the 2012 Settlement Agreement and amount to approximately 3.1 cents per residential kWh lost and 2.3 cents per non-residential kWh lost. The LFCR adjustment has a year-over-year cap of 1% of retail revenues. Any amounts left unrecovered in a particular year because of this cap can be carried over for recovery in a future year. The kWh’s lost from energy efficiency are based on a third-party evaluation of APS’s energy efficiency programs. Distributed generation sales losses are determined from the metered output from the distributed generation units.

APS files for a LFCR adjustment every January. APS filed its 2014 annual LFCR adjustment on January 15, 2014, requesting a LFCR adjustment of $25.3 million, effective March 1, 2014. The ACC approved APS’s LFCR adjustment without change on March 11, 2014, which became effective April 1, 2014. APS filed its 2015 annual LFCR adjustment on January 15, 2015, requesting an LFCR adjustment of $38.5 million, which was approved on March 2, 2015, effective for the first billing cycle of March. APS filed its 2016 annual LFCR adjustment on January 15, 2016, requesting an LFCR adjustment of $46.4 million (a $7.9 million annual increase), to be effective for the first billing cycle of March 2016. To date the ACC has not yet approved this matter.

Net Metering

On July 12, 2013, APS filed an application with the ACC proposing a solution to address the cost shift brought by the current net metering rules. On December 3, 2013, the ACC issued its order on APS's net metering proposal. The ACC instituted a charge on customers who install rooftop solar panels after December 31, 2013. The charge of $0.70 per kilowatt became effective on January 1, 2014, and is estimated to collect $4.90 per month from a typical future rooftop solar customer to help pay for their use of the electric grid. The fixed charge does not increase APS's revenue because it is credited to the LFCR.

In making its decision, the ACC determined that the current net metering program creates a cost shift, causing non-solar utility customers to pay higher rates to cover the costs of maintaining the electric grid. The ACC acknowledged that the $0.70 per kilowatt charge addresses only a portion of the cost shift.

On October 20, 2015, the ACC voted to conduct a generic evidentiary hearing on the value and cost of distributed generation to gather information that will inform the ACC on net metering issues and cost of service studies in upcoming utility rate cases. A hearing commenced in April 2016. APS cannot predict the outcome of this proceeding.

COMBINED NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

In 2015, Arizona jurisdictional utilities UNS Electric, Inc. and Tucson Electric Power Company both filed applications with the ACC requesting rate increases. These applications include rate design changes to mitigate the cost shift caused by net metering. On December 9, 2015 and February 23, 2016, APS filed testimony in the UNS Electric, Inc. rate case in support of the UNS Electric, Inc. proposed rate design changes. APS actively participated in the related hearings held in March 2016. APS has also intervened in the upcoming Tucson Electric Power Company rate case. The outcomes of these proceedings will not directly impact our financial position.

Appellate Review of Third-Party Regulatory Decision ("System Improvement Benefits" or "SIB")

In a recent appellate challenge to an ACC rate decision involving a water company, the Arizona Court of Appeals considered the question of how the ACC should determine the “fair value” of a utility’s property, as specified in the Arizona Constitution, in connection with authorizing the recovery of costs through rate adjustors outside of a rate case. The Court of Appeals reversed the ACC’s method of finding fair value in that case, and raised questions concerning the relationship between the need for fair value findings and the recovery of capital and certain other utility costs through adjustors. The ACC sought review by the Arizona Supreme Court of this decision and APS filed a brief supporting the ACC’s petition to the Arizona Supreme Court for review of the Court of Appeals’ decision. On February 9, 2016, the Arizona Supreme Court granted review of the decision and oral argument was conducted on March 22, 2016. If the decision is upheld by the Supreme Court without modification, certain APS rate adjustors may require modification. This could in turn have an impact on APS’s ability to recover certain costs in between rate cases. APS cannot predict the outcome of this matter.

Four Corners

On December 30, 2013, APS purchased Southern California Edison Company's ("SCE’s") 48% ownership interest in each of Units 4 and 5 of Four Corners. The 2012 Settlement Agreement includes a procedure to allow APS to request rate adjustments prior to its next general rate case related to APS’s acquisition of the additional interests in Units 4 and 5 and the related closure of Units 1-3 of Four Corners. APS made its filing under this provision on December 30, 2013. On December 23, 2014, the ACC approved rate adjustments resulting in a revenue increase of $57.1 million on an annual basis. This includes the deferral for future recovery of all non-fuel operating costs for the acquired SCE interest in Four Corners, net of the non-fuel operating costs savings resulting from the closure of Units 1-3 from the date of closing of the purchase through its inclusion in rates. The 2012 Settlement Agreement also provides for deferral for future recovery of all unrecovered costs incurred in connection with the closure of Units 1-3. The deferral balance related to the acquisition of SCE’s interest in Units 4 and 5 and the closure of Units 1-3 was $69 million as of March 31, 2016 and is being amortized in rates over a total of 10 years. On February 23, 2015, the Arizona School Boards Association and the Association of Business Officials filed a notice of appeal in Division 1 of the Arizona Court of Appeals of the ACC decision approving the rate adjustments. APS has intervened and is actively participating in the proceeding. The Arizona Court of Appeals has suspended the appeal pending the Arizona Supreme Court's decision in the SIB matter discussed above, which could have an effect on the outcome of this Four Corners proceeding. We cannot predict when or how this matter will be resolved.

COMBINED NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

termination. On December 22, 2015, APS and SCE agreed to terminate the Transmission Termination Agreement and allow for the Transmission Agreement to expire according to its terms, which includes settling obligations in accordance with the terms of the Transmission Agreement. APS established a regulatory asset of $12 million in 2015 in connection with the payment required under the terms of the Transmission Agreement, which it expects to recover through its FERC-jurisdictional rates.

Cholla

On September 11, 2014, APS announced that it would close Unit 2 of the Cholla Power Plant ("Cholla") and cease burning coal at the other APS-owned units (Units 1 and 3) at the plant by the mid-2020s, if the United States Environmental Protection Agency ("EPA") approves a compromise proposal offered by APS to meet required environmental and emissions standards and rules. On April 14, 2015, the ACC approved APS's plan to retire Unit 2, without expressing any view on the future recoverability of APS's remaining investment in the Unit. APS closed Unit 2 on October 1, 2015. Previously, APS estimated Cholla Unit 2’s end of life to be 2033. APS is currently recovering a return on and of the net book value of the unit in base rates and plans to seek recovery of the unit’s decommissioning and other retirement-related costs over the remaining life of the plant in its next retail rate case. APS believes it will be allowed recovery of the remaining net book value of Unit 2 ($121 million as of March 31, 2016), in addition to a return on its investment. In accordance with GAAP, in the third quarter of 2014, Unit 2’s remaining net book value was reclassified from property, plant and equipment to a regulatory asset. If the ACC does not allow full recovery of the remaining net book value of Cholla Unit 2, all or a portion of the regulatory asset will be written off and APS’s net income, cash flows, and financial position will be negatively impacted.

COMBINED NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

Regulatory Assets and Liabilities

The detail of regulatory assets is as follows (dollars in thousands):



	Amortization Through	March 31, 2016				December 31, 2015
	Amortization Through	Current		Non-Current		Current		Non-Current
Pension	(a)	$	—	$	610,569	$	—	$	619,223
Retired power plant costs	2033	9,913		125,037		9,913		127,518
Income taxes — allowance for funds used during construction ("AFUDC") equity	2046	5,419		132,149		5,495		133,712
Deferred fuel and purchased power — mark-to-market (Note 6)	2019	86,160		69,708		71,852		69,697
Four Corners cost deferral (b)	2024	6,689		61,910		6,689		63,582
Income taxes — investment tax credit basis adjustment	2045	1,852		48,347		1,766		48,462
Lost fixed cost recovery (b)	2017	48,702		—		45,507		—
Palo Verde VIEs (Note 5)	2046	—		18,311		—		18,143
Deferred compensation	2036	—		35,871		—		34,751
Deferred property taxes	(c)	—		56,589		—		50,453
Loss on reacquired debt	2034	1,515		15,996		1,515		16,375
Tax expense of Medicare subsidy	2024	1,512		12,073		1,520		12,163
Transmission vegetation management	2016	2,272		—		4,543		—
Mead-Phoenix transmission line CIAC	2050	332		10,957		332		11,040
Transmission cost adjustor (b)	2018	3,969		462		—		2,942
Coal reclamation	2026	418		5,495		418		6,085
Other	Various	—		—		5		—
Total regulatory assets (d)		$	168,753	$	1,203,474	$	149,555	$	1,214,146


(a)	This asset represents the future recovery of pension benefit obligations through retail rates. If these costs are disallowed by the ACC, this regulatory asset would be charged to Other Comprehensive Income ("OCI") and result in lower future revenues. See Note 4 for further discussion.


(b)	See "Cost Recovery Mechanisms" discussion above.


(c)	Per the provision of the 2012 Settlement Agreement.


(d)	There are no regulatory assets for which the ACC has allowed recovery of costs, but not allowed a return by exclusion from rate base. FERC rates are set using a formula rate as described in "Transmission Rates, Transmission Cost Adjustor and Other Transmission Matters."

COMBINED NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

The detail of regulatory liabilities is as follows (dollars in thousands):



	Amortization Through	March 31, 2016				December 31, 2015
	Amortization Through	Current		Non-Current		Current		Non-Current
Asset retirement obligations	2057	$	—	$	289,485	$	—	$	277,554
Removal costs	(a)	32,473		244,724		39,746		240,367
Other postretirement benefits	(d)	34,100		171,029		34,100		179,521
Income taxes — deferred investment tax credit	2045	3,774		96,940		3,604		97,175
Income taxes — change in rates	2046	1,771		71,756		1,113		72,454
Spent nuclear fuel	2047	31		71,235		3,051		67,437
Renewable energy standard (b)	2017	41,518		3,274		43,773		4,365
Demand side management (b)	2017	6,628		19,115		6,079		19,115
Sundance maintenance	2030	—		14,080		—		13,678
Deferred fuel and purchased power (b) (c)	2017	13,083		—		9,688		—
Deferred gains on utility property	2019	2,062		5,501		2,062		6,001
Four Corners coal reclamation	2031	—		14,725		—		8,920
Other	Various	114		7,554		2,550		7,565
Total regulatory liabilities		$	135,554	$	1,009,418	$	145,766	$	994,152


(a)	In accordance with regulatory accounting guidance, APS accrues for removal costs for its regulated assets, even if there is no legal obligation for removal.


(b)	See "Cost Recovery Mechanisms" discussion above.


(c)	Subject to a carrying charge.


(d)	See Note 4.


4.	Retirement Plans and Other Postretirement Benefits

Pinnacle West sponsors a qualified defined benefit and account balance pension plan, a non-qualified supplemental excess benefit retirement plan, and an other postretirement benefit plan for the employees of Pinnacle West and our subsidiaries. Pinnacle West uses a December 31 measurement date for its pension and other postretirement benefit plans. The market-related value of our plan assets is their fair value at the measurement dates. On September 30, 2014, Pinnacle West announced plan design changes to the other postretirement benefit plan. Because of the plan changes, the Company is currently in the process of seeking Internal Revenue Service ("IRS") and regulatory approval to move approximately $140 million of the other postretirement benefit trust assets into a new trust account to pay for active union employee medical costs.

Certain pension and other postretirement benefit costs in excess of amounts recovered in electric retail rates were deferred in 2011 and 2012 as a regulatory asset for future recovery, pursuant to APS’s 2009 retail rate case settlement. Pursuant to this order, we began amortizing the regulatory asset over three years beginning in July 2012. We completed amortizing these costs as of June 30, 2015. We amortized approximately $2 million for the three months ended March 31, 2015.

COMBINED NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

The following table provides details of the plans’ net periodic benefit costs and the portion of these costs charged to expense (including administrative costs and excluding amounts capitalized as overhead construction, billed to electric plant participants or charged or amortized to the regulatory asset) (dollars in thousands):



	Pension Benefits						Other Benefits
	Three Months Ended March 31,						Three Months Ended March 31,
	2016			2015			2016			2015
Service cost — benefits earned during the period	$	14,266		$	15,824		$	3,937		$	4,346
Interest cost on benefit obligation	32,945			31,189			7,341			7,184
Expected return on plan assets	(43,792		)	(45,149		)	(9,122		)	(9,147		)
Amortization of:
Prior service cost	132			149			(9,471		)	(9,492		)
Net actuarial loss	9,731			7,761			946			1,561
Net periodic benefit cost	$	13,282		$	9,774		$	(6,369	)	$	(5,548	)
Portion of cost charged to expense	$	6,519		$	5,987		$	(3,126	)	$	(1,788	)

Contributions

We made voluntary contributions of $60 million to our pension plan year-to-date in 2016. The minimum required contributions for the pension plan are zero for the next three years. We expect to make voluntary contributions up to a total of $300 million during the 2016-2018 period. We expect to make contributions of approximately $1 million in each of the next three years to our other postretirement benefit plans.


5.	Palo Verde Sale Leaseback Variable Interest Entities

In 1986, APS entered into agreements with three separate VIE lessor trust entities in order to sell and lease back interests in Palo Verde Unit 2 and related common facilities. APS will retain the assets through 2023 under one lease and 2033 under the other two leases. APS will be required to make payments relating to these leases of approximately $23 million annually for the period 2016 through 2023, and $16 million annually for the period 2024 through 2033. At the end of the lease period, APS will have the option to purchase the leased assets at their fair market value, extend the leases for up to two years, or return the assets to the lessors.

The leases' terms give APS the ability to utilize the assets for a significant portion of the assets’ economic life, and therefore provide APS with the power to direct activities of the VIEs that most significantly impact the VIEs’ economic performance. Predominantly due to the lease terms, APS has been deemed the primary beneficiary of these VIEs and therefore consolidates the VIEs.

As a result of consolidation, we eliminate lease accounting and instead recognize depreciation and interest expense, resulting in an increase in net income for the three months ended March 31, 2016 and 2015 of $5 million, entirely attributable to the noncontrolling interests. Income attributable to Pinnacle West shareholders is not impacted by the consolidation.

COMBINED NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

Our Condensed Consolidated Balance Sheets at March 31, 2016 and December 31, 2015 include the following amounts relating to the VIEs (in thousands):



	March 31, 2016		December 31, 2015
Palo Verde sale leaseback property plant and equipment, net of accumulated depreciation	$	116,418	$	117,385
Equity — Noncontrolling interests	140,414		135,540

Assets of the VIEs are restricted and may only be used for payment to the noncontrolling interest holders. Other than the VIEs’ assets reported on our consolidated financial statements, the creditors of the VIEs have no other recourse to the assets of APS or Pinnacle West, except in certain circumstances such as a default by APS under the lease.

APS is exposed to losses relating to these VIEs upon the occurrence of certain events that APS does not consider to be reasonably likely to occur. Under certain circumstances (for example, the United States Nuclear Regulatory Commission ("NRC") issuing specified violation orders with respect to Palo Verde or the occurrence of specified nuclear events), APS would be required to make specified payments to the VIEs’ noncontrolling equity participants and take title to the leased Unit 2 interests, which, if appropriate, may be required to be written down in value. If such an event were to occur during the lease periods, APS may be required to pay the noncontrolling equity participants approximately $288 million beginning in 2016, and up to $456 million over the lease terms.

For regulatory ratemaking purposes, the agreements continue to be treated as operating leases and, as a result, we have recorded a regulatory asset relating to the arrangements.


6.	Derivative Accounting

We are exposed to the impact of market fluctuations in the commodity price and transportation costs of electricity, natural gas, coal, emissions allowances and in interest rates. We manage risks associated with market volatility by utilizing various physical and financial derivative instruments, including futures, forwards, options and swaps. As part of our overall risk management program, we may use derivative instruments to hedge purchases and sales of electricity and fuels. Derivative instruments that meet certain hedge accounting criteria may be designated as cash flow hedges and are used to limit our exposure to cash flow variability on forecasted transactions. The changes in market value of such instruments have a high correlation to price changes in the hedged transactions. We also enter into derivative instruments for economic hedging purposes. While we believe the economic hedges mitigate exposure to fluctuations in commodity prices, these instruments have not been designated as accounting hedges. Contracts that have the same terms (quantities, delivery points and delivery periods) and for which power does not flow are netted, which reduces both revenues and fuel and purchased power costs in our Condensed Consolidated Statements of Income, but does not impact our financial condition, net income or cash flows.

Our derivative instruments, excluding those qualifying for a scope exception, are recorded on the balance sheet as an asset or liability and are measured at fair value. See Note 10 for a discussion of fair value measurements. Derivative instruments may qualify for the normal purchases and normal sales scope exception if they require physical delivery and the quantities represent those transacted in the normal course of business. Derivative instruments qualifying for the normal purchases and sales scope exception are accounted for under

COMBINED NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

the accrual method of accounting and excluded from our derivative instrument discussion and disclosures below.

Hedge effectiveness is the degree to which the derivative instrument contract and the hedged item are correlated and is measured based on the relative changes in fair value of the derivative instrument contract and the hedged item over time. We assess hedge effectiveness both at inception and on a continuing basis. These assessments exclude the time value of certain options. For accounting hedges that are deemed an effective hedge, the effective portion of the gain or loss on the derivative instrument is reported as a component of OCI and reclassified into earnings in the same period during which the hedged transaction affects earnings. We recognize in current earnings, subject to the PSA, the gains and losses representing hedge ineffectiveness, and the gains and losses on any hedge components which are excluded from our effectiveness assessment. As cash flow hedge accounting has been discontinued for the significant majority of our contracts, after May 31, 2012, effectiveness testing is no longer being performed for these contracts.

For its regulated operations, APS defers for future rate treatment 100% of the unrealized gains and losses on derivatives pursuant to the PSA mechanism that would otherwise be recognized in income. Realized gains and losses on derivatives are deferred in accordance with the PSA to the extent the amounts are above or below the Base Fuel Rate (see Note 3). Gains and losses from derivatives in the following tables represent the amounts reflected in income before the effect of PSA deferrals.

As of March 31, 2016, we had the following outstanding gross notional volume of derivatives, which represent both purchases and sales (does not reflect net position):



Commodity	Quantity
Power	2,239	GWh
Gas	179	Billion cubic feet

Gains and Losses from Derivative Instruments

The following table provides information about gains and losses from derivative instruments in designated cash flow accounting hedging relationships during the three months ended March 31, 2016 and 2015 (dollars in thousands):



	Financial Statement Location	Three Months Ended March 31,
Commodity Contracts	Financial Statement Location	2016			2015
Loss recognized in OCI on derivative instruments (effective portion)	OCI — derivative instruments	$	(147	)	$	(327	)
Loss reclassified from accumulated OCI into income (effective portion realized) (a)	Fuel and purchased power (b)	(941		)	(2,343		)


(a)	During the three months ended March 31, 2016 and 2015, we had no losses reclassified from accumulated OCI to earnings related to discontinued cash flow hedges.


(b)	Amounts are before the effect of PSA deferrals.

COMBINED NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

transactions. In accordance with the PSA, most of these amounts will be recorded as either a regulatory asset or liability and have no immediate effect on earnings.

The following table provides information about gains and losses from derivative instruments not designated as accounting hedging instruments during the three months ended March 31, 2016 and 2015 (dollars in thousands):



	Financial Statement Location	Three Months Ended March 31,
Commodity Contracts	Financial Statement Location	2016			2015
Net loss recognized in income	Operating revenues	$	(102	)	$	(48	)
Net loss recognized in income	Fuel and purchased power (a)	(30,936		)	(44,803		)
Total		$	(31,038	)	$	(44,851	)


(a)	Amounts are before the effect of PSA deferrals.

Derivative Instruments in the Condensed Consolidated Balance Sheets

Our derivative transactions are typically executed under standardized or customized agreements, which include collateral requirements and, in the event of a default, would allow for the netting of positive and negative exposures associated with a single counterparty. Agreements that allow for the offsetting of positive and negative exposures associated with a single counterparty are considered master netting arrangements. Transactions with counterparties that have master netting arrangements are offset and reported net on the Condensed Consolidated Balance Sheets. Transactions that do not allow for offsetting of positive and negative positions are reported gross on the Condensed Consolidated Balance Sheets.

We do not offset a counterparty’s current derivative contracts with the counterparty’s non-current derivative contracts, although our master netting arrangements would allow current and non-current positions to be offset in the event of a default. Additionally, in the event of a default, our master netting arrangements would allow for the offsetting of all transactions executed under the master netting arrangement. These types of transactions may include non-derivative instruments, derivatives qualifying for scope exceptions, trade receivables and trade payables arising from settled positions, and other forms of non-cash collateral (such as letters of credit). These types of transactions are excluded from the offsetting tables presented below.

The significant majority of our derivative instruments are not currently designated as hedging instruments. The Condensed Consolidated Balance Sheets as of March 31, 2016 and December 31, 2015, each include gross liabilities of $3 million of derivative instruments designated as hedging instruments.

The following tables provide information about the fair value of our risk management activities reported on a gross basis, and the impacts of offsetting as of March 31, 2016 and December 31, 2015. These amounts relate to commodity contracts and are located in the assets and liabilities from risk management activities lines of our Condensed Consolidated Balance Sheets.

COMBINED NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS



As of March 31, 2016: (dollars in thousands)	Gross Recognized Derivatives (a)			Amounts Offset (b)			Net Recognized Derivatives			Other (c)			Amount Reported on Balance Sheet
Current assets	$	25,365		$	(9,268	)	$	16,097		$	(8	)	$	16,089
Investments and other assets	11,248			(2,636		)	8,612			—			8,612
Total assets	36,613			(11,904		)	24,709			(8		)	24,701

Current liabilities	(115,822		)	26,868			(88,954		)	(4,329		)	(93,283		)
Deferred credits and other	(88,239		)	2,636			(85,603		)	—			(85,603		)
Total liabilities	(204,061		)	29,504			(174,557		)	(4,329		)	(178,886		)
Total	$	(167,448	)	$	17,600		$	(149,848	)	$	(4,337	)	$	(154,185	)


(a)	All of our gross recognized derivative instruments were subject to master netting arrangements.


(b)	Includes cash collateral provided to counterparties of $17,600.


(c)	Represents cash collateral and cash margin that is not subject to offsetting. Amounts relate to non-derivative instruments, derivatives qualifying for scope exceptions, or collateral and margin posted in excess of the recognized derivative instrument. Includes cash collateral received from counterparties of $4,329, and cash margin provided to counterparties of $(8).



As of December 31, 2015: (dollars in thousands)	Gross Recognized Derivatives (a)			Amounts Offset (b)			Net Recognized Derivatives			Other (c)			Amount Reported on Balance Sheet
Current assets	$	37,396		$	(22,163	)	$	15,233		$	672		$	15,905
Investments and other assets	15,960			(3,854		)	12,106			—			12,106
Total assets	53,356			(26,017		)	27,339			672			28,011

Current liabilities	(113,560		)	40,223			(73,337		)	(4,379		)	(77,716		)
Deferred credits and other	(93,827		)	3,854			(89,973		)	—			(89,973		)
Total liabilities	(207,387		)	44,077			(163,310		)	(4,379		)	(167,689		)
Total	$	(154,031	)	$	18,060		$	(135,971	)	$	(3,707	)	$	(139,678	)


(a)	All of our gross recognized derivative instruments were subject to master netting arrangements.


(b)	Includes cash collateral provided to counterparties of $18,060.


(c)	Represents cash collateral and cash margin that is not subject to offsetting. Amounts relate to non-derivative instruments, derivatives qualifying for scope exceptions, or collateral and margin posted in excess of the recognized derivative instrument. Includes cash collateral received from counterparties of $4,379, and cash margin provided to counterparties of $672.

Credit Risk and Credit Related Contingent Features

COMBINED NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

rating agencies, there is still a possibility that one or more of these companies could default, resulting in a material impact on consolidated earnings for a given period. Counterparties in the portfolio consist principally of financial institutions, major energy companies, municipalities and local distribution companies. We maintain credit policies that we believe minimize overall credit risk to within acceptable limits. Determination of the credit quality of our counterparties is based upon a number of factors, including credit ratings and our evaluation of their financial condition. To manage credit risk, we employ collateral requirements and standardized agreements that allow for the netting of positive and negative exposures associated with a single counterparty. Valuation adjustments are established representing our estimated credit losses on our overall exposure to counterparties.

Certain of our derivative instrument contracts contain credit-risk-related contingent features including, among other things, investment grade credit rating provisions, credit-related cross-default provisions, and adequate assurance provisions. Adequate assurance provisions allow a counterparty with reasonable grounds for uncertainty to demand additional collateral based on subjective events and/or conditions. For those derivative instruments in a net liability position, with investment grade credit contingencies, the counterparties could demand additional collateral if our debt credit rating were to fall below investment grade (below BBB- for Standard & Poor’s or Fitch or Baa3 for Moody’s).

The following table provides information about our derivative instruments that have credit-risk-related contingent features at March 31, 2016 (dollars in thousands):



	March 31, 2016
Aggregate fair value of derivative instruments in a net liability position	$	204,061
Cash collateral posted	17,600
Additional cash collateral in the event credit-risk-related contingent features were fully triggered (a)	133,688


(a)	This amount is after counterparty netting and includes those contracts which qualify for scope exceptions, which are excluded from the derivative details above.

We also have energy-related non-derivative instrument contracts with investment grade credit-related contingent features, which could also require us to post additional collateral of approximately $153 million if our debt credit ratings were to fall below investment grade.


7.	Commitments and Contingencies

Palo Verde Nuclear Generating Station

Spent Nuclear Fuel and Waste Disposal

On December 19, 2012, APS, acting on behalf of itself and the participant owners of Palo Verde, filed a second breach of contract lawsuit against the United States Department of Energy ("DOE") in the United States Court of Federal Claims ("Court of Federal Claims"). The lawsuit sought to recover damages incurred due to DOE’s breach of the Contract for Disposal of Spent Nuclear Fuel and/or High Level Radioactive Waste ("Standard Contract") for failing to accept Palo Verde's spent nuclear fuel and high level waste from January 1, 2007 through June 30, 2011, as it was required to do pursuant to the terms of the Standard Contract and the Nuclear Waste Policy Act. On August 18, 2014, APS and DOE entered into a settlement agreement, stipulating to a dismissal of the lawsuit and payment of $57.4 million by DOE to the Palo Verde owners for certain specified costs incurred by Palo Verde during the period January 1, 2007 through June 30, 2011. APS’s share

COMBINED NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

of this amount is $16.7 million. Amounts recovered in the lawsuit and settlement were recorded as adjustments to a regulatory liability and had no impact on the amount of reported net income. In addition, the settlement agreement provides APS with a method for submitting claims and getting recovery for costs incurred through December 31, 2016.

APS has submitted two claims pursuant to the terms of the August 18, 2014 settlement agreement, for two separate time periods during July 1, 2011 through June 30, 2015. The DOE has approved and paid $53.9 million for these claims (APS’s share is $15.7 million). The amounts recovered were primarily recorded as adjustments to a regulatory liability and had no impact on reported net income.

Nuclear Insurance

Public liability for incidents at nuclear power plants is governed by the Price-Anderson Nuclear Industries Indemnity Act ("Price-Anderson Act"), which limits the liability of nuclear reactor owners to the amount of insurance available from both commercial sources and an industry retrospective payment plan. In accordance with the Price-Anderson Act, the Palo Verde participants are insured against public liability for a nuclear incident up to $13.5 billion per occurrence. Palo Verde maintains the maximum available nuclear liability insurance in the amount of $375 million, which is provided by American Nuclear Insurers ("ANI"). The remaining balance of $13.1 billion of liability coverage is provided through a mandatory industry-wide retrospective assessment program. If losses at any nuclear power plant covered by the program exceed the accumulated funds, APS could be assessed retrospective premium adjustments. The maximum retrospective premium assessment per reactor under the program for each nuclear liability incident is approximately $127.3 million, subject to an annual limit of $19 million per incident, to be periodically adjusted for inflation. Based on APS’s ownership interest in the three Palo Verde units, APS’s maximum potential retrospective premium assessment per incident for all three units is approximately $111 million, with a maximum annual retrospective premium assessment of approximately $16.6 million.

The Palo Verde participants maintain "all risk" (including nuclear hazards) insurance for property damage to, and decontamination of, property at Palo Verde in the aggregate amount of $2.8 billion, a substantial portion of which must first be applied to stabilization and decontamination. APS has also secured insurance against portions of any increased cost of replacement generation or purchased power and business interruption resulting from a sudden and unforeseen accidental outage of any of the three units. The property damage, decontamination, and replacement power coverages are provided by Nuclear Electric Insurance Limited ("NEIL"). APS is subject to retrospective premium assessments under all NEIL policies if NEIL’s losses in any policy year exceed accumulated funds. The maximum amount APS could incur under the current NEIL policies totals approximately $23.1 million for each retrospective premium assessment declared by NEIL’s Board of Directors due to losses. In addition, NEIL policies contain rating triggers that would result in APS providing approximately $61.7 million of collateral assurance within 20 business days of a rating downgrade to non-investment grade. The insurance coverage discussed in this and the previous paragraph is subject to certain policy conditions, sublimits and exclusions.

COMBINED NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

Contractual Obligations

There have been no material changes, as of March 31, 2016, outside the normal course of business in contractual obligations from the information provided in our 2015 Form 10-K. See Note 2 for discussion regarding changes in our long-term debt obligations.

Superfund-Related Matters

The Comprehensive Environmental Response Compensation and Liability Act ("Superfund") establishes liability for the cleanup of hazardous substances found contaminating the soil, water or air. Those who generated, transported or disposed of hazardous substances at a contaminated site are among those who are potentially responsible parties ("PRPs"). PRPs may be strictly, and often are jointly and severally, liable for clean-up. On September 3, 2003, EPA advised APS that EPA considers APS to be a PRP in the Motorola 52^nd Street Superfund Site, Operable Unit 3 ("OU3") in Phoenix, Arizona. APS has facilities that are within this Superfund site. APS and Pinnacle West have agreed with EPA to perform certain investigative activities of the APS facilities within OU3. In addition, on September 23, 2009, APS agreed with EPA and one other PRP to voluntarily assist with the funding and management of the site-wide groundwater remedial investigation and feasibility study work plan. We estimate that our costs related to this investigation and study will be approximately $2 million. We anticipate incurring additional expenditures in the future, but because the overall investigation is not complete and ultimate remediation requirements are not yet finalized, at the present time expenditures related to this matter cannot be reasonably estimated.

On August 6, 2013, the Roosevelt Irrigation District ("RID") filed a lawsuit in Arizona District Court against APS and 24 other defendants, alleging that RID’s groundwater wells were contaminated by the release of hazardous substances from facilities owned or operated by the defendants. The lawsuit also alleges that, under Superfund laws, the defendants are jointly and severally liable to RID. The allegations against APS arise out of APS’s current and former ownership of facilities in and around OU3. As part of a state governmental investigation into groundwater contamination in this area, on January 25, 2015, the Arizona Department of Environmental Quality ("ADEQ") sent a letter to APS seeking information concerning the degree to which, if any, APS’s current and former ownership of these facilities may have contributed to groundwater contamination in this area. APS responded to ADEQ on May 4, 2015. We are unable to predict the outcome of these matters; however, we do not expect the outcome to have a material impact on our financial position, results of operations or cash flows.

Southwest Power Outage

On September 8, 2011 at approximately 3:30 PM, a 500 kilovolt ("kV") transmission line running between the Hassayampa and North Gila substations in southwestern Arizona tripped out of service due to a fault that occurred at a switchyard operated by APS. Approximately ten minutes after the transmission line went off-line, generation and transmission resources for the Yuma area were lost, resulting in approximately 69,700 APS customers losing service.

On September 6, 2013, a purported consumer class action complaint was filed in Federal District Court in San Diego, California, naming APS and Pinnacle West as defendants and seeking damages for loss of perishable inventory and sales as a result of interruption of electrical service. APS and Pinnacle West filed a motion to dismiss, which the court granted on December 9, 2013. On January 13, 2014, the plaintiffs appealed the lower court’s decision. On March 2, 2016, the United States Court of Appeals for the Ninth Circuit unanimously affirmed the District Court's decision. The plaintiffs filed a Petition for Rehearing En Banc, which was denied on April 11, 2016.

COMBINED NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

Environmental Matters

APS is subject to numerous environmental laws and regulations affecting many aspects of its present and future operations, including air emissions, water quality, wastewater discharges, solid waste, hazardous waste, and coal combustion residuals ("CCRs"). These laws and regulations can change from time to time, imposing new obligations on APS resulting in increased capital, operating, and other costs. Associated capital expenditures or operating costs could be material. APS intends to seek recovery of any such environmental compliance costs through our rates, but cannot predict whether it will obtain such recovery. The following proposed and final rules involve material compliance costs to APS.

Regional Haze Rules. APS has received the final rulemaking imposing new requirements on Four Corners, Cholla and the Navajo Generating Station ("Navajo Plant"). EPA and ADEQ will require these plants to install pollution control equipment that constitutes best available retrofit technology ("BART") to lessen the impacts of emissions on visibility surrounding the plants.

Four Corners. Based on EPA’s final standards, APS estimates that its 63% share of the cost of these controls for Four Corners Units 4 and 5 would be approximately $400 million. In addition, APS and El Paso Electric Company ("El Paso") entered into an asset purchase agreement providing for the purchase by APS, or an affiliate of APS, of El Paso's 7% interest in Four Corners Units 4 and 5. When APS, or an affiliate of APS, ultimately acquires El Paso's interest in Four Corners, Navajo Transitional Energy Company, LLC ("NTEC") has the option to purchase the interest within a certain timeframe pursuant to an option granted by APS to NTEC. In December 2015, NTEC notified APS of its intent to exercise the option. APS is negotiating a definitive purchase agreement with NTEC for the purchase of the 7% interest. The cost of the pollution controls related to the 7% interest is approximately $45 million, which will be assumed by the ultimate owner of the 7% interest.

Navajo Plant. APS estimates that its share of costs for upgrades at the Navajo Plant, based on EPA’s Federal Implementation Plan ("FIP"), could be up to approximately $200 million. In October 2014, a coalition of environmental groups, an Indian tribe and others filed petitions for review in the United States Court of Appeals for the Ninth Circuit asking the Court to review EPA's final BART rule for the Navajo Plant. We cannot predict the outcome of this review process.

Cholla. APS believes that EPA’s final rule as it applies to Cholla, which would require installation of selective catalytic reduction ("SCR") controls with a cost to APS of approximately $100 million (excludes costs related to Cholla Unit 2 which was closed on October 1, 2015), is unsupported and that EPA had no basis for disapproving Arizona’s State Implementation Plan ("SIP") and promulgating a FIP that is inconsistent with the state’s considered BART determinations under the regional haze program. Accordingly, on February 1, 2013, APS filed a Petition for Review of the final BART rule in the United States Court of Appeals for the Ninth Circuit. Briefing in the case was completed in February 2014.

In September 2014, APS met with EPA to propose a compromise BART strategy wherein, pending certain regulatory approvals, APS would permanently close Cholla Unit 2 and cease burning coal at Units 1 and 3 by the mid-2020s. (See Note 3 for details related to the resulting regulatory asset.) APS made the proposal with the understanding that additional emission control equipment is unlikely to be required in the future because retiring and/or converting the units as contemplated in the proposal is more cost effective than, and will result in increased visibility improvement over, the current BART requirements for NOx imposed on the Cholla units under EPA's BART FIP. APS’s proposal involves state and federal rulemaking processes. In

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light of these ongoing administrative proceedings, on February 19, 2015, APS, PacifiCorp (owner of Cholla Unit 4), and EPA jointly moved the court to sever and hold in abeyance those claims in the litigation pertaining to Cholla pending regulatory actions by the state and EPA. The court granted the parties' unopposed motion on February 20, 2015. On October 16, 2015, ADEQ issued the Cholla permit, which incorporates APS's proposal, and subsequently submitted a proposed revision to the SIP to the EPA, which would incorporate the new permit terms. APS is unable to predict when or whether APS's proposal may ultimately be approved by the EPA.

Mercury and Air Toxic Standards ("MATS"). In 2011, EPA issued rules establishing maximum achievable control technology standards to regulate emissions of mercury and other hazardous air pollutants from fossil-fired plants. APS estimates that the cost for the remaining equipment necessary to meet these standards is approximately $8 million for Cholla (excludes costs related to Cholla Unit 2 which was closed on October 1, 2015). No additional equipment is needed for Four Corners Units 4 and 5 to comply with these rules. Salt River Project Agricultural Improvement and Power District ("SRP"), the operating agent for the Navajo Plant, estimates that APS's share of costs for equipment necessary to comply with the rules is approximately $1 million. The United States Supreme Court’s 2015 decision in Michigan vs. EPA reversed and remanded the MATS proceeding back to the DC Circuit Court. The Circuit Court then remanded the MATS rule back to EPA to address rulemaking deficiencies identified by the Supreme Court. On April 14, 2016, EPA took action to resolve these deficiencies by issuing a revised "appropriate and necessary" finding, which is a prerequisite to regulating hazardous air pollutants emitted by power plants under the Clean Air Act, to expressly evaluate the costs of the MATS regulation. Further litigation concerning the propriety of this finding is expected. These proceedings do not materially impact APS. Regardless of the results from further judicial or administrative proceedings concerning the MATS rulemaking, the Arizona State Mercury Rule, the stringency of which is roughly equivalent to that of MATS, would still apply to Cholla.

Coal Combustion Waste. On December 19, 2014, EPA issued its final regulations governing the handling and disposal of CCR, such as fly ash and bottom ash. The rule regulates CCR as a non-hazardous waste under Subtitle D of the Resource Conservation and Recovery Act ("RCRA") and establishes national minimum criteria for existing and new CCR landfills and surface impoundments and all lateral expansions consisting of location restrictions, design and operating criteria, groundwater monitoring and corrective action, closure requirements and post closure care, and recordkeeping, notification, and Internet posting requirements. The rule generally requires any existing unlined CCR surface impoundment that is contaminating groundwater above a regulated constituent’s groundwater protection standard to stop receiving CCR and either retrofit or close, and further requires the closure of any CCR landfill or surface impoundment that cannot meet the applicable performance criteria for location restrictions or structural integrity.

Because the Subtitle D rule is self-implementing, the CCR standards apply directly to the regulated facility, and facilities are directly responsible for ensuring that their operations comply with the rule’s requirements. While EPA has chosen to regulate the disposal of CCR in landfills and surface impoundments as non-hazardous waste under the final rule, the agency makes clear that it will continue to evaluate any risks associated with CCR disposal and leaves open the possibility that it may regulate CCR as a hazardous waste under RCRA Subtitle C in the future.

APS currently disposes of CCR in ash ponds and dry storage areas at Cholla and Four Corners. APS estimates that its share of incremental costs to comply with the CCR rule for Four Corners is approximately $15 million, and its share of incremental costs for Cholla is approximately $40 million. The Navajo Plant currently disposes of CCR in a dry landfill storage area. APS estimates that its share of incremental costs to comply with the CCR rule for the Navajo Plant is approximately $1 million. Additionally, the CCR rule requires on-going groundwater monitoring. Depending upon the results of such monitoring at each of Cholla,

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Four Corners and the Navajo Plant, we may be required to take corrective actions. Because the initial monitoring at these plants is not yet complete, at the present time expenditures related to potential corrective actions cannot be reasonably estimated.

Clean Power Plan. On August 3, 2015, EPA finalized carbon pollution standards for existing, new, modified, and reconstructed electric generating units ("EGUs"). EPA’s final rules require newly built fossil fuel-fired EGUs, along with those undergoing modification or reconstruction, to meet CO₂ performance standards based on a combination of best operating practices and equipment upgrades. EPA established separate performance standards for two types of EGUs: stationary combustion turbines, typically natural gas; and electric utility steam generating units, typically coal.

With respect to existing power plants, EPA’s recently finalized “Clean Power Plan” imposes state-specific goals or targets to achieve reductions in CO₂ emission rates from existing EGUs measured from a 2012 baseline. In a significant change from the proposed rule, EPA’s final performance standards apply directly to specific units based upon their fuel-type and configuration (i.e., coal- or oil-fired steam plants versus combined cycle natural gas plants). As such, each state’s goal is an emissions performance standard that reflects the fuel mix employed by the EGUs in operation in those states. The final rule provides guidelines to states to help develop their plans for meeting the interim (2022-2029) and final (2030 and beyond) emission performance standards, with three distinct compliance periods within that timeframe. States were originally required to submit their plans to EPA by September 2016, with an optional two-year extension provided to states establishing a need for additional time; however, it is expected that this timing will be impacted by the court-imposed stay described below.

Prior to the court-imposed stay described below, ADEQ, with input from a technical working group comprised of Arizona utilities and other stakeholders, was working to develop a compliance plan for submittal to EPA. Since the imposition of the stay, ADEQ reports that it is continuing to assess its options while completing outreach and soliciting feedback from stakeholders. In addition to these on-going state proceedings, EPA has taken public comments on proposed model rules and a proposed federal compliance plan, which included consideration as to how the Clean Power Plan will apply to EGUs on tribal land such as the Navajo Nation.

The legality of the Clean Power Plan is being challenged in the U.S. Court of Appeals for the D.C. Circuit; the parties raising this challenge include, among others, the ACC. On February 9, 2016, the U.S. Supreme Court granted a stay of the Clean Power Plan pending judicial review of the rule, which temporarily delays compliance obligations under the Clean Power Plan. We cannot predict the extent of such a delay.

With respect to our Arizona generating units, we are currently evaluating the range of compliance options available to ADEQ, including whether Arizona deploys a rate- or mass-based compliance plan. Based on the fuel-mix and location of our Arizona EGUs, and the significant investments we have made in renewable generation and demand-side energy efficiency, if ADEQ selects a rate-based compliance plan, we believe that we will be able to comply with the Clean Power Plan for our Arizona generating units in a manner that will not have material financial or operational impacts to the Company. On the other hand, if ADEQ selects a mass-based approach to compliance with the Clean Power Plan, our annual cost of compliance could be material. These costs could include costs to acquire mass-based compliance allowances.

As to our facilities on the Navajo Nation, EPA has yet to determine whether or to what extent EGUs on the Navajo Nation will be required to comply with the Clean Power Plan. EPA has proposed to determine that it is necessary or appropriate to impose a federal plan on the Navajo Nation for compliance with the Clean Power Plan. In response, we filed comments with EPA advocating that such a federal plan is neither necessary

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nor appropriate to protect air quality on the Navajo Nation. If EPA reaches a determination that is consistent with our preferred approach for the Navajo Nation, we believe the Clean Power Plan will not have material financial or operational impacts on our operations within the Navajo Nation.

Alternatively, if EPA determines that a federal plan is necessary or appropriate for the Navajo Nation, and depending on our need for future operations at our EGUs located there, we may be unable to comply with the federal plan unless we acquire mass-based allowances or emission rate credits within established carbon trading markets, or curtail our operations. Subject to the uncertainties set forth below, and assuming that EPA establishes a federal plan for the Navajo Nation that requires carbon allowances or credits to be surrendered for plan compliance, it is possible we will be required to purchase some quantity of credits or allowances, the cost of which could be material.

Because ADEQ has not issued its plan for Arizona, and because we do not know whether EPA will decide to impose a plan or, if so, what that plan will require, there are a number of uncertainties associated with our potential cost exposure. These uncertainties include: whether judicial review will result in the Clean Power Plan being vacated in whole or in part or, if not, the extent of any resulting compliance deadline delays; whether any plan will be imposed for EGUs on the Navajo Nation; the future existence and liquidity of allowance or credit compliance trading markets; the applicability of existing contractual obligations with current and former owners of our participant-owned coal-fired EGUs; the type of federal or state compliance plan (either rate- or mass-based); whether or not the trading of allowances or credits will be authorized mechanisms for compliance with any final EPA or ADEQ plan; and how units that have been closed will be treated for allowance or credit allocation purposes.

In the event that the incurrence of compliance costs is not economically viable or prudent for our operations in Arizona or on the Navajo Nation, or if we do not have the option of acquiring allowances to account for the emissions from our operations, we may explore other options, including reduced levels of output, as an alternative to purchasing allowances. Given these uncertainties, our analysis of the available compliance options remains on-going, and additional information or considerations may arise that change our expectations.

Other environmental rules that could involve material compliance costs include those related to effluent limitations, the ozone national ambient air quality standard and other rules or matters involving the Clean Air Act, Clean Water Act, Endangered Species Act, the Navajo Nation, and water supplies for our power plants. The financial impact of complying with current and future environmental rules could jeopardize the economic viability of our coal plants or the willingness or ability of power plant participants to fund any required equipment upgrades or continue their participation in these plants. The economics of continuing to own certain resources, particularly our coal plants, may deteriorate, warranting early retirement of those plants, which may result in asset impairments. APS would seek recovery in rates for the book value of any remaining investments in the plants as well as other costs related to early retirement, but cannot predict whether it would obtain such recovery.

Federal Agency Environmental Lawsuit Related to Four Corners

On December 21, 2015, several environmental groups filed a notice of intent to sue with Office of Surface Mining Reclamation and Enforcement ("OSM") and other federal agencies under the Endangered Species Act (“ESA”) alleging that OSM’s reliance on the Biological Opinion and Incidental Take Statement prepared in connection with a federal environmental review were not in accordance with applicable law. The environmental review was undertaken as part of the United States Department of the Interior's ("DOI's") review process necessary to allow for the effectiveness of lease amendments and related rights-of-way

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renewals for Four Corners. This review process also required separate environmental impact evaluations under the National Environmental Policy Act (“NEPA”) and culminated in the issuance of a Record of Decision justifying the agency action extending the life of the plant and the adjacent mine.

On April 20, 2016, the same environmental groups followed through with their notice of intent to sue by filing a lawsuit against OSM and other federal agencies in the District of Arizona. Expanding upon the December 2015 ESA notice, the lawsuit alleges that these federal agencies violated both the ESA and NEPA in providing the federal approvals necessary to extend operations at the Four Corners Power Plant and the adjacent Navajo Mine past July 6, 2016. We are monitoring the proceedings and intend to request the right to intervene in the litigation. We cannot predict the outcome of this matter or its potential effect on Four Corners.

New Mexico Tax Matter

On May 23, 2013, the New Mexico Taxation and Revenue Department ("NMTRD") issued a notice of assessment for coal severance surtax, penalty, and interest totaling approximately $30 million related to coal supplied under the coal supply agreement for Four Corners (the "Assessment"). APS’s share of the Assessment is approximately $12 million. For procedural reasons, on behalf of the Four Corners co-owners, including APS, the coal supplier made a partial payment of the Assessment in the amount of $0.8 million and immediately filed a refund claim with respect to that partial payment in August 2013. The NMTRD denied the refund claim. On December 19, 2013, the coal supplier and APS, on its own behalf and as operating agent for Four Corners, filed a complaint with the New Mexico District Court contesting both the validity of the Assessment and the refund claim denial. On June 30, 2015, the court ruled that the Assessment was not valid and further ruled that APS and the other Four Corners co-owners receive a refund of all of the contested amounts previously paid under the applicable tax statute. The NMTRD filed an appeal of the decision on August 31, 2015.

On March 16, 2016, APS and the coal supplier entered into a final settlement agreement with the NMTRD with respect to the Assessment. Pursuant to the final settlement agreement, the NMTRD agreed to release the Assessment, dismiss its filed appeal, and release its rights to any other surtax claims with respect to the coal supply agreement. APS and the other Four Corners co-owners agreed to forgo refund rights with respect to all of the contested amounts previously paid under the applicable tax statute, as well as pay $1 million. APS's share of this settlement payment, together with its share of the partial payment described above is approximately $0.8 million.

Financial Assurances

In the normal course of business, we obtain standby letters of credit and surety bonds from financial institutions and other third parties. These instruments guarantee our own future performance and provide third parties with financial and performance assurance in the event we do not perform. These instruments support certain debt arrangements, commodity contract collateral obligations, and other transactions. As of March 31, 2016, standby letters of credit totaled $79 million and will expire in 2016. As of March 31, 2016, surety bonds expiring through 2018 totaled $150 million. The underlying liabilities insured by these instruments are reflected on our balance sheets, where applicable. Therefore, no additional liability is reflected for the letters of credit and surety bonds themselves.

We enter into agreements that include indemnification provisions relating to liabilities arising from or related to certain of our agreements. Most significantly, APS has agreed to indemnify the equity participants and other parties in the Palo Verde sale leaseback transactions with respect to certain tax matters. Generally, a maximum obligation is not explicitly stated in the indemnification provisions and, therefore, the overall

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maximum amount of the obligation under such indemnification provisions cannot be reasonably estimated. Based on historical experience and evaluation of the specific indemnities, we do not believe that any material loss related to such indemnification provisions is likely.

Pinnacle West has issued parental guarantees and has provided indemnification under certain surety bonds for APS which were not material at March 31, 2016.


8.	Other Income and Other Expense

The following table provides detail of Pinnacle West's Consolidated other income and other expense for the three months ended March 31, 2016 and 2015 (dollars in thousands):



	Three Months Ended March 31,
	2016			2015
Other income:
Interest income	$	117		$	110
Miscellaneous	—			125
Total other income	$	117		$	235
Other expense:
Non-operating costs	$	(2,049	)	$	(2,249	)
Investment losses — net	(518		)	(495		)
Miscellaneous	(1,471		)	(1,542		)
Total other expense	$	(4,038	)	$	(4,286	)

The following table provides detail of APS’s other income and other expense for the three months ended March 31, 2016 and 2015 (dollars in thousands):



	Three Months Ended March 31,
	2016			2015
Other income:
Interest income	$	73		$	67
Gain on disposition of property	332			207
Miscellaneous	205			365
Total other income	$	610		$	639
Other expense:
Non-operating costs (a)	$	(1,966	)	$	(2,517	)
Loss on disposition of property	(426		)	(643		)
Miscellaneous	(2,358		)	(2,194		)
Total other expense	$	(4,750	)	$	(5,354	)

(a) As defined by FERC, includes below-the-line non-operating utility expense (items excluded from utility rate recovery).

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9.	Earnings Per Share

The following table presents the calculation of Pinnacle West’s basic and diluted earnings per share for the three months ended March 31, 2016 and 2015 (in thousands, except per share amounts):



	Three Months Ended March 31,
	2016		2015
Net income attributable to common shareholders	$	4,453	$	16,122
Weighted average common shares outstanding — basic	111,296		110,916
Net effect of dilutive securities:
Contingently issuable performance shares and restricted stock units	551		461
Weighted average common shares outstanding — diluted	111,847		111,377
Earnings per weighted-average common share outstanding
Net income attributable to common shareholders — basic	$	0.04	$	0.15
Net income attributable to common shareholders — diluted	$	0.04	$	0.14


10.	Fair Value Measurements

We classify our assets and liabilities that are carried at fair value within the fair value hierarchy. This hierarchy ranks the quality and reliability of the inputs used to determine fair values, which are then classified and disclosed in one of three categories. The three levels of the fair value hierarchy are:

Level 1 — Unadjusted quoted prices in active markets for identical assets or liabilities that we have the ability to access at the measurement date. Active markets are those in which transactions for the asset or liability occur in sufficient frequency and volume to provide information on an ongoing basis. This category includes exchange traded equities, exchange traded derivative instruments, exchange traded mutual funds, cash equivalents, and investments in U.S. Treasury securities.

Level 2 — Utilizes quoted prices in active markets for similar assets or liabilities; quoted prices in markets that are not active; and model-derived valuations whose inputs are observable (such as yield curves). This category includes non-exchange traded contracts such as forwards, options, swaps and certain investments in fixed income securities.

Level 3 — Valuation models with significant unobservable inputs that are supported by little or no market activity. Instruments in this category include long-dated derivative transactions where valuations are unobservable due to the length of the transaction, options, and transactions in locations where observable market data does not exist. The valuation models we employ utilize spot prices, forward prices, historical market data and other factors to forecast future prices.

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We assess whether a market is active by obtaining observable broker quotes, reviewing actual market activity, and assessing the volume of transactions. We consider broker quotes observable inputs when the quote is binding on the broker, we can validate the quote with market activity, or we can determine that the inputs the broker used to arrive at the quoted price are observable.

Certain instruments have been valued using the concept of Net Asset Value (“NAV”), as a practical expedient. These instruments are typically structured as investment companies offering shares or units to multiple investors for the purpose of providing a return. These instruments are similar to mutual funds; however, they are not traded on an exchange. During the first quarter of 2016 we retrospectively adopted new accounting guidance that requires instruments valued using NAV, as a practical expedient, to no longer be classified within the fair value hierarchy. As such, instruments valued using NAV, as a practical expedient, are included in our fair value disclosures and tables in a separate column; however, these investments are not classified within any of the fair value hierarchy levels. Prior to the adoption of this guidance these instruments were typically reported within Level 2 or Level 3. The adoption of this guidance changes our fair value disclosures, but does not impact the methodology for valuing these instruments, or our financial statement results.

Recurring Fair Value Measurements

We apply recurring fair value measurements to certain cash equivalents, derivative instruments, investments held in our nuclear decommissioning trust and plan assets held in our retirement and other benefit plans. See Note 7 in the 2015 Form 10-K for the fair value discussion of plan assets held in our retirement and other benefit plans.

Cash Equivalents

Cash equivalents represent short-term investments with original maturities of three months or less in exchange traded money market funds that are valued using quoted prices in active markets.

Risk Management Activities — Derivative Instruments

Exchange traded commodity contracts are valued using unadjusted quoted prices. For non-exchange traded commodity contracts, we calculate fair value based on the average of the bid and offer price, discounted to reflect net present value. We maintain certain valuation adjustments for a number of risks associated with the valuation of future commitments. These include valuation adjustments for liquidity and credit risks. The liquidity valuation adjustment represents the cost that would be incurred if all unmatched positions were closed out or hedged. The credit valuation adjustment represents estimated credit losses on our net exposure to counterparties, taking into account netting agreements, expected default experience for the credit rating of the counterparties and the overall diversification of the portfolio. We maintain credit policies that management believes minimize overall credit risk.

Certain non-exchange traded commodity contracts are valued based on unobservable inputs due to the long-term nature of contracts, characteristics of the product, or the unique location of the transactions. Our long-dated energy transactions consist of observable valuations for the near-term portion and unobservable valuations for the long-term portions of the transaction. We rely primarily on broker quotes to value these instruments. When our valuations utilize broker quotes, we perform various control procedures to ensure the quote has been developed consistent with fair value accounting guidance. These controls include assessing the quote for reasonableness by comparison against other broker quotes, reviewing historical price relationships, and assessing market activity. When broker quotes are not available, the primary valuation technique used to

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calculate the fair value is the extrapolation of forward pricing curves using observable market data for more liquid delivery points in the same region and actual transactions at more illiquid delivery points.

Option contracts are primarily valued using a Black-Scholes option valuation model, which utilizes both observable and unobservable inputs such as broker quotes, interest rates and price volatilities.

When the unobservable portion is significant to the overall valuation of the transaction, the entire transaction is classified as Level 3. Our classification of instruments as Level 3 is primarily reflective of the long-term nature of our energy transactions and the use of option valuation models with significant unobservable inputs.

Our energy risk management committee, consisting of officers and key management personnel, oversees our energy risk management activities to ensure compliance with our stated energy risk management policies. We have a risk control function that is responsible for valuing our derivative commodity instruments in accordance with established policies and procedures. The risk control function reports to the chief financial officer’s organization.

Investments Held in our Nuclear Decommissioning Trust

The nuclear decommissioning trust invests in fixed income securities and equity securities. Equity securities are held indirectly through commingled funds. The commingled funds are valued using the funds' NAV as a practical expedient. The funds' NAV is primarily derived from the quoted active market prices of the underlying equity securities held by the funds. We may transact in these commingled funds on a semi-monthly basis at the NAV. The commingled funds are maintained by a bank and hold investments in accordance with the stated objective of tracking the performance of the S&P 500 Index. Because the commingled funds' shares are offered to a limited group of investors, they are not considered to be traded in an active market. As these instruments are valued using NAV, as a practical expedient, they have not been classified within the fair value hierarchy.

Cash equivalents reported within Level 1 represent investments held in a short-term investment exchange-traded mutual fund, which invests in certificates of deposit, variable rate notes, time deposit accounts, U.S. Treasury and Agency obligations, U.S. Treasury repurchase agreements, and commercial paper.

Fixed income securities issued by the U.S. Treasury held directly by the nuclear decommissioning trust are valued using quoted active market prices and are typically classified as Level 1. Fixed income securities issued by corporations, municipalities, and other agencies, including mortgage-backed instruments, are valued using quoted inactive market prices, quoted active market prices for similar securities, or by utilizing calculations which incorporate observable inputs such as yield curves and spreads relative to such yield curves. These instruments are classified as Level 2. Whenever possible, multiple market quotes are obtained which enables a cross-check validation. A primary price source is identified based on asset type, class, or issue of securities.

We price securities using information provided by our trustee for our nuclear decommissioning trust assets. Our trustee uses pricing services that utilize the valuation methodologies described to determine fair market value. We have internal control procedures designed to ensure this information is consistent with fair value accounting guidance. These procedures include assessing valuations using an independent pricing source, verifying that pricing can be supported by actual recent market transactions, assessing hierarchy classifications, comparing investment returns with benchmarks, and obtaining and reviewing independent audit

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reports on the trustee’s internal operating controls and valuation processes. See Note 11 for additional discussion about our nuclear decommissioning trust.

Fair Value Tables

The following table presents the fair value at March 31, 2016, of our assets and liabilities that are measured at fair value on a recurring basis (dollars in thousands):



	Quoted Prices in Active Markets for Identical Assets (Level 1)		Significant Other Observable Inputs (Level 2)			Significant Unobservable Inputs (a) (Level 3)			Other				Balance at March 31, 2016
Assets
Risk management activities — derivative instruments:
Commodity contracts	$	—	$	12,613		$	23,847		$	(11,759	)	(b)	$	24,701
Nuclear decommissioning trust:
U.S. commingled equity funds	—		—			—			319,971			(c)	319,971
Fixed income securities:
Cash and cash equivalent funds	11,535		—			—			(1,898		)	(d)	9,637
U.S. Treasury	107,698		—			—			—				107,698
Corporate debt	—		101,687			—			—				101,687
Mortgage-backed securities	—		109,298			—			—				109,298
Municipal bonds	—		80,344			—			—				80,344
Other	—		23,319			—			—				23,319
Subtotal nuclear decommissioning trust	119,233		314,648			—			318,073				751,954
Total	$	119,233	$	327,261		$	23,847		$	306,314			$	776,655
Liabilities
Risk management activities — derivative instruments:
Commodity contracts	$	—	$	(140,554	)	$	(63,354	)	$	25,022		(b)	$	(178,886	)


(a)	Primarily consists of heat rate options and other long-dated electricity contracts.


(b)	Represents counterparty netting, margin and collateral. See Note 6.


(c)	Valued using NAV as a practical expedient, and therefore not classified in the fair value hierarchy.


(d)	Represents nuclear decommissioning trust net pending securities sales and purchases.

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The following table presents the fair value at December 31, 2015, of our assets and liabilities that are measured at fair value on a recurring basis (dollars in thousands):



	Quoted Prices in Active Markets for Identical Assets (Level 1)		Significant Other Observable Inputs (Level 2)			Significant Unobservable Inputs (a) (Level 3)			Other				Balance at December 31, 2015
Assets
Risk management activities — derivative instruments:
Commodity contracts	$	—	$	22,992		$	30,364		$	(25,345	)	(b)	$	28,011
Nuclear decommissioning trust:
U.S. commingled equity funds	—		—			—			314,957			(c)	314,957
Fixed income securities:
Cash and cash equivalent funds	12,260		—			—			(335		)	(d)	11,925
U.S. Treasury	117,245		—			—			—				117,245
Corporate debt	—		96,243			—			—				96,243
Mortgage-backed securities	—		99,065			—			—				99,065
Municipal bonds	—		72,206			—			—				72,206
Other	—		23,555			—			—				23,555
Subtotal nuclear decommissioning trust	129,505		291,069			—			314,622				735,196
Total	$	129,505	$	314,061		$	30,364		$	289,277			$	763,207
Liabilities
Risk management activities — derivative instruments:
Commodity contracts	$	—	$	(144,044	)	$	(63,343	)	$	39,698		(b)	$	(167,689	)


(a)	Primarily consists of heat rate options and other long-dated electricity contracts.


(b)	Represents counterparty netting, margin and collateral. See Note 6.


(c)	Valued using NAV as a practical expedient, and therefore not classified in the fair value hierarchy.


(d)	Represents nuclear decommissioning trust net pending securities sales and purchases.

Fair Value Measurements Classified as Level 3

The significant unobservable inputs used in the fair value measurement of our energy derivative contracts include broker quotes that cannot be validated as an observable input primarily due to the long-term nature of the quote and option model inputs. Significant changes in these inputs in isolation would result in significantly higher or lower fair value measurements. Changes in our derivative contract fair values, including changes relating to unobservable inputs, typically will not impact net income due to regulatory accounting treatment (see Note 3).

Because our forward commodity contracts classified as Level 3 are currently in a net purchase position, we would expect price increases of the underlying commodity to result in increases in the net fair value of the related contracts. Conversely, if the price of the underlying commodity decreases, the net fair value of the related contracts would likely decrease.

COMBINED NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

Our option contracts classified as Level 3 primarily relate to purchase heat rate options. The significant unobservable inputs at March 31, 2016 for these instruments include electricity prices, and volatilities. The significant unobservable inputs at December 31, 2015 for these instruments include electricity prices, gas prices and volatilities. If electricity prices and electricity price volatilities increase, we would expect the fair value of these options to increase, and if these valuation inputs decrease, we would expect the fair value of these options to decrease. If natural gas prices and natural gas price volatilities increase, we would expect the fair value of these options to decrease, and if these inputs decrease, we would expect the fair value of the options to increase. The commodity prices and volatilities do not always move in corresponding directions. The options’ fair values are impacted by the net changes of these various inputs.

Other unobservable valuation inputs include credit and liquidity reserves which do not have a material impact on our valuations; however, significant changes in these inputs could also result in higher or lower fair value measurements.

The following tables provide information regarding our significant unobservable inputs used to value our risk management derivative Level 3 instruments at March 31, 2016 and December 31, 2015:



	March 31, 2016 Fair Value (thousands)				Valuation Technique	Significant Unobservable Input		Weighted-Average
Commodity Contracts	Assets		Liabilities		Valuation Technique	Significant Unobservable Input	Range	Weighted-Average
Electricity:
Forward Contracts (a)	$	21,606	$	51,305	Discounted cash flows	Electricity forward price (per MWh)	$13.97 - $39.61	$	26.45
Option Contracts (b)	—		5,880		Option model	Electricity forward price (per MWh)	$19.46 - $37.93	$	29.39
						Electricity price volatilities	47% - 72%	63		%
						Natural gas price volatilities	38% - 45%	41		%
Natural Gas:
Forward Contracts (a)	2,241		6,169		Discounted cash flows	Natural gas forward price (per MMBtu)	$1.65 - $3.11	$	2.67
Total	$	23,847	$	63,354


(a)	Includes swaps and physical and financial contracts.


(b)	Electricity and natural gas price volatilities are estimated based on historical forward price movements due to lack of market quotes for implied volatilities.

COMBINED NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS



	December 31, 2015 Fair Value (thousands)				Valuation Technique	Significant Unobservable Input		Weighted-Average
Commodity Contracts	Assets		Liabilities		Valuation Technique	Significant Unobservable Input	Range	Weighted-Average
Electricity:
Forward Contracts (a)	$	24,543	$	54,679	Discounted cash flows	Electricity forward price (per MWh)	$15.92 - $40.73	$	26.86
Option Contracts (b)	—		5,628		Option model	Electricity forward price (per MWh)	$23.87 - $44.13	$	33.91
						Electricity price volatilities	40% - 59%	52		%
						Natural gas price volatilities	32% - 40%	35		%
Natural Gas:
Forward Contracts (a)	5,821		3,036		Discounted cash flows	Natural gas forward price (per MMBtu)	$2.18 - $3.14	$	2.61
Total	$	30,364	$	63,343


(a)	Includes swaps and physical and financial contracts.


(b)	Electricity and natural gas price volatilities are estimated based on historical forward price movements due to lack of market quotes for implied volatilities.

The following table shows the changes in fair value for our risk management activities' assets and liabilities that are measured at fair value on a recurring basis using Level 3 inputs for the three months ended March 31, 2016 and 2015 (dollars in thousands):



	Three Months Ended March 31,
Commodity Contracts	2016			2015
Net derivative balance at beginning of period	$	(32,979	)	$	(41,386	)
Total net gains (losses) realized/unrealized:
Included in OCI	—			(262		)
Deferred as a regulatory asset or liability	(9,103		)	(10,747		)
Settlements	1,765			310
Transfers into Level 3 from Level 2	262			(402		)
Transfers from Level 3 into Level 2	548			3,673
Net derivative balance at end of period	$	(39,507	)	$	(48,814	)

Net unrealized gains included in earnings related to instruments still held at end of period	$	—		$	—

Amounts included in earnings are recorded in either operating revenues or fuel and purchased power depending on the nature of the underlying contract.

COMBINED NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

other hierarchy level. Transfers in or out of Level 3 are typically related to our long-dated energy transactions that extend beyond available quoted periods.

Financial Instruments Not Carried at Fair Value

The carrying value of our net accounts receivable, accounts payable and short-term borrowings approximate fair value. Our short-term borrowings are classified within Level 2 of the fair value hierarchy. See Note 2 for our long-term debt fair values.


11.	Nuclear Decommissioning Trusts

To fund the costs APS expects to incur to decommission Palo Verde, APS established external decommissioning trusts in accordance with NRC regulations. Third-party investment managers are authorized to buy and sell securities per stated investment guidelines. The trust funds are invested in fixed income securities and equity securities. APS classifies investments in decommissioning trust funds as available for sale. As a result, we record the decommissioning trust funds at their fair value on our Condensed Consolidated Balance Sheets. See Note 10 for a discussion of how fair value is determined and the classification of the nuclear decommissioning trust investments within the fair value hierarchy. Because of the ability of APS to recover decommissioning costs in rates and in accordance with the regulatory treatment for decommissioning trust funds, we have deferred realized and unrealized gains and losses (including other-than-temporary impairments on investment securities) in other regulatory liabilities. The following table includes the unrealized gains and losses based on the original cost of the investment and summarizes the fair value of APS’s nuclear decommissioning trust fund assets at March 31, 2016 and December 31, 2015 (dollars in thousands):



	Fair Value			Total Unrealized Gains		Total Unrealized Losses
March 31, 2016
Equity securities	$	319,971		$	159,790	$	(65	)
Fixed income securities	433,881			18,250		(676		)
Net payables (a)	(1,898		)	—		—
Total	$	751,954		$	178,040	$	(741	)



	Fair Value			Total Unrealized Gains		Total Unrealized Losses
December 31, 2015
Equity securities	$	314,957		$	157,098	$	(115	)
Fixed income securities	420,574			11,955		(2,645		)
Net payables (a)	(335		)	—		—
Total	$	735,196		$	169,053	$	(2,760	)


(a)	Net payables relate to pending purchases and sales of securities.

COMBINED NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

The costs of securities sold are determined on the basis of specific identification. The following table sets forth approximate gains and losses and proceeds from the sale of securities by the nuclear decommissioning trust funds (dollars in thousands):



	Three Months Ended March 31,
	2016			2015
Realized gains	$	2,438		$	1,195
Realized losses	(1,786		)	(525		)
Proceeds from the sale of securities (a)	141,809			115,282


(a)	Proceeds are reinvested in the trust.

The fair value of fixed income securities, summarized by contractual maturities, at March 31, 2016 is as follows (dollars in thousands):



	Fair Value
Less than one year	$	11,633
1 year – 5 years	126,221
5 years – 10 years	101,773
Greater than 10 years	194,254
Total	$	433,881

12. New Accounting Standards

In May 2014, a new revenue recognition accounting standard was issued. This standard provides a single comprehensive model for entities to use in accounting for revenue arising from contracts with customers and supersedes most current revenue recognition guidance. The new revenue standard will be effective for us on January 1, 2018. The guidance may be adopted using a full retrospective application or a simplified transition method that allows entities to record a cumulative effect adjustment in retained earnings at the date of initial application. We are currently evaluating this new standard and the impacts it may have on our financial statements.

In January 2016, a new accounting standard was issued relating to the recognition and measurement of financial instruments. The new guidance will require certain investments in equity securities to be measured at fair value with changes in fair value recognized in net income, and modifies the impairment assessment of certain equity securities. The new guidance is effective for us on January 1, 2018. Certain aspects of the guidance may require a cumulative-effect adjustment and other aspects of the guidance are required to be adopted prospectively. We are currently evaluating this new accounting standard and the impacts it may have on our financial statements.

In February 2016, a new lease accounting standard was issued. This new standard supersedes the existing lease accounting model, and modifies both lessee and lessor accounting. The new guidance will require a lessee to reflect most operating lease arrangements on the balance sheet by recording a right-of-use asset and a lease liability that will initially be measured at the present value of lease payments. Among other changes, the new standard also modifies the definition of a lease, and requires expanded lease disclosures. The new standard will be effective for us on January 1, 2019, with early application permitted. The guidance must be adopted using a modified retrospective approach, with various optional practical expedients provided to

COMBINED NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

facilitate transition. We are currently evaluating this new accounting standard and the impacts it may have on our financial statements.

In March 2016, new stock compensation accounting guidance was issued that modifies the accounting for employee share-based payments. The new guidance will require all tax benefits and deficiencies arising from share-based payments to be recognized in net income, modifies the tax withholding threshold for awards to qualify for equity classification, simplifies accounting for forfeitures, and clarifies certain cash flow presentation matters. The new guidance is effective for us on January 1, 2017, with early application permitted. Certain aspects of the guidance must be adopted using a prospective approach and other aspects will be adopted using a retrospective approach. We are currently evaluating this new accounting standard and the impacts it may have on our financial statements.

In February 2015, new consolidation accounting guidance was issued that amends many aspects of the guidance relating to the analysis and consolidation of variable interest entities. We adopted this new guidance during the first quarter of 2016. The adoption did not impact our financial statements.

13. Changes in Accumulated Other Comprehensive Loss

The following table shows the changes in Pinnacle West's consolidated accumulated other comprehensive loss, including reclassification adjustments, net of tax, by component for the three months ended March 31, 2016 and 2015 (dollars in thousands):



	Three Months Ended
	March 31,
	2016			2015
Balance at beginning of period	$	(44,748	)	$	(68,141	)
Derivative Instruments
OCI (loss) before reclassifications	(693		)	(800		)
Amounts reclassified from accumulated other comprehensive loss (a)	1,141			1,976
Net current period OCI (loss)	448			1,176
Pension and Other Postretirement Benefits
Amounts reclassified from accumulated other comprehensive loss (b)	530			583
Net current period OCI (loss)	530			583
Balance at end of period	$	(43,770	)	$	(66,382	)


(a)	These amounts represent realized gains and losses and are included in the computation of fuel and purchased power costs and are subject to the PSA. See Note 6.


(b)	These amounts primarily represent amortization of actuarial loss, and are included in the computation of net periodic pension cost. See Note 4.

COMBINED NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

The following table shows the changes in APS's consolidated accumulated other comprehensive loss, including reclassification adjustments, net of tax, by component for the three months ended March 31, 2016 and 2015 (dollars in thousands):



	Three Months Ended
	March 31,
	2016			2015
Balance at beginning of period	$	(27,097	)	$	(48,333	)
Derivative Instruments
OCI (loss) before reclassifications	(693		)	(800		)
Amounts reclassified from accumulated other comprehensive loss (a)	1,141			1,976
Net current period OCI (loss)	448			1,176
Pension and Other Postretirement Benefits
Amounts reclassified from accumulated other comprehensive loss (b)	611			681
Net current period OCI (loss)	611			681
Balance at end of period	$	(26,038	)	$	(46,476	)


(a)	These amounts represent realized gains and losses and are included in the computation of fuel and purchased power costs and are subject to the PSA. See Note 6.


(b)	These amounts primarily represent amortization of actuarial loss and are included in the computation of net periodic pension cost. See Note 4.

ITEM 2. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS

INTRODUCTION

The following discussion should be read in conjunction with Pinnacle West’s Condensed Consolidated Financial Statements and APS’s Condensed Consolidated Financial Statements and the related Notes that appear in Item 1 of this report. For information on factors that may cause our actual future results to differ from those we currently seek or anticipate, see "Forward-Looking Statements" at the front of this report and "Risk Factors" in Part 1, Item 1A of the 2015 Form 10-K.

OVERVIEW

Pinnacle West owns all of the outstanding common stock of APS. APS is a vertically-integrated electric utility that provides either retail or wholesale electric service to most of the state of Arizona, with the major exceptions of about one-half of the Phoenix metropolitan area, the Tucson metropolitan area and Mohave County in northwestern Arizona. APS currently accounts for essentially all of our revenues and earnings.

Areas of Business Focus

Operational Performance, Reliability and Recent Developments.

Nuclear. APS operates and is a joint owner of Palo Verde. The March 2011 earthquake and tsunamis in Japan and the resulting accident at Japan’s Fukushima Daiichi nuclear power station had a significant impact on nuclear power operators worldwide. In the aftermath of the accident, the NRC conducted an independent assessment to consider actions to address lessons learned from the Fukushima events. The independent assessment, named the "Near Term Task Force," recommended a number of proposed enhancements to U.S. commercial nuclear power plant equipment and emergency plans. The NRC has directed nuclear power plants to begin implementing some of the Near Term Task Force’s recommendations. Palo Verde has met the NRC's imposed deadlines for installation of equipment to address these requirements, and has minor additional work to perform in 2016. To implement these recommendations, Palo Verde has spent approximately $125 million on capital enhancements as of March 31, 2016 (APS’s share is 29.1%).

Coal and Related Environmental Matters and Transactions. APS is a joint owner of three coal-fired power plants and acts as operating agent for two of the plants. APS is focused on the impacts on its coal fleet that may result from increased regulation and potential legislation concerning GHG emissions. On June 2, 2014, EPA proposed a rule to limit carbon dioxide emissions from existing power plants (the "Clean Power Plan"), and EPA finalized its proposal on August 3, 2015.

EPA’s nationwide CO₂ emissions reduction goal is 32% below 2005 emission levels. As finalized for the state of Arizona and the Navajo Nation, compliance with the Clean Power Plan could involve a shift in generation from coal to natural gas and renewable generation. Until implementation plans for these jurisdictions are finalized, we are unable to determine the actual impacts to APS. APS continually analyzes its long-range capital management plans to assess the potential effects of these changes, understanding that any resulting regulation and legislation could impact the economic viability of certain plants, as well as the willingness or ability of power plant participants to continue participation in such plants.

Cholla

On September 11, 2014, APS announced that it would close its 260 MW Unit 2 at Cholla and cease burning coal at Units 1 and 3 by the mid-2020s if EPA approves a compromise proposal offered by APS to

meet required environmental and emissions standards and rules. On April 14, 2015, the ACC approved APS's plan to retire Unit 2, without expressing any view on the future recoverability of APS's remaining investment in the Unit. (See Note 3 for details related to the resulting regulatory asset and Note 7 for details of the proposal.) APS believes that the environmental benefits of this proposal are greater in the long term than the benefits that would have resulted from adding emissions control equipment. APS closed Unit 2 on October 1, 2015.

Four Corners

Asset Purchase Agreement and Coal Supply Matters. On December 30, 2013, APS purchased SCE’s 48% interest in each of Units 4 and 5 of Four Corners. The final purchase price for the interest was approximately $182 million. In connection with APS’s most recent retail rate case with the ACC, the ACC reserved the right to review the prudence of the Four Corners transaction for cost recovery purposes upon the closing of the transaction. On December 23, 2014, the ACC approved rate adjustments related to APS’s acquisition of SCE’s interest in Four Corners resulting in a revenue increase of $57.1 million on an annual basis. On February 23, 2015, the ACC decision approving the rate adjustments was appealed. APS has intervened and is actively participating in the proceeding. The Arizona Court of Appeals has suspended the appeal pending the Arizona Supreme Court's decision in the SIB matter discussed below, which could have an effect on the outcome of this Four Corners proceeding. We cannot predict when or how this matter will be resolved.

Concurrently with the closing of the SCE transaction, BHP Billiton, the parent company of BNCC, the coal supplier and operator of the mine that serves Four Corners, transferred its ownership of BNCC to NTEC, a company formed by the Navajo Nation to own the mine and develop other energy projects. BHP Billiton will be retained by NTEC under contract as the mine manager and operator until July 2016. Also occurring concurrently with the closing, the Four Corners’ co-owners executed the 2016 Coal Supply Agreement for the supply of coal to Four Corners from July 2016, when the current coal supply agreement expires, through 2031. El Paso, a 7% owner in Units 4 and 5 of Four Corners, did not sign the 2016 Coal Supply Agreement. Under the 2016 Coal Supply Agreement, APS has agreed to assume the 7% shortfall obligation. On February 17, 2015, APS and El Paso entered into an asset purchase agreement providing for the purchase by APS, or an affiliate of APS, of El Paso’s 7% interest in each of Units 4 and 5 of Four Corners. The cash purchase price, which will be subject to certain adjustments at closing, is immaterial in amount, and the purchaser will assume El Paso's reclamation and decommissioning obligations associated with the 7% interest. Completion of the purchase is subject to the receipt of certain regulatory approvals and is expected to occur in July 2016.

When APS, or an affiliate of APS, ultimately acquires El Paso's interest in Four Corners, NTEC has the option to purchase the interest within a certain timeframe pursuant to an option granted by APS to NTEC. On December 29, 2015, NTEC notified APS of its intent to exercise the option. APS is negotiating a definitive purchase agreement with NTEC for the purchase by NTEC of the 7% interest. The 2016 Coal Supply Agreement contains alternate pricing terms for the 7% shortfall obligations in the event NTEC does not purchase the interest.

Lease Extension. APS, on behalf of the Four Corners participants, negotiated amendments to an existing facility lease with the Navajo Nation, which extends the Four Corners leasehold interest from 2016 to 2041. The Navajo Nation approved these amendments in March 2011. The effectiveness of the amendments also required the approval of the DOI, as did a related federal rights-of-way grant. A federal environmental review was undertaken as part of the DOI review process, and culminated in the issuance by DOI of a record of decision on July 17, 2015 justifying the agency action extending the life of the plant and the adjacent mine.

On April 20, 2016, several environmental groups filed a lawsuit against OSM and other federal agencies in the District of Arizona. The lawsuit alleges that these federal agencies violated both the ESA and

NEPA in providing the federal approvals necessary to extend operations at the Four Corners Power Plant and the adjacent Navajo Mine past July 6, 2016. We are monitoring the proceedings and intend to request the right to intervene in the litigation. We cannot predict the outcome of this matter or its potential effect on Four Corners.

Natural Gas. APS has six natural gas power plants located throughout Arizona, including Ocotillo. Ocotillo is a 330 MW 4-unit gas plant located in the metropolitan Phoenix area. In early 2014, APS announced a project to modernize the plant, which involves retiring two older 110 MW steam units, adding five 102 MW combustion turbines and maintaining two existing 55 MW combustion turbines. In total, this increases the capacity of the site by 290 MW, to 620 MW, with completion targeted by summer 2019. APS completed a competitive solicitation process in which the Ocotillo project was evaluated against other alternatives. Consistent with the independent monitor’s report, the Ocotillo project was selected as the best alternative. APS must finalize the permitting process, including any EPA Environmental Appeals Board ("EAB") reviews, before construction can begin. On April 21, 2016, the Sierra Club filed a petition with the EAB to review the Prevention of Significant Deterioration permit issued by Maricopa County, Arizona for the Ocotillo project. We will participate in the proceeding and expect a decision to be rendered by the EAB by the end of 2016. If the permit is upheld by the EAB, we do not expect a delay in the construction schedule for the project.

Transmission and Delivery. APS is working closely with regulators to identify and plan for transmission needs that continue to support system reliability, access to markets and renewable energy development. The capital expenditures table presented in the "Liquidity and Capital Resources" section below includes new APS transmission projects through 2018, along with other transmission costs for upgrades and replacements. APS is also working to establish and expand advanced grid technologies throughout its service territory to provide long-term benefits both to APS and its customers. APS is strategically deploying a variety of technologies that are intended to allow customers to better monitor their energy use and needs, minimize system outage durations, as well as the number of customers that experience outages, and facilitate greater cost savings to APS through improved reliability and the automation of certain distribution functions, including remote meter reading and remote connects and disconnects.

Renewable Energy. The ACC approved the RES in 2006. The renewable energy requirement is 6% of retail electric sales in 2016 and increases annually until it reaches 15% in 2025. In the 2009 Settlement Agreement, APS agreed to exceed the RES standards, committing to use APS’s best efforts to obtain 1,700 GWh of new renewable resources to be in service by year-end 2015, in addition to its RES renewable resource commitments. APS met its settlement commitment and RES target for 2015. Taken together, APS's commitment to renewable energy is currently estimated to be at least 12% of APS's estimated retail energy sales by year-end 2016, which is double the existing RES target of 6% for that year. APS believes that it will meet this commitment. A component of the RES targets development of distributed energy systems.

On July 1, 2015, APS filed its 2016 RES implementation plan and proposed a RES budget of approximately $148 million. On January 12, 2016, the ACC approved APS’s plan and requested budget.

The following table summarizes renewable energy sources in APS's renewable portfolio that are in operation and under development as of April 29, 2016.



	Net Capacity in Operation (MW)	Net Capacity Planned / Under Development (MW)
Total APS Owned: Solar (a)	189	49 (c)
Purchased Power Agreements:
Solar	310	—
Wind	289	—
Geothermal	10	—
Biomass	14	—
Biogas	6	—
Total Purchased Power Agreements	629	—
Total Distributed Energy: Solar (b)	484	39 (d)
Total Renewable Portfolio	1,302	88

(a) Included in the 189 MW number is 170 MW of solar resources procured through the AZ Sun Program.

(b) Includes rooftop solar facilities owned by third parties. Distributed generation is produced in DC and is converted to AC for reporting purposes.


(c)	This amount represents APS-owned grid scale and distributed generation projects currently under development. Projects include the 40 MW Red Rock Solar Plant and the Solar Partner Program. Upon completion of construction, these projects will be considered "in operation" for purposes of this table.


(d)	Applications received by APS that are not yet installed and online.

APS has developed owned solar resources through the ACC-approved AZ Sun Program. APS has invested approximately $675 million in its AZ Sun Program.

In accordance with the ACC’s decision on the 2014 RES plan, on April 15, 2014, APS filed an application with the ACC requesting permission to build an additional 20 MW of APS-owned grid scale solar under the AZ Sun Program. In a subsequent filing, APS also offered an alternative proposal to replace the 20 MW of grid scale solar with 10 MW (approximately 1,500 customers) of APS-owned residential solar that will not be under the AZ Sun Program. On December 19, 2014, the ACC voted that it had no objection to APS implementing its residential rooftop solar program. The first stage of the residential rooftop solar program, called the "Solar Partner Program", is to be 8 MW followed by a 2 MW second stage that will only be deployed if coupled with distributed storage. The program will target specific distribution feeders in an effort to maximize potential system benefits, as well as make systems available to limited-income customers who cannot easily install solar through transactions with third parties. The ACC expressly reserved that any determination of prudency of the residential rooftop solar program for rate making purposes shall not be made until the project is fully in service and APS requests cost recovery in a future rate case.

Demand Side Management. In December 2009, Arizona regulators placed an increased focus on energy efficiency and other demand side management programs to encourage customers to conserve energy, while incentivizing utilities to aid in these efforts that ultimately reduce the demand for energy. The ACC initiated an Energy Efficiency rulemaking, with a proposed Energy Efficiency Standard of 22% cumulative annual energy savings by 2020. The 22% figure represents the cumulative reduction in future energy usage through 2020 attributable to energy efficiency initiatives. This standard became effective on January 1, 2011.

In March 2014 the ACC approved a Resource Savings Initiative that allows APS to count towards compliance with the ACC Electric Energy Efficiency Standards, savings from improvements to APS’s transmission and delivery system, generation and facilities that have been approved through a DSM Plan.

On March 20, 2015, APS filed an application with the ACC requesting a budget of $68.9 million for 2015 and minor modifications to its DSM portfolio going forward, including for the first time three resource savings projects which reflect energy savings on APS's system. The ACC approved APS’s 2015 DSM budget on November 25, 2015. In its decision, the ACC also approved that verified energy savings from APS’s resource savings projects could be counted toward compliance with the Electric Energy Efficiency Standard, however, the ACC ruled that APS was not allowed to count savings from systems savings projects toward determination of its achievement tier level for its performance incentive, nor may APS include savings from conservation voltage reduction in the calculation of its LFCR mechanism.

On November 4, 2014, the ACC staff issued a request for informal comment on a draft of possible amendments to Arizona’s Electric Utility Energy Efficiency Standards. The draft proposed substantial changes to the rules and energy efficiency standards. The ACC accepted written comments and took public comment regarding the possible amendments on December 19, 2014. A formal rulemaking has not been initiated and there has been no additional action on the draft to date.

Rate Matters. APS needs timely recovery through rates of its capital and operating expenditures to maintain its financial health. APS’s retail rates are regulated by the ACC and its wholesale electric rates (primarily for transmission) are regulated by FERC. On June 1, 2011, APS filed a rate case with the ACC. APS and other parties to the retail rate case subsequently entered into the 2012 Settlement Agreement detailing the terms upon which the parties have agreed to settle the rate case. See Note 3 for details regarding the 2012 Settlement Agreement terms and for information on APS’s FERC rates.

On January 29, 2016, APS filed a NOI informing the ACC that APS intends to submit a rate case application in June 2016 using an adjusted test year ending December 31, 2015. The NOI provides an overview of the key issues APS expects to address in its formal request such as rate design changes (residential, commercial and industrial), permission to defer for potential future recovery costs associated with the Ocotillo Modernization Project, permission to defer for potential future recovery costs associated with environmental standards compliance, inclusion of post-test year plant and modifications to certain adjustor mechanisms, among other items. In its rate application, APS will request that its proposed pricing changes take effect in July 2017. APS is still developing the exact amount of the request.

APS has several recovery mechanisms in place that provide more timely recovery to APS of its fuel and transmission costs, and costs associated with the promotion and implementation of its demand side management and renewable energy efforts and customer programs. These mechanisms are described more fully in Note 3.

As part of APS’s acquisition of SCE’s interest in Units 4 and 5 of Four Corners, APS and SCE agreed, via a "Transmission Termination Agreement" that, upon closing of the acquisition, the companies would terminate an existing transmission agreement ("Transmission Agreement") between the parties that provides transmission capacity on a system (the "Arizona Transmission System") for SCE to transmit its portion of the output from Four Corners to California. APS previously submitted a request to FERC related to this termination, which resulted in a FERC order denying rate recovery of $40 million that APS agreed to pay SCE associated with the termination. On December 22, 2015, APS and SCE agreed to terminate the Transmission Termination Agreement and allow for the Transmission Agreement to expire according to its terms, which includes settling obligations in accordance with the terms of the Transmission Agreement. APS established a regulatory asset of $12 million in 2015 in connection with the payment required under the terms of the Transmission Agreement, which it expects to recover through its FERC-jurisdictional rates.

Net Metering. On July 12, 2013, APS filed an application with the ACC proposing a solution to address the cost shift brought by the current net metering rules. On December 3, 2013, the ACC issued its order on APS’s net metering proposal. The ACC instituted a charge on customers who install rooftop solar panels after December 31, 2013. The charge of $0.70 per kilowatt became effective on January 1, 2014, and is estimated to collect $4.90 per month from a typical future rooftop solar customer to help pay for their use of the electric grid. The fixed charge does not increase APS's revenue because it is credited to the LFCR.

Appellate Review of Third-Party Regulatory Decision ("System Improvement Benefits" or "SIB"). In a recent appellate challenge to an ACC rate decision involving a water company, the Arizona Court of Appeals considered the question of how the ACC should determine the “fair value” of a utility’s property, as specified in the Arizona Constitution, in connection with authorizing the recovery of costs through rate adjustors outside of a rate case. The Court of Appeals reversed the ACC’s method of finding fair value in that case, and raised questions concerning the relationship between the need for fair value findings and the recovery of capital and certain other utility costs through adjustors. The ACC sought review by the Arizona Supreme Court of this decision and APS filed a brief supporting the ACC’s petition to the Arizona Supreme Court for review of the Court of Appeals’ decision. On February 9, 2016, the Arizona Supreme Court granted review of the decision and oral argument was conducted on March 22, 2016. If the decision is upheld by the Supreme Court without modification, certain APS rate adjustors may require modification. This could in turn have an impact on APS’s ability to recover certain costs in between rate cases. APS cannot predict the outcome of this matter.

Financial Strength and Flexibility. Pinnacle West and APS currently have ample borrowing capacity under their respective credit facilities, and may readily access these facilities ensuring adequate liquidity for each company. Capital expenditures will be funded with internally generated cash and external financings, which may include issuances of long-term debt and Pinnacle West common stock.

Other Subsidiaries.

Bright Canyon Energy. On July 31, 2014, Pinnacle West announced its creation of a wholly-owned subsidiary, BCE. BCE will focus on new growth opportunities that leverage the Company’s core expertise in the electric energy industry. BCE’s first initiative is a 50/50 joint venture with BHE U.S. Transmission LLC, a subsidiary of Berkshire Hathaway Energy Company. The joint venture, named TransCanyon, is pursuing independent transmission opportunities within the eleven states that comprise the Western Electricity Coordinating Council, excluding opportunities related to transmission service that would otherwise be provided under the tariffs of the retail service territories of the venture partners’ utility affiliates. TransCanyon continues to pursue transmission development opportunities in the western United States consistent with its strategy.

On March 29, 2016, TransCanyon entered into a strategic alliance agreement with Pacific Gas and Electric Company ("PG&E") to jointly pursue competitive transmission opportunities solicited by the California System Operator Corporation ("CAISO"), the operator for the majority of California's transmission grid. TransCanyon and PG&E intend to jointly engage in the development of future transmission infrastructure and compete to develop, build, own and operate transmission projects approved by the CAISO.

El Dorado. The operations of El Dorado are not expected to have any material impact on our financial results, or to require any material amounts of capital, over the next three years.

Key Financial Drivers

In addition to the continuing impact of the matters described above, many factors influence our financial results and our future financial outlook, including those listed below. We closely monitor these factors to plan for the Company’s current needs, and to adjust our expectations, financial budgets and forecasts appropriately.

Electric Operating Revenues. For the years 2013 through 2015, retail electric revenues comprised approximately 93% of our total electric operating revenues. Our electric operating revenues are affected by customer growth or decline, variations in weather from period to period, customer mix, average usage per customer and the impacts of energy efficiency programs, distributed energy additions, electricity rates and tariffs, the recovery of PSA deferrals and the operation of other recovery mechanisms. These revenue transactions are affected by the availability of excess generation or other energy resources and wholesale market conditions, including competition, demand and prices.

Customer and Sales Growth. Retail customers in APS’s service territory increased 1.3% for the three-month period ended March 31, 2016 compared with the prior-year period. For the three years 2013 through 2015, APS’s customer growth averaged 1.3% per year. We currently expect annual customer growth to average in the range of 2.0-3.0% for 2016 through 2018 based on our assessment of modestly improving economic conditions in Arizona. Retail electricity sales in kWh, adjusted to exclude the effects of weather variations, increased 1.3% for the three-month period ended March 31, 2016 compared with the prior-year period, reflecting the effects of improving economic conditions and customer growth and an additional day of sales due to the leap year, partially offset by customer conservation and energy efficiency and distributed renewable generation initiatives. For the three years 2013 through 2015, APS experienced annual increases in retail electricity sales averaging 0.1%, adjusted to exclude the effects of weather variations. We currently

estimate that annual retail electricity sales in kWh will increase on average in the range of 0.5-1.5% during 2016 through 2018, including the effects of customer conservation and energy efficiency and distributed renewable generation initiatives, but excluding the effects of weather variations. A slower recovery of the Arizona economy could further impact these estimates.

Actual sales growth, excluding weather-related variations, may differ from our projections as a result of numerous factors, such as economic conditions, customer growth, usage patterns and energy conservation, impacts of energy efficiency programs and growth in distributed generation, and responses to retail price changes. Based on past experience, a reasonable range of variation in our kWh sales projections attributable to such economic factors under normal business conditions can result in increases or decreases in annual net income of up to $10 million.

Weather and Seasonality. In forecasting the retail sales growth numbers provided above, we assume normal weather patterns based on historical data. Historically, extreme weather variations have resulted in annual variations in net income in excess of $20 million. However, our experience indicates that the more typical variations from normal weather can result in increases or decreases in annual net income of up to $10 million. Additionally, amounts reported in our interim Condensed Consolidated Statements of Income are not necessarily indicative of amounts expected for the respective annual periods, due to the effects of seasonal temperature variations on energy consumption.

Fuel and Purchased Power Costs. Fuel and purchased power costs included on our Consolidated Statements of Income are impacted by our electricity sales volumes, existing contracts for purchased power and generation fuel, our power plant performance, transmission availability or constraints, prevailing market prices, new generating plants being placed in service in our market areas, changes in our generation resource allocation, our hedging program for managing such costs and PSA deferrals and the related amortization.

Operations and Maintenance Expenses. Operations and maintenance expenses are impacted by customer and sales growth, power plant operations, maintenance of utility plant (including generation, transmission, and distribution facilities), inflation, outages, renewable energy and demand side management related expenses (which are offset by the same amount of operating revenues) and other factors.

Depreciation and Amortization Expenses. Depreciation and amortization expenses are impacted by net additions to utility plant and other property (such as new generation, transmission, and distribution facilities), and changes in depreciation and amortization rates. See "Capital Expenditures" below for information regarding the planned additions to our facilities. See Note 3 regarding deferral of certain costs pursuant to an ACC order.

Property Taxes. Taxes other than income taxes consist primarily of property taxes, which are affected by the value of property in-service and under construction, assessment ratios, and tax rates. The average property tax rate in Arizona for APS, which owns essentially all of our property, was 11.0% of the assessed value for 2015, 10.7% for 2014 and 10.5% for 2013. We expect property taxes to increase as we add new generating units and continue with improvements and expansions to our existing generating units, transmission and distribution facilities. (See Note 3 for property tax deferrals contained in the 2012 Settlement Agreement.)

Income Taxes. Income taxes are affected by the amount of pretax book income, income tax rates, certain deductions and non-taxable items, such as AFUDC. In addition, income taxes may also be affected by the settlement of issues with taxing authorities.

Interest Expense. Interest expense is affected by the amount of debt outstanding and the interest rates on that debt (see Note 2). The primary factors affecting borrowing levels are expected to be our capital expenditures, long-term debt maturities, equity issuances and internally generated cash flow. An allowance for

borrowed funds used during construction offsets a portion of interest expense while capital projects are under construction. We stop accruing AFUDC on a project when it is placed in commercial operation.

RESULTS OF OPERATIONS

Pinnacle West’s only reportable business segment is our regulated electricity segment, which consists of traditional regulated retail and wholesale electricity businesses (primarily retail and wholesale sales supplied to traditional cost-based rate regulation ("Native Load") customers) and related activities and includes electricity generation, transmission and distribution.

Operating Results — Three-month period ended March 31, 2016 compared with three-month period ended March 31, 2015.

Our consolidated net income attributable to common shareholders for the three months ended March 31, 2016 was $4 million, compared with consolidated net income attributable to common shareholders of $16 million for the prior-year period. The results reflect a decrease of approximately $12 million for the regulated electricity segment primarily due to higher operations and maintenance expenses related to fossil generation and employee benefit costs, partially offset by the effects of weather, higher retail sales due to customer growth and changes in customer usage patterns and related pricing, and higher retail transmission revenues.

The following table presents net income attributable to common shareholders by business segment compared with the prior-year period:



	Three Months Ended March 31,
	2016			2015			Net Change
	(dollars in millions)
Regulated Electricity Segment:
Operating revenues less fuel and purchased power expenses	$	455		$	447		$	8
Operations and maintenance	(243		)	(215		)	(28		)
Depreciation and amortization	(119		)	(121		)	2
Taxes other than income taxes	(43		)	(43		)	—
All other income and expenses, net	8			6			2
Interest charges, net of allowance for borrowed funds used during construction	(46		)	(44		)	(2		)
Income taxes	(2		)	(8		)	6
Less income related to noncontrolling interests (Note 5)	(5		)	(5		)	—
Regulated electricity segment income	5			17			(12		)
All other	(1		)	(1		)	—
Net Income Attributable to Common Shareholders	$	4		$	16		$	(12	)

Operating revenues less fuel and purchased power expenses. Regulated electricity segment operating revenues less fuel and purchased power expenses were $8 million higher for the three months ended March 31, 2016 compared with the prior-year period. The following table summarizes the major components of this change:



	Increase (Decrease)
	Operating revenues			Fuel and purchased power expenses			Net change
	(dollars in millions)
Effects of weather	$	6		$	2		$	4
Higher retail sales due to customer growth and changes in customer usage patterns and related pricing	5			2			3
Higher retail transmission revenues	3			—			3
Changes in net fuel and purchased power costs, including off-system sales margins and related deferrals	(7		)	(7		)	—
Miscellaneous items, net	(1		)	1			(2		)
Total	$	6		$	(2	)	$	8

Operations and maintenance. Operations and maintenance expenses increased $28 million for the three months ended March 31, 2016 compared with the prior-year period primarily because of:


•	An increase of $15 million in fossil generation costs primarily related to increased planned outage costs;


•	An increase of $10 million for employee benefit costs primarily related to stock compensation; and


•	An increase of $3 million related to miscellaneous other factors.

Income Taxes. Income taxes were $6 million lower for the three months ended March 31, 2016 compared with the prior-year period, primarily because of lower taxable income in the current year.

LIQUIDITY AND CAPITAL RESOURCES

Overview

Pinnacle West’s primary cash needs are for dividends to our shareholders and principal and interest payments on our indebtedness. The level of our common stock dividends and future dividend growth will be dependent on declaration by our Board of Directors and based on a number of factors, including our financial condition, payout ratio, free cash flow and other factors.

Our primary sources of cash are dividends from APS and external debt and equity issuances. An ACC order requires APS to maintain a common equity ratio of at least 40%. As defined in the related ACC order, the common equity ratio is defined as total shareholder equity divided by the sum of total shareholder equity and long-term debt, including current maturities of long-term debt. At March 31, 2016, APS’s common equity ratio, as defined, was 55%. Its total shareholder equity was approximately $4.7 billion, and total capitalization was approximately $8.6 billion. Under this order, APS would be prohibited from paying dividends if such payment would reduce its total shareholder equity below approximately $3.4 billion, assuming APS’s total

capitalization remains the same. This restriction does not materially affect Pinnacle West’s ability to meet its ongoing cash needs or ability to pay dividends to shareholders.

APS’s capital requirements consist primarily of capital expenditures and maturities of long-term debt. APS funds its capital requirements with cash from operations and, to the extent necessary, external debt financing and equity infusions from Pinnacle West.

Many of APS’s current capital expenditure projects qualify for bonus depreciation. On December 18, 2015, President Obama signed into law the Consolidated Appropriations Act, 2016 (H.R. 2029), which combined the tax and government funding bills (The Protecting Americans from Tax Hikes Act and Omnibus Bill) containing an extension of bonus depreciation through 2019. Enactment of this legislation is expected to generate approximately $375-$425 million of cash tax benefits over the next three years, which is expected to be fully realized by APS and Pinnacle West Consolidated during this time frame. The cash generated by the extension of bonus depreciation is an acceleration of the tax benefits that APS would have otherwise received over 20 years and reduces rate base for ratemaking purposes. At Pinnacle West Consolidated, the extension of bonus depreciation will, in turn, delay until 2019 full cash realization of approximately $82 million of currently unrealized Investment Tax Credits, which are recorded as a deferred tax asset on the Condensed Consolidated Balance Sheet as of December 31, 2015.

Summary of Cash Flows

The following tables present net cash provided by (used for) operating, investing and financing activities for the three months ended March 31, 2016 and 2015 (dollars in millions):

Pinnacle West Consolidated



	Three Months Ended March 31,						Net
	2016			2015			Change
Net cash flow provided by operating activities	$	144		$	144		$	—
Net cash flow used for investing activities	(372		)	(233		)	(139		)
Net cash flow provided by financing activities	203			93			110
Net increase (decrease) in cash and cash equivalents	$	(25	)	$	4		$	(29	)

Arizona Public Service Company



	Three Months Ended March 31,						Net
	2016			2015			Change
Net cash flow provided by operating activities	$	154		$	153		$	1
Net cash flow used for investing activities	(363		)	(232		)	(131		)
Net cash flow provided by financing activities	192			81			111
Net increase (decrease) in cash and cash equivalents	$	(17	)	$	2		$	(19	)

Operating Cash Flows

Three-month period ended March 31, 2016 compared with three-month period ended March 31, 2015. Pinnacle West’s consolidated net cash provided by operating activities was $144 million in 2016 compared to $144 million in 2015, reflecting no change in net cash provided.

Retirement plans and other postretirement benefits. Pinnacle West sponsors a qualified defined benefit pension plan and a non-qualified supplemental excess benefit retirement plan for the employees of Pinnacle West and our subsidiaries. The requirements of the Employee Retirement Income Security Act of 1974 ("ERISA") require us to contribute a minimum amount to the qualified plan. We contribute at least the minimum amount required under ERISA regulations, but no more than the maximum tax-deductible amount. The minimum required funding takes into consideration the value of plan assets and our pension benefit obligations. Under ERISA, the qualified pension plan was 116% funded as of January 1, 2015 and is estimated to be approximately 116% funded as of January 1, 2016. Under GAAP, the qualified pension plan was 89% funded as of January 1, 2015 and is estimated to be approximately 88% funded as of January 1, 2016. The assets in the plan are comprised of fixed-income, equity, real estate, and short-term investments. Future year contribution amounts are dependent on plan asset performance and plan actuarial assumptions. We made voluntary contributions of $60 million to our pension plan year-to-date in 2016. The minimum required contributions for the pension plan are zero for the next three years. We expect to make voluntary contributions up to a total of $300 million during the 2016-2018 period. We expect to make contributions of approximately $1 million in each of the next three years to our other postretirement benefit plans.

Investing Cash Flows

Three-month period ended March 31, 2016 compared with three-month period ended March 31, 2015. Pinnacle West’s consolidated net cash used for investing activities was $372 million in 2016, compared to $233 million in 2015, an increase of $139 million in net cash used primarily related to increased capital expenditures.

Capital Expenditures. The following table summarizes the estimated capital expenditures for the next three years:

Capital Expenditures

(dollars in millions)



	Estimated for the Year Ended December 31,
	2016		2017		2018
APS
Generation:
Nuclear Fuel	$	81	$	78	$	81
Renewables	110		1		1
Environmental	232		194		90
New Gas Generation	77		234		115
Other Generation	139		140		217
Distribution	364		354		382
Transmission	114		200		150
Other (a)	88		84		88
Total APS	$	1,205	$	1,285	$	1,124

(a) Primarily information systems and facilities projects.

Generation capital expenditures are comprised of various improvements to APS’s existing fossil, renewable and nuclear plants. Examples of the types of projects included in this category are additions, upgrades and capital replacements of various power plant equipment, such as turbines, boilers and environmental equipment. The estimated renewables capital expenditures include a grid scale solar facility. We have not included estimated costs for Cholla's compliance with EPA’s regional haze rule since we have challenged the regional haze rule judicially and we have proposed a compromise strategy to EPA, which, if approved, would allow us to avoid expenditures related to environmental control equipment. We are monitoring the status of other environmental matters, which, depending on their final outcome, could require modification to our planned environmental expenditures.

On February 17, 2015, APS and El Paso entered into an asset purchase agreement providing for the purchase by APS, or an affiliate of APS, of El Paso’s 7% interest in each of Units 4 and 5 of Four Corners. On December 29, 2015, NTEC notified APS of its intent to exercise its option to purchase the 7% interest. The table above does not include capital expenditures related to El Paso's 7% interest in Four Corners Units 4 and 5 of approximately $30 million in 2016 and $25 million in 2017.

Distribution and transmission capital expenditures are comprised of infrastructure additions and upgrades, capital replacements, and new customer construction. Examples of the types of projects included in the forecast include power lines, substations, and line extensions to new residential and commercial developments.

Capital expenditures will be funded with internally generated cash and external financings, which may include issuances of long-term debt and Pinnacle West common stock.

Financing Cash Flows and Liquidity

Three-month period ended March 31, 2016 compared with three-month period ended March 31, 2015. Pinnacle West’s consolidated net cash provided by financing activities was $203 million in 2016, compared to $93 million of net cash provided in 2015, an increase of $110 million in net cash provided. The increase in net cash provided by financing activities is primarily due to a $365 million net change in short-term borrowings and $250 million lower issuances of long-term debt.

Significant Financing Activities. On April 20, 2016, the Pinnacle West Board of Directors declared a dividend of $0.625 per share of common stock, payable on June 1, 2016 to shareholders of record on May 2, 2016.

Available Credit Facilities. Pinnacle West and APS maintain committed revolving credit facilities in order to enhance liquidity and provide credit support for their commercial paper programs.

During the first quarter of 2016, APS increased its commercial paper program from $250 million to $500 million.

See "Financial Assurances" in Note 7 for a discussion of APS’s separate outstanding letters of credit.

Other Financing Matters. See Note 6 for information related to the change in our margin and collateral accounts.

Debt Provisions

Pinnacle West’s and APS’s debt covenants related to their respective bank financing arrangements include maximum debt to capitalization ratios. Pinnacle West and APS comply with this covenant. For both Pinnacle West and APS, this covenant requires that the ratio of consolidated debt to total consolidated capitalization not exceed 65%. At March 31, 2016, the ratio was approximately 48% for Pinnacle West and 47% for APS. Failure to comply with such covenant levels would result in an event of default which, generally speaking, would require the immediate repayment of the debt subject to the covenants and could "cross-default" other debt. See further discussion of "cross-default" provisions below.

Neither Pinnacle West’s nor APS’s financing agreements contain "rating triggers" that would result in an acceleration of the required interest and principal payments in the event of a rating downgrade. However, our bank credit agreements and term loan facilities contain a pricing grid in which the interest rates we pay for borrowings thereunder are determined by our current credit ratings.

All of Pinnacle West’s loan agreements contain "cross-default" provisions that would result in defaults and the potential acceleration of payment under these loan agreements if Pinnacle West or APS were to default under certain other material agreements. All of APS’s bank agreements contain "cross-default" provisions that would result in defaults and the potential acceleration of payment under these bank agreements if APS were to default under certain other material agreements. Pinnacle West and APS do not have a material adverse change restriction for credit facility borrowings.

See Note 2 for further discussions of liquidity matters.

Credit Ratings

The ratings of securities of Pinnacle West and APS as of April 22, 2016 are shown below. We are disclosing these credit ratings to enhance understanding of our cost of short-term and long-term capital and our ability to access the markets for liquidity and long-term debt. The ratings reflect the respective views of the rating agencies, from which an explanation of the significance of their ratings may be obtained. There is no assurance that these ratings will continue for any given period of time. The ratings may be revised or withdrawn entirely by the rating agencies if, in their respective judgments, circumstances so warrant. Any downward revision or withdrawal may adversely affect the market price of Pinnacle West’s or APS’s securities and/or result in an increase in the cost of, or limit access to, capital. Such revisions may also result in substantial additional cash or other collateral requirements related to certain derivative instruments, insurance policies, natural gas transportation, fuel supply, and other energy-related contracts. At this time, we believe we have sufficient available liquidity resources to respond to a downward revision to our credit ratings.



	Moody’s	Standard & Poor’s	Fitch
Pinnacle West
Corporate credit rating	A3	A-	A-
Commercial paper	P-2	A-2	F2
Outlook	Stable	Stable	Stable

APS
Corporate credit rating	A2	A-	A-
Senior unsecured	A2	A-	A
Commercial paper	P-1	A-2	F2
Outlook	Stable	Stable	Stable

Off-Balance Sheet Arrangements

See Note 5 for a discussion of the impacts on our financial statements of consolidating certain VIEs.

Contractual Obligations

CRITICAL ACCOUNTING POLICIES

In preparing the financial statements in accordance with GAAP, management must often make estimates and assumptions that affect the reported amounts of assets, liabilities, revenues, expenses and related disclosures at the date of the financial statements and during the reporting period. Some of those judgments can be subjective and complex, and actual results could differ from those estimates. There have been no changes to our critical accounting policies since our 2015 Form 10-K. See "Critical Accounting Policies" in Item 7 of the 2015 Form 10-K for further details about our critical accounting policies.

OTHER ACCOUNTING MATTERS

During the first quarter of 2016, we adopted new consolidation accounting guidance. The adoption of this guidance did not impact our financial statements.

We are currently evaluating the impacts of adopting the following new accounting standards:


•	Stock compensation guidance effective for us January 1, 2017


•	Revenue recognition guidance effective for us January 1, 2018


•	Financial instrument recognition and measurement guidance effective for us January 1, 2018


•	Lease accounting guidance effective for us January 1, 2019

See Note 12 for additional information related to accounting matters.

MARKET AND CREDIT RISKS

Market Risks

Our operations include managing market risks related to changes in interest rates, commodity prices and investments held by our nuclear decommissioning trust fund and benefit plan assets.

Interest Rate and Equity Risk

We have exposure to changing interest rates. Changing interest rates will affect interest paid on variable-rate debt and the market value of fixed income securities held by our nuclear decommissioning trust fund (see Note 10 and Note 11) and benefit plan assets. The nuclear decommissioning trust fund and benefit plan assets also have risks associated with the changing market value of their equity and other non-fixed income investments. Nuclear decommissioning and benefit plan costs are recovered in regulated electricity prices.

Commodity Price Risk

We are exposed to the impact of market fluctuations in the commodity price and transportation costs of electricity and natural gas. Our risk management committee, consisting of officers and key management personnel, oversees company-wide energy risk management activities to ensure compliance with our stated energy risk management policies. We manage risks associated with these market fluctuations by utilizing various commodity instruments that may qualify as derivatives, including futures, forwards, options and swaps. As part of our risk management program, we use such instruments to hedge purchases and sales of electricity and fuels. The changes in market value of such contracts have a high correlation to price changes in the hedged commodities.

The following table shows the net pretax changes in mark-to-market of our derivative positions for the three months ended March 31, 2016 and 2015 (dollars in millions):



	Three Months Ended March 31,
	2016			2015
Mark-to-market of net positions at beginning of year	$	(154	)	$	(115	)
Increase in regulatory asset/liability	(14		)	(41		)
Recognized in OCI:
Mark-to-market losses realized during the period	1			1
Change in valuation techniques	—			—
Mark-to-market of net positions at end of period	$	(167	)	$	(155	)

The table below shows the fair value of maturities of our derivative contracts (dollars in millions) at March 31, 2016 by maturities and by the type of valuation that is performed to calculate the fair values, classified in their entirety based on the lowest level of input that is significant to the fair value measurement. See Note 1, "Derivative Accounting" and "Fair Value Measurements," in Item 8 of our 2015 Form 10-K and Note 10 for more discussion of our valuation methods.



Source of Fair Value	2016			2017			2018			2019			2020			Total fair value
Observable prices provided by other external sources	$	(71	)	$	(39	)	$	(17	)	$	(1	)	$	—		$	(128	)
Prices based on unobservable inputs	(13		)	(9		)	(8		)	(7		)	(2		)	(39		)
Total by maturity	$	(84	)	$	(48	)	$	(25	)	$	(8	)	$	(2	)	$	(167	)

The table below shows the impact that hypothetical price movements of 10% would have on the market value of our risk management assets and liabilities included on Pinnacle West’s Condensed Consolidated Balance Sheets at March 31, 2016 and December 31, 2015 (dollars in millions):



	March 31, 2016 Gain (Loss)					December 31, 2015 Gain (Loss)
	Price Up 10%		Price Down 10%			Price Up 10%		Price Down 10%
Mark-to-market changes reported in:
Regulatory asset (liability) or OCI (a)
Electricity	$	2	$	(2	)	$	2	$	(2	)
Natural gas	36		(36		)	35		(35		)
Total	$	38	$	(38	)	$	37	$	(37	)


(a)	These contracts are economic hedges of our forecasted purchases of natural gas and electricity. The impact of these hypothetical price movements would substantially offset the impact that these same price movements would have on the physical exposures being hedged. To the extent the amounts are eligible for inclusion in the PSA, the amounts are recorded as either a regulatory asset or liability.

Credit Risk

We are exposed to losses in the event of non-performance or non-payment by counterparties. See Note 6 for a discussion of our credit valuation adjustment policy.

Item 3. QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK

See "Key Financial Drivers" and "Market and Credit Risks" in Item 2 above for a discussion of quantitative and qualitative disclosures about market risks.

Item 4. CONTROLS AND PROCEDURES

(a) Disclosure Controls and Procedures

The term "disclosure controls and procedures" means controls and other procedures of a company that are designed to ensure that information required to be disclosed by a company in the reports that it files or submits under the Securities Exchange Act of 1934, as amended (the "Exchange Act") (15 U.S.C. 78a et seq.), is recorded, processed, summarized and reported, within the time periods specified in the SEC’s rules and forms. Disclosure controls and procedures include, without limitation, controls and procedures designed to ensure that information required to be disclosed by a company in the reports that it files or submits under the Exchange Act is accumulated and communicated to a company’s management, including its principal executive and principal financial officers, or persons performing similar functions, as appropriate to allow timely decisions regarding required disclosure.

Pinnacle West’s management, with the participation of Pinnacle West’s Chief Executive Officer and Chief Financial Officer, have evaluated the effectiveness of Pinnacle West’s disclosure controls and procedures as of March 31, 2016. Based on that evaluation, Pinnacle West’s Chief Executive Officer and Chief Financial Officer have concluded that, as of that date, Pinnacle West’s disclosure controls and procedures were effective.

APS’s management, with the participation of APS’s Chief Executive Officer and Chief Financial Officer, has evaluated the effectiveness of APS’s disclosure controls and procedures as of March 31, 2016. Based on that evaluation, APS’s Chief Executive Officer and Chief Financial Officer have concluded that, as of that date, APS’s disclosure controls and procedures were effective.

(b) Changes in Internal Control Over Financial Reporting

The term "internal control over financial reporting" (defined in SEC Rule 13a-15(f)) refers to the process of a company that is designed to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with GAAP.

No change in Pinnacle West’s or APS’s internal control over financial reporting occurred during the fiscal quarter ended March 31, 2016 that materially affected, or is reasonably likely to materially affect, Pinnacle West’s or APS’s internal control over financial reporting.

PART II -- OTHER INFORMATION

Item 1. LEGAL PROCEEDINGS

See "Business of Arizona Public Service Company — Environmental Matters" in Item 1 of the 2015 Form 10-K with regard to pending or threatened litigation and other disputes.

See Note 3 for ACC and FERC-related matters.

See Note 7 for information regarding environmental matters, Superfund-related matters, matters related to a September 2011 power outage and a New Mexico tax matter.

See "Management's Discussion and Analysis of Financial Condition and Results of Operations - Overview - Areas of Business Focus - Operational Performance, Reliability and Recent Developments - Natural Gas" for information regarding the appeal of a permit related to our Ocotillo modernization project.

Item 1A. RISK FACTORS

In addition to the other information set forth in this report, you should carefully consider the factors discussed in Part I, Item 1A — Risk Factors in the 2015 Form 10-K, which could materially affect the business, financial condition, cash flows or future results of Pinnacle West and APS. The risks described in the 2015 Form 10-K are not the only risks facing Pinnacle West and APS. Additional risks and uncertainties not currently known to us or that we currently deem to be immaterial also may materially adversely affect the business, financial condition, cash flows and/or operating results of Pinnacle West and APS.

Item 2. UNREGISTERED SALES OF EQUITY SECURITIES AND USE OF PROCEEDS

Issuer Purchases of Equity Securities

The following table contains information about our purchases of our common stock during the first quarter of 2016.



Period	Total Number of Shares Purchased (a)	Average Price Paid per Share	Total Number of Shares Purchased as Part of Publicly Announced Plans or Programs	Maximum Number of Shares that May Yet Be Purchased Under the Plans or Programs
January 1 - January 31, 2016	—	—
February 1 - February 29, 2016	71,962	67.81
March 1 - March 31, 2016	—	—
Total	71,962	$67.81	--	--

(a) Represents shares of common stock withheld by Pinnacle West to satisfy tax withholding obligations upon the vesting of performance and restricted stock.

Item 5. OTHER INFORMATION

None

Item 6. EXHIBITS

(a) Exhibits



Exhibit No.	Registrant(s)	Description
10.1	Pinnacle West APS	Term Loan Agreement dated as of April 22, 2016 among APS, as Borrower, Toronto Dominion (Texas) LLC, as Agent and such institutions compromising the lenders party thereto

12.1	Pinnacle West	Ratio of Earnings to Fixed Charges

12.2	APS	Ratio of Earnings to Fixed Charges

12.3	Pinnacle West	Ratio of Earnings to Combined Fixed Charges and Preferred Stock Dividend Requirements

31.1	Pinnacle West	Certificate of Donald E. Brandt, Chief Executive Officer, pursuant to Rule 13a-14(a) and Rule 15d-14(a) of the Securities Exchange Act, as amended

31.2	Pinnacle West	Certificate of James R. Hatfield, Executive Vice President and Chief Financial Officer, pursuant to Rule 13a-14(a) and Rule 15d-14(a) of the Securities Exchange Act, as amended



31.3	APS	Certificate of Donald E. Brandt, Chief Executive Officer, pursuant to Rule 13a-14(a) and Rule 15d-14(a) of the Securities Exchange Act, as amended

31.4	APS	Certificate of James R. Hatfield, Executive Vice President and Chief Financial Officer, pursuant to Rule 13a-14(a) and Rule 15d-14(a) of the Securities Exchange Act, as amended

32.1*	Pinnacle West	Certification of Chief Executive Officer and Chief Financial Officer, pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002

32.2*	APS	Certification of Chief Executive Officer and Chief Financial Officer, pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002

101.INS	Pinnacle West APS	XBRL Instance Document

101.SCH	Pinnacle West APS	XBRL Taxonomy Extension Schema Document

101.CAL	Pinnacle West APS	XBRL Taxonomy Extension Calculation Linkbase Document

101.LAB	Pinnacle West APS	XBRL Taxonomy Extension Label Linkbase Document

101.PRE	Pinnacle West APS	XBRL Taxonomy Extension Presentation Linkbase Document

101.DEF	Pinnacle West APS	XBRL Taxonomy Definition Linkbase Document

________________________________

*Furnished herewith as an Exhibit.

In addition, Pinnacle West and APS hereby incorporate the following Exhibits pursuant to Exchange Act Rule 12b-32 and Regulation §229.10(d) by reference to the filings set forth below:



Exhibit No.	Registrant(s)	Description	Previously Filed as Exhibit(1)	Date Filed

3.1	Pinnacle West	Pinnacle West Capital Corporation Bylaws, amended as of May 19, 2010	3.1 to Pinnacle West/APS June 30, 2010 Form 10-Q Report, File Nos. 1-8962 and 1-4473	8/3/2010

3.2	Pinnacle West	Articles of Incorporation, restated as of May 21, 2008	3.1 to Pinnacle West/APS June 30, 2008 Form 10-Q Report, File Nos. 1-8962 and 1-4473	8/7/2008

3.3	APS	Articles of Incorporation, restated as of May 25, 1988	4.2 to APS’s Form S-3 Registration Nos. 33-33910 and 33-55248 by means of September 24, 1993 Form 8-K Report, File No. 1-4473	9/29/1993

3.4	APS	Amendment to the Articles of Incorporation of Arizona Public Service Company, amended May 16, 2012	3.1 to Pinnacle West/APS May 22, 2012 Form 8-K Report, File Nos. 1-8962 and 1-4473	5/22/2012

3.5	APS	Arizona Public Service Company Bylaws, amended as of December 16, 2008	3.4 to Pinnacle West/APS December 31, 2008 Form 10-K, File Nos. 1-8962 and 1-4473	2/20/2009

10.11.6	Pinnacle West	Five-Year Credit Agreement dated as of September 2, 2015 among APS, as Borrower, Barclays Bank PLC, as Agent and Issuing Bank, and the lenders and other parties thereto	10.1 to Pinnacle West/APS September 30, 2015 Form 10-Q Report, File Nos. 1-8962 and 1-4473	10/30/2015

10.11.7	Pinnacle West	Term Loan Agreement dated as of June 26, 2015 among APS, as Borrower, Toronto Dominion (Texas) LLC, as Agent, Citibank, N.A., as Syndication Agent, and such institutions compromising the lenders party thereto	10.1 to Pinnacle West/APS June 30, 2015 Form 10-Q Report, File Nos. 1-8962 and 1-4473	7/30/2015

_______________________________

(1) Reports filed under File Nos. 1-4473 and 1-8962 were filed in the office of the Securities and Exchange Commission located in Washington, D.C.

SIGNATURES

Pursuant to the requirements of the Securities Exchange Act of 1934, each registrant has duly caused this report to be signed on its behalf by the undersigned thereunto duly authorized.



		PINNACLE WEST CAPITAL CORPORATION
		(Registrant)


Dated:	April 29, 2016	By:	/s/ James R. Hatfield
			James R. Hatfield
			Executive Vice President and
			Chief Financial Officer
			(Principal Financial Officer and
			Officer Duly Authorized to sign this Report)


		ARIZONA PUBLIC SERVICE COMPANY
		(Registrant)


Dated:	April 29, 2016	By:	/s/ James R. Hatfield
			James R. Hatfield
			Executive Vice President and
			Chief Financial Officer
			(Principal Financial Officer and
			Officer Duly Authorized to sign this Report)

Exhibit

EXECUTION VERSION

U.S. $100,000,000

TERM LOAN AGREEMENT

Dated as of April 22, 2016

among

ARIZONA PUBLIC SERVICE COMPANY,

as Borrower,

THE LENDERS PARTY HERETO,

TORONTO DOMINION (TEXAS) LLC,

as Agent,

_____________________________________________________________________

TD SECURITIES (USA) LLC,

and

CITIBANK, N.A.

and

THE BANK OF NEW YORK MELLON

as Joint Lead Arrangers and as Joint Bookrunners

TABLE OF CONTENTS


ARTICLE I DEFINITIONS AND ACCOUNTING TERMS	1


Section 1.01	Certain Defined Terms 1


Section 1.02	Other Interpretive Provisions 19


Section 1.03	Accounting Terms 20


Section 1.04	Rounding 21


Section 1.05	Times of Day 21


ARTICLE II AMOUNTS AND TERMS OF THE LOANS	21


Section 2.01	The Loans 21


Section 2.02	Making the Loans 21


Section 2.03	Agent’s Fees 22


Section 2.04	Repayment of Loans 23


Section 2.05	Interest on Loans 23


Section 2.06	Interest Rate Determination 24


Section 2.07	Optional Conversion of Loans 25


Section 2.08	Prepayments of Loans 25


Section 2.09	Increased Costs 26


Section 2.10	Illegality 27


Section 2.11	Payments and Computations 27


Section 2.12	Taxes 28


Section 2.13	Sharing of Payments, Etc 33


Section 2.14	Evidence of Debt 33


Section 2.15	Use of Proceeds 34


Section 2.16	Affected Lenders 34


Section 2.17	Replacement of Lenders 34


ARTICLE III CONDITIONS PRECEDENT	35


Section 3.01	Conditions Precedent to Effectiveness 35


Section 3.02	Determinations Under Section 3.01 37


ARTICLE IV REPRESENTATIONS AND WARRANTIES	37


Section 4.01	Representations and Warranties of the Borrower 37


ARTICLE V COVENANTS OF THE BORROWER	41


Section 5.01	Affirmative Covenants 41


Section 5.02	Negative Covenants 45


Section 5.03	Financial Covenant 47


ARTICLE VI EVENTS OF DEFAULT	47


Section 6.01	Events of Default 47


ARTICLE VII THE AGENT	49


Section 7.01	Appointment and Authority 49


Section 7.02	Rights as a Lender 49


Section 7.03	Exculpatory Provisions 50


Section 7.04	Reliance by Agent 50


Section 7.05	Delegation of Duties 51


Section 7.06	Resignation of Agent 51


Section 7.07	Non-Reliance on Agent and Other Lenders 51


Section 7.08	No Other Duties, Etc 52


ARTICLE VIII MISCELLANEOUS	52


Section 8.01	Amendments, Etc 52


Section 8.02	Notices, Etc. 53


Section 8.03	No Waiver; Cumulative Remedies; Enforcement 55


Section 8.04	Costs and Expenses; Indemnity; Damage Waiver 55


Section 8.05	Right of Set-off 57


Section 8.06	Effectiveness; Binding Effect 58


Section 8.07	Successors and Assigns 58


Section 8.08	Confidentiality 61


Section 8.09	Governing Law 62


Section 8.10	Counterparts; Integration 62


Section 8.11	Jurisdiction, Etc. 62


Section 8.12	Payments Set Aside 63


Section 8.13	Patriot Act 63


Section 8.14	Waiver of Jury Trial 63


Section 8.15	No Advisory or Fiduciary Responsibility 63


Section 8.16	Survival of Representations and Warranties 64


Section 8.17	Severability 64


Section 8.18	Acknowledgement and Consent to Bail-In of EEA Financial Institutions 64

Schedules

Schedule 1.01 Commitments and Ratable Shares

Schedule 4.01(j) Subsidiaries

Schedule 4.01(k) Existing Indebtedness

Schedule 8.02 Certain Addresses for Notices

Exhibits

Exhibit A Form of Note

Exhibit B Form of Notice of Initial Borrowing

Exhibit C Form of Assignment and Assumption

Exhibit D Form of Interest Election Request

Exhibit E Form of Prepayment Notice

TERM LOAN AGREEMENT

Dated as of April 22, 2016

ARIZONA PUBLIC SERVICE COMPANY, an Arizona corporation (the “Borrower”), the banks, financial institutions and other institutional lenders (the “Initial Lenders”) listed on the signature pages hereof and TORONTO DOMINION (TEXAS) LLC, as Agent for the Lenders (as hereinafter defined), agree as follows:

The Borrower has requested that the Lenders provide a $100,000,000 term loan facility for the purposes set forth herein, and the Lenders are willing to do so on the terms and conditions set forth herein.

In consideration of the mutual covenants and agreements herein contained, the parties hereto covenant and agree as follows:

Article I

DEFINITIONS AND ACCOUNTING TERMS

Section 1.01 Certain Defined Terms. As used in this Agreement, the following terms shall have the following meanings:

“2013 Order” means Decision No. 73659, dated February 6, 2013, of the Arizona Corporation Commission.

“Administrative Questionnaire” means an Administrative Questionnaire in a form supplied by the Agent.

“Affected Lender” means any Lender, as reasonably determined by the Agent or, if the Agent is the Affected Lender, by the Required Lenders, that (a) has failed to (i) fund all or any portion of its Loans or (ii) pay to the Agent or any other Lender any other amount required to be paid by it under this Agreement, (b) has notified the Borrower, the Agent or any Lender in writing of its intention not to fund a Loan or any of its other funding obligations under this Agreement, (c) has failed, within three Business Days after written request by the Agent, or, if the Agent is the Affected Lender, by the Required Lenders, to confirm that it will comply with the terms of this Agreement relating to its obligations to fund a Loan, (d) shall (or whose parent company shall) generally not pay its debts as such debts become due, or shall admit in writing its inability to pay its debts generally, or shall make a general assignment for the benefit of creditors; or shall have had any proceeding instituted by or against such Lender (or its parent company) seeking to adjudicate it as bankrupt or insolvent, or seeking liquidation, winding up, reorganization, arrangement, adjustment, protection, relief, or composition of it or its debts under any law relating to bankruptcy, insolvency or reorganization or relief of debtors, or seeking the entry of an order for relief or the appointment of a receiver, trustee, administrator, assignee for the benefit of creditors or similar Person charged with reorganization or liquidation of its business or custodian for it or for any substantial part of its property and, in the case of any such proceeding instituted against it (but not instituted by it), either such proceeding shall remain undismissed or unstayed for a period of 30 days, or any of the actions sought in such proceeding (including, without limitation, the entry of an order for relief against, or the appointment of a receiver, trustee, administrator, assignee for the benefit of creditors or similar Person charged with reorganization or liquidation of its business or custodian for, it or for any substantial part of its property) shall occur, or shall take (or whose parent company shall take) any corporate action to authorize any of the actions set forth above in this subsection (d) or (e) has (or whose parent company has) become the subject of a Bail-In Action, provided that a Lender shall not be deemed to be an Affected Lender solely by virtue of the ownership or acquisition of any equity interest in such Lender or any Person that directly or indirectly controls such Lender by a Governmental Authority or an instrumentality thereof.

“Affiliate” means, as to any Person, any other Person that, directly or indirectly, controls, is controlled by or is under common control with such Person or is a director or officer of such Person. For purposes of this definition, the term “control” (including the terms “controlling”, “controlled by” and “under common control with”) of a Person means the possession, direct or indirect, of the power to direct or cause the direction of the management and policies of such Person, whether through the ownership of Voting Stock, by contract or otherwise.

“Agent” means Toronto Dominion (Texas) LLC, (including its branches and Affiliates as may be required to administer its duties) in its capacity as administrative agent under any of the Loan Documents, or any successor administrative agent.

“Agent’s Account” means the account of the Agent designated as such by the Agent to the Lenders and the Borrower from time to time.

“Agent’s Office” means the Agent’s address specified in Section 8.02(a) and, as appropriate, the Agent’s Account, or such other address or account as the Agent may from time to time notify to the Borrower and the Lenders.

“Agreement” means this Term Loan Agreement, dated as of April 22, 2016, among the Borrower, the Lenders named herein and from time to time party hereto and the Agent, together with all schedules and exhibits hereto.

“Anti-Corruption Laws” means all laws, rules, and regulations of any jurisdiction applicable to the Borrower or its Subsidiaries from time to time concerning or relating to bribery, corruption or money laundering.

“Applicable Lending Office” means, with respect to each Lender, such Lender’s Domestic Lending Office in the case of a Base Rate Loan and such Lender’s Eurodollar Lending Office in the case of a Eurodollar Rate Loan.

“Applicable Rate” means, from time to time, the following percentages per annum determined by reference to the Public Debt Rating as set forth below:



Public Debt Rating S&P/Moody’s	Base Rate Loan		Eurodollar Rate Loan
Level 1 ≥ A+/A1	0.000%		0.65%
Level 2 <Level 1 but ≥ A/A2	0.000	%	0.70	%
Level 3 < Level 2 but ≥ A-/A3	0.000	%	0.75	%
Level 4 < Level 3 but ≥ BBB+/Baa1	0.000	%	0.85	%
Level 5 < Level 4 but > BBB/Baa2	0.05	%	1.05	%
Level 6 < Level 5	0.20	%	1.20	%

“Approved Fund” means any Fund that is administered or managed by (a) a Lender, (b) an Affiliate of a Lender or (c) an entity or an Affiliate of any entity that administers or manages a Lender.

“Arrangers” means each of TD Securities (USA) LLC, Citibank, N.A. and The Bank of New York Mellon, together with their successors and assigns.

“Assignment and Assumption” means an assignment and assumption entered into by a Lender and an Eligible Assignee, and accepted by the Agent, in substantially the form of Exhibit C hereto.

“Authorized Officer” means the chairman of the board, chief executive officer, chief operating officer, chief financial officer, chief accounting officer, president, any vice president, treasurer, controller or any assistant treasurer of the Borrower.

“Bail-In Action” means the exercise of any Write-Down and Conversion Powers by the applicable EEA Resolution Authority in respect of any liability of an EEA Financial Institution.

“Bail-In Legislation” means, with respect to any EEA Member Country implementing Article 55 of Directive 2014/59/EU of the European Parliament and of the Council of the European Union, the implementing law for such EEA Member Country from time to time which is described in the EU Bail-In Legislation Schedule.

“Base Rate” means for any day a fluctuating rate per annum equal to the highest of:

(a) Prime Rate in effect on such day;

(b) the Federal Funds Rate in effect on such day plus 0.50%; and

(c) an amount equal to (i) the Eurodollar Rate for a one month Interest Period on such day (or if such day is not a Business Day, the immediately preceding Business Day) plus (ii) 1%; provided that, if the Base Rate shall be less than zero, such rate shall be deemed to be zero for purposes of this Agreement.

“Base Rate Loan” means a Loan that bears interest as provided in Section 2.05(a)(i).

“Borrower” has the meaning given to such term in the introductory paragraph hereof.

“Borrower Information” has the meaning specified in Section 8.08.

“Borrowing” means Loans of the same Type that are made, Converted or continued on the same date and, in the case of Eurodollar Rate Loans, as to which a single Interest Period is in effect.

“Business Day” means a day of the year on which banks are not required or authorized by Law to close in New York, New York or Phoenix, Arizona and, if the applicable Business Day relates to any Loan in which interest is calculated by reference to the Eurodollar Rate, on which dealings are carried on in the London interbank market.

“Capital Lease” means, at any time, a lease with respect to which the lessee is required concurrently to recognize the acquisition of an asset and the incurrence of a liability in accordance with GAAP.

“Capital Lease Obligations” means as to any Person, the obligations of such Person to pay rent or other amounts under a lease of (or other agreement conveying the right to use) real and/or personal property, which obligations are required to be classified and accounted for as a Capital Lease on the balance sheet of such Person under GAAP and, for the purposes of this Agreement, the amount of such obligations shall be the capitalized amount thereof, determined in accordance with GAAP.

“Change in Law” means the occurrence, after the date of this Agreement, of any of the following: (a) the adoption of any Law, (b) any change in any Law or in the administration, interpretation or application thereof by any Governmental Authority or (c) the making or issuance of any request, rules, guideline, requirement or directive (whether or not having the force of law) by any Governmental Authority; provided, however, that notwithstanding anything herein to the contrary, (i) the Dodd-Frank Wall Street Reform and Consumer Protection Act and all requests, rules, guidelines, requirements and directives thereunder, issued in connection therewith or in implementation thereof, and (ii) all requests, rules, guidelines, requirements and directives promulgated by the Bank for International Settlements, the Basel Committee on Banking Supervision (or any successor or similar authority) or the United States or foreign regulatory authorities, in each case pursuant to Basel III, shall in each case be deemed a “Change in Law” regardless of the date enacted, adopted, issued or implemented.

“Commitment” means, as to any Lender, its obligation to make a Loan to the Borrower pursuant to Section 2.01, in an aggregate principal amount not to exceed the amount set forth opposite such Lender’s name on Schedule 1.01 under the column “Commitment”. “Commitments” means the total of the Lenders’ Commitments hereunder. The Commitments shall in no event exceed $100,000,000.

“Consolidated” refers to the consolidation of accounts in accordance with GAAP.

“Consolidated Indebtedness” means, at any date, the Indebtedness of the Borrower and its Consolidated Subsidiaries determined on a Consolidated basis as of such date; provided, however, that so long as the creditors of the VIE Lessor Trusts have no recourse to the assets of the Borrower, “Consolidated Indebtedness” shall not include any Indebtedness or other obligations of the VIE Lessor Trusts.

“Consolidated Net Worth” means, at any date, the sum as of such date of (a) the par value (or value stated on the books of the Borrower) of all classes of capital stock of the Borrower and its Subsidiaries, excluding the Borrower’s capital stock owned by the Borrower and/or its Subsidiaries, plus (or minus in the case of a surplus deficit) (b) the amount of the Consolidated surplus, whether capital or earned, of the Borrower, determined in accordance with GAAP as of the end of the most recent calendar month (excluding the effect on the Borrower’s accumulated other comprehensive income/loss of the ongoing application of Accounting Standards Codification Topic 815).

“Consolidated Subsidiary” means, at any date, any Subsidiary or other entity the accounts of which would be Consolidated with those of the Borrower on its Consolidated financial statements if such financial statements were prepared as of such date; provided that in no event will Consolidated Subsidiaries include the VIE Lessor Trusts.

“Controlled Affiliate” has the meaning specified in Section 4.01(n).

“Convert”, “Conversion” and “Converted” each refers to a conversion of Loans of one Type into Loans of the other Type pursuant to Section 2.06, Section 2.07 or Section 2.10.

“Debtor Relief Laws” means the Bankruptcy Code of the United States of America, and all other liquidation, conservatorship, bankruptcy, assignment for the benefit of creditors, moratorium, rearrangement, receivership, insolvency, reorganization, or similar debtor relief Laws of the United States of America or other applicable jurisdictions from time to time in effect and affecting the rights of creditors generally.

“Default” means any Event of Default or any event that would constitute an Event of Default but for the requirement that notice be given or time elapse or both.

“Dollars” or “$” means dollars of the United States of America.

“Domestic Lending Office” means, with respect to any Lender, the office of such Lender described as such in such Lender’s Administrative Questionnaire, or such other office or offices as a Lender may from time to time notify the Borrower and the Agent.

“EEA Financial Institution” means (a) any credit institution or investment firm established in any EEA Member Country which is subject to the supervision of an EEA Resolution Authority, (b) any entity established in an EEA Member Country which is a parent of an institution described in clause (a) of this definition, or (c) any financial institution established in an EEA Member Country which is a subsidiary of an institution described in clauses (a) or (b) of this definition and is subject to consolidated supervision with its parent;

“EEA Member Country” means any of the member states of the European Union, Iceland, Liechtenstein, and Norway.

“EEA Resolution Authority” means any public administrative authority or any person entrusted with public administrative authority of any EEA Member Country (including any delegee) having responsibility for the resolution of any EEA Financial Institution.

“Effective Date” has the meaning specified in Section 3.01.

“Eligible Assignee” means any Person that meets the requirements to be an assignee under Section 8.07(b)(iii) and (v), (subject to such consents, if any, as may be required under Section 8.07(b)(iii)).

“Environmental Action” means any action, suit, demand, demand letter, claim, notice of non-compliance or violation, notice of liability or potential liability, investigation, proceeding, consent order or consent agreement relating in any way to any Environmental Law, Environmental Permit or Hazardous Materials or arising from alleged injury or threat of injury to health, safety or the environment and relating to any Environmental Law, including, without limitation, (a) by any Governmental Authority for enforcement, cleanup, removal, response, remedial or other actions or damages and (b) by any Governmental Authority or any third party for damages, contribution, indemnification, cost recovery, compensation or injunctive relief.

“Environmental Law” means any federal, state, local or foreign statute, law, ordinance, rule, regulation, code, order, judgment, decree or judicial or agency interpretation, policy or guidance relating to pollution or protection of the environment, natural resources or, to the extent relating to exposure to Hazardous Materials, human health or safety, including, without limitation, those relating to the use, handling, transportation, treatment, storage, disposal, release or discharge of Hazardous Materials.

“Environmental Permit” means any permit, approval, identification number, license or other authorization required under any Environmental Law.

“ERISA” means the Employee Retirement Income Security Act of 1974.

“ERISA Affiliate” means any trade or business (whether or not incorporated) under common control with the Borrower within the meaning of Section 414(b) or (c) of the Internal Revenue Code (and Sections 414(m) and (o) of the Internal Revenue Code for purposes of provisions relating to Section 412 of the Internal Revenue Code).

“ERISA Event” means (a) a Reportable Event with respect to a Pension Plan; (b) a withdrawal by the Borrower or any ERISA Affiliate from a Pension Plan subject to Section 4063 of ERISA during a plan year in which it was a substantial employer (as defined in Section 4001(a)(2) of ERISA) or a cessation of operations that is treated as such a withdrawal under Section 4062(e) of ERISA; (c) a complete or partial withdrawal by the Borrower or any ERISA Affiliate from a Multiemployer Plan or notification that a Multiemployer Plan is in reorganization; (d) the filing of a notice of intent to terminate, the treatment of a Plan amendment as a termination under Section 4041 or 4041A of ERISA, or the commencement of proceedings by the PBGC to terminate a Pension Plan or Multiemployer Plan; (e) an event or condition which constitutes grounds under Section 4042 of ERISA for the termination of, or the appointment of a trustee to administer, any Pension Plan or Multiemployer Plan; or (f) the imposition of any liability under Title IV of ERISA, other than for PBGC premiums due but not delinquent under Section 4007 of ERISA, upon the Borrower or any ERISA Affiliate.

“EU Bail-In Legislation Schedule” means the EU Bail-In Legislation Schedule published by the Loan Market Association (or any successor person), as in effect from time to time.

“Eurodollar Lending Office” means, with respect to any Lender, the office of such Lender described as such in such Lender’s Administrative Questionnaire, or such other office or offices as a Lender may from time to time notify the Borrower and the Agent.

“Eurodollar Rate” means:

(a) for any Interest Period with respect to a Eurodollar Rate Loan, the London interbank offered rate administered by ICE Benchmark Administration (or any other Person that takes over the administration of such rate for Dollars) (“ICE LIBOR”), as published by Reuters (or other commercially available source providing quotations of ICE LIBOR as designated by the Agent from time to time) at approximately 11:00 a.m., London time, two Business Days prior to the commencement of such Interest Period, for Dollar deposits (for delivery on the first day of such Interest Period) with a term equivalent to such Interest Period. If such rate is not available at such time for any reason, then the “Eurodollar Rate” for such Interest Period shall be the rate per annum determined by the Agent to be the rate at which deposits in dollars for delivery on the first day of such Interest Period in same day funds in the approximate amount of the Eurodollar Rate Loan being made, continued or converted by the Agent and with a term equivalent to such Interest Period would be offered by the Agent to major banks in the London interbank eurodollar market at their request at approximately 11:00 a.m. (London time) two Business Days prior to the commencement of such Interest Period; and

(b) for any interest rate calculation with respect to a Base Rate Loan, the rate per annum equal to (i) ICE LIBOR, at approximately 11:00 a.m., London time, two Business Days prior to the date of determination (provided that if such day is not a Business Day in London, the next preceding Business Day in London) for Dollar deposits being delivered in the London interbank market for a term of one month commencing that day or (ii) if such published rate is not available at such time for any reason, the rate determined by the Agent to be the rate at which deposits in Dollars for delivery on the date of determination in same day funds in the approximate amount of the Base Rate Loan being made, continued or converted by the Agent and with a term equal to one month would be offered by the Agent’s London Branch to major banks in the London interbank Eurodollar market at their request at the date and time of determination;

provided that, if the Eurodollar Rate shall be less than zero, such rate shall be deemed to be zero for purposes of this Agreement.

“Eurodollar Rate Loan” means a Loan that bears interest at a rate based on the Eurodollar Rate (other than a Base Rate Loan bearing interest at a rate based on the Eurodollar Rate).

“Events of Default” has the meaning specified in Section 6.01.

“Excluded Taxes” means, with respect to the Agent, any Lender or any other recipient of any payment to be made by or on account of any obligation of the Borrower hereunder, (a) Taxes imposed on or measured by its overall net income (however denominated), and franchise Taxes imposed on it (in lieu of net income Taxes), by the United States of America or the jurisdiction (or any political subdivision thereof) under the Laws of which such recipient is organized or does business or in which its principal office is located or, in the case of any Lender, in which its Applicable Lending Office is located, (b) any branch profits Taxes imposed by the United States of America or any similar Tax imposed by any other jurisdiction in which the Borrower is located, (c) any backup withholding Tax that is required by the Internal Revenue Code to be withheld from amounts payable to a Lender that has failed to comply with clause (A) of Section 2.12(e)(ii), (d)in the case of a Foreign Lender (other than as agreed to between any assignee and the Borrower pursuant to a request by the Borrower under Section 2.17), any United States of America withholding Tax that (i) is required to be imposed on amounts payable to such Foreign Lender pursuant to the Laws in force at the time such Foreign Lender becomes a party hereto (or designates a new Applicable Lending Office) or (ii) is attributable to such Foreign Lender’s failure or inability (other than as a result of a Change in Law) to comply with clause (B) of Section 2.12(e)(ii), except to the extent that such Foreign Lender (or its assignor, if any) was entitled, at the time of designation of a new Applicable Lending Office (or assignment), to receive additional amounts from the Borrower with respect to such withholding Tax pursuant to Section 2.12(a)(i) or (ii); and (e) any United States withholding Tax imposed by FATCA.

“Executive Order” has the meaning specified in Section 4.01(p).

“FATCA” means Sections 1471 through 1474 of the Internal Revenue Code, as of the date of this Agreement (or any amended or successor version that is substantively comparable and not materially more onerous to comply with), any current or future regulations or official interpretations thereof and any agreement entered into pursuant to Section 1471(b)(1) of the Internal Revenue Code.

“Federal Funds Rate” means, for any day, the rate per annum equal to the weighted average of the rates on overnight federal funds transactions with members of the Federal Reserve System arranged by federal funds brokers on such day, as published by the Federal Reserve Bank of New York on the Business Day next succeeding such day; provided that (a) if such day is not a Business Day, the Federal Funds Rate for such day shall be such rate on such transactions on the next preceding Business Day as so published on the next succeeding Business Day, (b) if no such rate is so published on such next succeeding Business Day, the Federal Funds Rate for such day shall be the average rate (rounded upward, if necessary, to a whole multiple of 1/100 of 1%) charged to the Agent on such day on such transactions as determined by the Agent; provided further, that if the Federal Funds Rate shall be less than zero, such rate shall be deemed to be zero for purposes of this Agreement.

“Fee Letter” means that certain Administrative Agent Fee Letter dated as April 22, 2016, between the Agent and the Borrower, as amended, modified, restated or supplemented from time to time.

“Foreign Lender” means any Lender that is organized under the Laws of a jurisdiction other than that in which the Borrower is resident for tax purposes. For purposes of this definition, the United States of America, each State thereof and the District of Columbia shall be deemed to constitute a single jurisdiction.

“Four Corners Acquisition” means the acquisition by the Borrower from Southern California Edison Company (“SCE”) of SCE’s interests in Units 4 and 5 of the Four Corners Power Plant near Farmington, New Mexico, pursuant to the Purchase and Sale Agreement, dated as of November 8, 2010, by and between SCE and the Borrower.

“Fund” means any Person (other than a natural person) that is (or will be) engaged in making, purchasing, holding or otherwise investing in commercial loans and similar extensions of credit in the ordinary course of its business.

“GAAP” has the meaning specified in Section 1.03.

“Governmental Authority” means the government of the United States of America or any other nation, or of any political subdivision thereof, whether state or local, and any agency, authority, instrumentality, regulatory body, court, central bank or other entity exercising executive, legislative, judicial, taxing, regulatory or administrative powers or functions of or pertaining to government (including any supra-national bodies such as the European Union or the European Central Bank) and any group or body charged with setting financial accounting or regulatory capital rules or standards (including, without limitation, the Financial Accounting Standards Board, the Bank for International Settlements or the Basel Committee on Banking Supervision or any successor or similar authority to any of the foregoing).

“Government Official” shall mean (a) an executive, official, employee or agent of a governmental department, agency or instrumentality, (b) a director, officer, employee or agent of a wholly or partially government owned or controlled company or business, (c) a political party or official thereof, or candidate for political office or (d) an executive, official, employee or agent of a public international organization (e.g., the International Monetary Fund or the World Bank).

“Guarantee” means as to any Person, any obligation, contingent or otherwise, of such Person directly or indirectly guaranteeing any Indebtedness of any other Person or in any manner providing for the payment of any Indebtedness of any other Person or otherwise protecting the holder of such Indebtedness against loss (whether by virtue of partnership arrangements, agreements to keep well, to purchase assets, goods, securities or services, or to take-or-pay or otherwise), provided that the term “Guarantee” shall not include endorsements for collection or deposit in the ordinary course of business. The term “Guarantee” used as a verb has a corresponding meaning.

“Hazardous Materials” means (a) petroleum and petroleum products, byproducts or breakdown products, radioactive materials, asbestos-containing materials, polychlorinated biphenyls and radon gas and (b) any other chemicals, materials or substances designated, classified or regulated as hazardous or toxic or as a pollutant or contaminant under any Environmental Law.

“Hedge Agreement” means any interest rate swap, cap or collar agreement, interest rate future or option contract, currency swap agreement, currency future or option contract, commodity future or option contract, commodity forward contract or other similar agreement.

“Indebtedness” means as to any Person at any date (without duplication): (a) indebtedness created, issued, incurred or assumed by such Person for borrowed money or evidenced by bonds, debentures, notes or similar instruments; (b) all obligations of such Person to pay the deferred purchase price of property or services, excluding, however, trade accounts payable (other than for borrowed money) arising in, and accrued expenses incurred in, the ordinary course of business of such Person so long as such trade accounts payable are paid within 180 days of the date incurred (unless subject to a good faith dispute); (c) all Indebtedness secured by a Lien on any asset of such Person, to the extent such Indebtedness has been assumed by, or is a recourse obligation of, such Person; (d) all Guarantees by such Person; (e) all Capital Lease Obligations of such Person; and (f) the amount of all reimbursement obligations of such Person (whether contingent or otherwise) in respect of letters of credit, bankers’ acceptances, surety or other bonds and similar instruments in support of Indebtedness.

“Indemnified Taxes” means Taxes other than Excluded Taxes.

“Ineligible Institution” means (a) a natural person, (b) an Affected Lender or any of its Subsidiaries, (c) the Borrower, any of its Subsidiaries or any of its Affiliates, or (d) a company, investment vehicle or trust for, or owned and operated for the primary benefit of, a natural person or relative(s) thereof.

“Initial Borrowing” means the Loans made by the Initial Lenders on the Effective Date pursuant to Section 2.01 hereof.

“Initial Lenders” has the meaning given to such term in the introductory paragraph hereof.

“Interest Election Request” means a written request by the Borrower to Convert or continue a Borrowing in accordance with the definition of “Interest Period” contained in this Section 1.01 and/or Section 2.07, as applicable, in each case in substantially the form of Exhibit D hereto.

“Interest Period” means, for each Eurodollar Rate Loan comprising part of the same Borrowing, the period commencing on (i) the date such Eurodollar Rate Loan is disbursed, (ii) the date of the Conversion of any Base Rate Loan into such Eurodollar Rate Loan or (iii) the effective date of the most recent continuation of such Eurodollar Rate Loan, as the case may be, and ending on the last day of the period selected by the Borrower pursuant to the provisions below and, thereafter, each subsequent period commencing on the last day of the immediately preceding Interest Period and ending on the last day of the period selected by the Borrower pursuant to the provisions below. The duration of each such Interest Period shall be one, two, three or six months, as the Borrower may, upon notice (in the form of an Interest Election Request duly completed and executed by the Borrower) received by the Agent not later than 12:00 noon on the third Business Day prior to the first day of such Interest Period, select; provided, however, that:

(a) the Borrower may not select any Interest Period that ends after the Maturity Date;

(b) Interest Periods commencing on the same date for Eurodollar Rate Loans comprising part of the same Borrowing shall be of the same duration;

(c) whenever the last day of any Interest Period would otherwise occur on a day other than a Business Day, the last day of such Interest Period shall be extended to occur on the next succeeding Business Day, provided, however, that, if such extension would cause the last day of such Interest Period to occur in the next following calendar month, the last day of such Interest Period shall occur on the next preceding Business Day; and

(d) whenever the first day of any Interest Period occurs on a day of an initial calendar month for which there is no numerically corresponding day in the calendar month that succeeds such initial calendar month by the number of months equal to the number of months in such Interest Period, such Interest Period shall end on the last Business Day of such succeeding calendar month.

“Internal Revenue Code” means the Internal Revenue Code of 1986, as amended from time to time, and the regulations promulgated and rulings issued thereunder.

“Laws” means, collectively, all international, foreign, Federal, state and local statutes, treaties, rules, guidelines, regulations, ordinances, codes and administrative or judicial precedents or authorities, including the interpretation or administration thereof by any Governmental Authority charged with the enforcement, interpretation or administration thereof, and all applicable administrative orders, directed duties, licenses, authorizations and permits of, and agreements with, any Governmental Authority.

“Lenders” means the Initial Lenders and each Person that shall become a party hereto pursuant to Section 8.07.

“Lien” means any mortgage, pledge, hypothecation, assignment, deposit arrangement, encumbrance, lien (statutory or otherwise), charge or other security interest or preferential arrangement that has the practical effect of creating a security interest, including, without limitation, the lien or retained security title of a conditional vendor and any easement, right of way or other encumbrance on title to real property, and any Capital Lease having substantially the same economic effect as any of the foregoing.

“Loans” has the meaning specified in Section 2.01.

“Loan Documents” mean this Agreement, each Note and the Fee Letter.

“Material Adverse Effect” means a material adverse effect on (a) the financial condition, operations, business or properties of the Borrower and its Subsidiaries taken as a whole, (b) the rights and remedies of the Agent or any Lender under this Agreement or any Note or (c) the ability of the Borrower to perform its obligations under this Agreement or any Note.

“Material Subsidiary” means at any time, any Subsidiary of the Borrower which as of such time meets the definition of a “significant subsidiary” included as of the date hereof in Regulation S-X of the Securities and Exchange Commission or whose assets at such time exceed 10% of the assets of the Borrower and the Subsidiaries (on a Consolidated basis).

“Maturity Date” means April 22, 2019.

“Moody’s” means Moody’s Investors Service, Inc.

“Multiemployer Plan” means any employee benefit plan of the type described in Section 4001(a)(3) of ERISA, to which the Borrower or any ERISA Affiliate makes or is obligated to make contributions, or during the preceding five plan years, has made or been obligated to make contributions.

“Note” means a promissory note of the Borrower payable to the order of any Lender, delivered pursuant to a request made under Section 2.14, in substantially the form of Exhibit A hereto.

“Notice of Initial Borrowing” has the meaning specified in Section 2.02(a).

“Obligations” means all loans to, and debts, liabilities, obligations, covenants and duties of, the Borrower arising under any Loan Document or otherwise with respect to any Loan, whether direct or indirect (including those acquired by assumption), absolute or contingent, due or to become due, now existing or hereafter arising and including interest and fees that accrue under any Loan Document after the commencement by or against the Borrower of any proceeding under any Debtor Relief Laws naming such Person as the debtor in such proceeding, regardless of whether such interest and fees are allowed claims in such proceeding.

“OFAC” means Office of Foreign Assets Control of the United States Department of the Treasury.

“Other Taxes” means all present or future stamp or documentary taxes or any other excise or property taxes, charges or similar levies arising from any payment made hereunder or under any other Loan Document or from the execution, delivery or enforcement of, or otherwise with respect to, this Agreement or any other Loan Document.

“Participant” has the meaning specified in Section 8.07(d).

“Participant Register” has the meaning specified in Section 8.07(d).

“PATRIOT Act” means the USA PATRIOT Act (Title III of Pub. L. 107-56 (signed into law October 26, 2001)), as amended.

“PBGC” means the Pension Benefit Guaranty Corporation.

“Pension Plan” means any “employee pension benefit plan” (as such term is defined in Section 3(2) of ERISA), other than a Multiemployer Plan, that is subject to Title IV of ERISA and is sponsored or maintained by the Borrower or any ERISA Affiliate or to which the Borrower or any ERISA Affiliate contributes or has an obligation to contribute, or in the case of a multiple employer or other plan described in Section 4064(a) of ERISA, has made contributions at any time during the immediately preceding five plan years.

“Permitted Lien” of the Borrower or any Material Subsidiary means any of the following:

(i)Liens for taxes, assessments or other governmental charges or levies not at the time delinquent or thereafter payable without penalty or being contested in good faith by appropriate proceedings and for which adequate reserves in accordance with GAAP shall have been made;

(ii) Liens imposed by or arising by operation of law, such as Liens of carriers, warehousemen, mechanics, materialmen and landlords incurred in the ordinary course of business, including, without limitation, landlord’s liens arising under Arizona Law under leases entered into by the Borrower in the 1986 sale and leaseback transactions with respect to PVNGS Unit 2 and securing the payment of rent under such leases, in each case, for sums not overdue for a period of more than 30 days or being contested in good faith by appropriate proceedings and for which adequate reserves in accordance with GAAP shall have been made;

(iii) Liens incurred in the ordinary course of business in connection with worker’s compensation, unemployment insurance or other forms of governmental insurance or benefits or other similar statutory obligations;

(iv) Liens to secure obligations on surety or appeal bonds;

(v) Liens on cash deposits in the nature of a right of setoff, banker’s lien, counterclaim or netting of cash amounts owed arising in the ordinary course of business on deposit accounts, commodity accounts or securities accounts;

(vi) easements, restrictions, reservations, licenses, covenants, and other defects of title that are not, in the aggregate, materially adverse to the use of such property for the purpose for which it is used;

(vii) Liens securing claims against or other obligations of any Person other than the Borrower or any Subsidiary of the Borrower neither assumed nor guaranteed by the Borrower or any Subsidiary of the Borrower nor on which the Borrower or any Subsidiary of the Borrower customarily pays interest, existing upon real estate or rights in or relating to real estate acquired by the Borrower or any Subsidiary of the Borrower for use in the operation of the business of the Borrower or any Subsidiary of the Borrower, including, without limitation, for the generation, transmission or distribution of electric energy, transportation, telephonic, telegraphic, radio, wireless or other electronic communication or any other purpose;

(viii) rights reserved to or vested in and Liens on assets arising out of obligations or duties to any municipality or public authority with respect to any right, power, franchise, grant, license or permit, or by any provision of Law;

(ix) rights reserved to or vested in others to take or receive any part of the power pursuant to firm power commitment contracts, purchased power contracts, tolling agreements and similar agreements, coal, gas, oil or other minerals, timber or other products generated, developed, manufactured or produced by, or grown on, or acquired with, any property of the Borrower;

(x) rights reserved to or vested in any municipality or public authority to control or regulate any property of the Borrower, or to use such property in a manner that does not materially impair the use of such property for the purposes for which it is held by the Borrower;

(xi) security interests granted in favor of the lessors in the Borrower’s Decommissioning Trust Agreement (PVNGS Unit 2) dated as of January 31, 1992 (such agreement, as amended or otherwise modified from time to time, being the “Unit 2 Trust Agreement”) entered into in connection with the PVNGS Unit 2 sale leaseback transaction to secure the Borrower’s obligations in respect of the decommissioning of PVNGS Unit 2 or related facilities;

(xii) Liens that may exist with respect to the Unit 2 Trust Agreement (other than as described in paragraph (xi) above) or with respect to either of the Borrower’s Decommissioning Trust Agreement (PVNGS Unit 1) or Decommissioning Trust Agreement (PVNGS Unit 3), each dated as of July 1, 1991, as amended or otherwise modified from time to time, relating to the Borrower’s obligation to set aside funds for the decommissioning and retirement from service of such Units;

(xiii) pledges of pollution control bonds and related rights to secure the Borrower’s reimbursement obligations in respect of letters of credit, bond insurance, and other credit or liquidity enhancements supporting pollution control bond transactions, provided that such pollution control bonds are not secured by any other assets of the Borrower or any Material Subsidiary;

(xiv) rights and interests of Persons other than the Borrower or any Material Subsidiary (including, without limitation, acquisition rights), related obligations of the Borrower or any Material Subsidiary and restrictions on it or its property arising out of contracts, agreements and other instruments to which the Borrower or any Material Subsidiary is a party that relate to the common ownership or joint use of property or other use of property for the benefit of one or more third parties or that allow a third party to purchase property of the Borrower or any Material Subsidiary and all Liens on the interests of Persons other than the Borrower or any Material Subsidiary in such property;

(xv) transfers of operational or other control of facilities to a regional transmission organization or other similar body and Liens on such facilities to cover expenses, fees and other costs of such an organization or body;

(xvi) Liens established on specified bank accounts of the Borrower to secure the Borrower’s reimbursement obligations in respect of letters of credit supporting commercial paper issued by the Borrower and similar arrangements for collateral security with respect to refinancings or replacements of the same;

(xvii) rights of transmission users or any regional transmission organizations or similar entities in transmission facilities;

(xviii) Liens on property of the Borrower sold in a transaction permitted by Section 5.02(a) to another Person pursuant to a conditional sales agreement where the Borrower retains title;

(xix) Liens created under this Agreement;

(xx) Liens on cash or cash equivalents not to exceed $200,000,000 (A) deposited in margin accounts with or on behalf of futures contract brokers or paid over to other contract counterparties or (B) pledged or deposited as collateral to a contract counterparty to secure obligations with respect to (1) contracts (other than for Indebtedness) for commercial and trading activities in the ordinary course of business for the purchase, transmission, distribution, sale, storage, lease or hedge of any energy or energy related commodity or (2) Hedge Agreements;

(xxi) Liens granted on cash or cash equivalents to defease Indebtedness of the Borrower or any of its Subsidiaries;

(xxii) Liens granted on cash or cash equivalents constituting proceeds from any sale or disposition of assets that is not prohibited by Section 5.02(c) deposited in escrow accounts or otherwise withheld or set aside to secure obligations of the Borrower or any Subsidiary providing for indemnification, adjustment of purchase price or any similar obligations, in each case, in an amount not to exceed the amount of gross proceeds received by the Borrower or any Subsidiary in connection with such sale or disposition;

(xxiii) Liens, deposits and similar arrangements to secure the performance of bids, tenders or contracts (other than contracts for borrowed money), public or statutory obligations, performance bonds and other obligations of a like nature incurred in the ordinary course of business by the Borrower or any of its Subsidiaries;

(xxiv) rights of lessees arising under leases entered into by the Borrower or any of its Subsidiaries as lessor, in the ordinary course of business;

(xxv) any Liens on or reservations with respect to governmental and other licenses, permits, franchises, consents and allowances;

(xxvi) Liens on property which is the subject of a Capital Lease Obligation designating the Borrower or any of its Subsidiaries as lessee and all right, title and interest of the Borrower or any of its Subsidiaries in and to such property and in, to and under such lease agreement, whether or not such lease agreement is intended as a security;

(xxvii) licenses of intellectual property entered into in the ordinary course of business;

(xxviii) Liens solely on any cash earnest money deposits made by the Borrower or any of its Subsidiaries in connection with any letter of intent or purchase agreement permitted hereunder;

(xxix) deposits or funds established for the removal from service of operating facilities and coal mines and related facilities or other similar facilities used in connection therewith; and

(xxx) Liens on cash deposits used to secure letters of credit under defaulting lender provisions in credit or reimbursement facilities;

provided, however, that no Lien in favor of the PBGC shall, in any event, be a Permitted Lien.

“Percentage” means, with respect to any Lender at any time, a fraction the numerator of which is the outstanding principal amount of such Lender’s Loans at such time and the denominator of which is the aggregate outstanding principal amount of all Loans at such time; provided, that (i) the initial Percentage of each Lender shall be the percentage set forth opposite such Lender’s name on Schedule 1.01 under the column “Ratable Share” and (ii) if the outstanding principal amount of all Loans has been repaid in full, the Percentage of each Lender shall be such Lender’s Percentage as in effect immediately prior to such repayment.

“Person” means an individual, partnership, corporation (including a business trust), joint stock company, trust, unincorporated association, joint venture, limited liability company or other entity, or a government or any political subdivision or agency thereof.

“Plan” means any “employee benefit plan” (as such term is defined in Section 3(3) of ERISA) established by the Borrower or, with respect to any such plan that is subject to Section 412 of the Internal Revenue Code or Title IV of ERISA, any ERISA Affiliate.

“Prohibited Person” means any Person (a) listed in the Annex to the Executive Order or identified pursuant to Section 1 of the Executive Order; (b) that is owned or controlled by, or acting for or on behalf of, any Person listed in the Annex to the Executive Order or identified pursuant to the provisions of Section 1 of the Executive Order; (c) with whom a Lender is prohibited from dealing or otherwise engaging in any transaction by any terrorism or anti-laundering law, including the Executive Order; (d) who commits, threatens, conspires to commit, or support “terrorism” as defined in the Executive Order; (e) who is named as a “Specially designated national or blocked person” on the most current list published by the OFAC at its official website, at http://www.treas.gov/offices/enforcement/ofac/sdn/t11sdn.pdf or any replacement website or other replacement official publication of such list; or (f) who is owned or controlled by a Person listed above in clause (c) or (e).

“Prime Rate” means the rate of interest per annum announced from time to time by Toronto Dominion (Texas) LLC as its prime rate in effect at its principal office in New York, New York; each change in the Prime Rate shall be effective from and including the date such change is announced as being effective.

“Public Debt Rating” means, as of any date, the rating that has been most recently announced by either S&P or Moody’s, as the case may be, for any class of non-credit enhanced long-term senior unsecured debt issued by the Borrower (or, if any such rating agency shall have issued more than one such rating, the lowest such rating issued by such rating agency). For purposes of the foregoing, (a) if only one of S&P and Moody’s shall have in effect a Public Debt Rating, the Applicable Rate shall be determined by reference to the available rating; (b) except as set forth in the proviso at the end of this definition, if neither S&P nor Moody’s shall have in effect a Public Debt Rating, the Applicable Rate will be set in accordance with Level 6 under the definition of “Applicable Rate”; (c) if the ratings established by S&P and Moody’s shall fall within different levels, the Applicable Rate shall be based upon the higher rating unless such ratings differ by two or more levels, in which case the applicable level will be deemed to be one level below the higher of such levels; and (d) if any rating established by S&P or Moody’s shall be changed (other than as a result of a change in the basis on which ratings are established), such change shall be effective as of the date on which such change is first announced publicly by the rating agency making such change; provided that if the Public Debt Rating system of S&P or Moody’s shall change, or if either such rating agency shall cease to be in the business of rating corporate debt obligations, the Borrower and the Lenders shall negotiate in good faith to amend the definition of “Applicable Rate” to reflect such changed rating system or the unavailability of ratings from such rating agency and, pending the effectiveness of any such amendment, the Applicable Rate will be set in accordance with the level most recently in effect under the definition of “Applicable Rate” prior to such change or cessation.

“PVNGS” means the Palo Verde Nuclear Generating Station.

“PWCC” means Pinnacle West Capital Corporation, an Arizona corporation.

“Ratable Share” of any amount means, with respect to any Lender at any time, the product of such amount times such Lender’s Percentage.

“Register” has the meaning specified in Section 8.07(c).

“Related Parties” means, with respect to any Person, such Person’s Affiliates and the partners, directors, officers, employees, agents, trustees and advisors of such Person and of such Person’s Affiliates.

“Reportable Event” means any of the events set forth in Section 4043(c) of ERISA, other than events for which the 30-day notice period has been waived under the final regulations issued under Section 4043, as in effect as of the date of this Agreement (the “Section 4043 Regulations”). Any changes made to the Section 4043 Regulations that become effective after the Effective Date shall have no impact on the definition of Reportable Event as used herein unless otherwise amended by the Borrower and the Required Lenders.

“Required Lenders” means, as of any date of determination, but subject to Section 2.16, Lenders holding in the aggregate more than 50% of the aggregate outstanding principal amount of all Loans (or, if all Loans have been repaid in full, more than 50% of the aggregate amount of all outstanding Obligations); provided that at all times when two or more Lenders (excluding Affected Lenders) are party to this Agreement, the term “Required Lenders” shall in no event mean less than two Lenders.

“S&P” means Standard & Poor’s Ratings Services, a division of The McGraw-Hill Companies, Inc.

“Sale Leaseback Obligation Bonds” means any bonds issued by or on behalf of the Borrower in connection with a sale/leaseback transaction and any refinancing or refunding of such obligations.

“Sanctions” means economic or financial sanctions or trade embargoes imposed, administered or enforced from time to time by OFAC and any similar economic or financial sanctions or trade embargoes of the type described in Sections 4.01(n) through (q) and imposed, administered or enforced from time to time by the U.S. government, including the U.S. Department of State.

“SEC Reports” means the Borrower’s (i) Form 10-K Report for the fiscal year ended December 31, 2015, as filed with the Securities and Exchange Commission.

“Subsequent Order” means any decision, order or ruling of the Arizona Corporation Commission issued after the Effective Date relating to the incurrence or maintenance of Indebtedness by the Borrower and that amends, supersedes or otherwise modifies the 2013 Order or any successor decision, order or ruling.

“Subsidiary” of any Person means any corporation, partnership, joint venture, limited liability company, trust or estate of which (or in which) more than 50% of (a) the issued and outstanding Voting Stock, (b) the interest in the capital or profits of such limited liability company, partnership or joint venture or (c) the beneficial interest in such trust or estate, is at the time directly or indirectly owned or controlled by such Person, by such Person and one or more of its other Subsidiaries or by one or more of such Person’s other Subsidiaries; provided that in no event will Subsidiaries include the VIE Lessor Trusts.

“Taxes” means all present or future taxes, levies, imposts, duties, deductions, withholdings (including backup withholding), assessments, fees or other charges imposed by any Governmental Authority, including any interest, additions to tax or penalties applicable thereto.

“Type”, when used in reference to any Loan or Borrowing, refers to whether the rate of interest on such Loan, or on the Loans comprising such Borrowing, is determined by reference to the Eurodollar Rate or the Base Rate.

“VIE Lessor Trusts” means the three (3) separate variable-interest entity lessor trusts that purchased from, and leased back to, the Borrower certain interests in the PVNGS Unit 2 and related common facilities, as described in Note 18 of Notes to Condensed Consolidated Financial Statements in the Borrower’s Annual Report on Form 10-K for the fiscal year ended December 31, 2015.

“Voting Stock” means capital stock issued by a corporation, or equivalent interests in any other Person, the holders of which are ordinarily, in the absence of contingencies, entitled to vote for the election of directors (or persons performing similar functions) of such Person, even if the right so to vote has been suspended by the happening of such a contingency.

“Write-Down and Conversion Powers” means, with respect to any EEA Resolution Authority, the write-down and conversion powers of such EEA Resolution Authority from time to time under the Bail-In Legislation for the applicable EEA Member Country, which write-down and conversion powers are described in the EU Bail-In Legislation Schedule.

Section 1.02 Other Interpretive Provisions. With reference to this Agreement and each other Loan Document, unless otherwise specified herein or in such other Loan Document:

(a) The definitions of terms herein shall apply equally to the singular and plural forms of the terms defined. Whenever the context may require, any pronoun shall include the corresponding masculine, feminine and neuter forms. The words “include,” “includes” and “including” shall be deemed to be followed by the phrase “without limitation.” The word “will” shall be construed to have the same meaning and effect as the word “shall.” Unless the context requires otherwise, (i) any definition of or reference to any agreement, instrument or other document shall be construed as referring to such agreement, instrument or other document as from time to time amended, restated, supplemented or otherwise modified (subject to any restrictions on such amendments, restatements, supplements or modifications set forth herein or in any other Loan Document), (ii) any reference herein to any Person shall be construed to include such Person’s permitted successors and permitted assigns, (iii) the words “herein,” “hereof” and “hereunder,” and words of similar import when used in any Loan Document, shall be construed to refer to such Loan Document in its entirety and not to any particular provision thereof, (iv) all references in a Loan Document to Articles, Sections, Exhibits and Schedules shall be construed to refer to Articles and Sections of, and Exhibits and Schedules to, the Loan Document in which such references appear, (v) any reference to any law shall include all statutory and regulatory provisions consolidating, amending, replacing or interpreting such law and any reference to any law or regulation shall, unless otherwise specified, refer to such law or regulation as amended, modified or supplemented from time to time, and (vi) the words “asset” and “property” shall be construed to have the same meaning and effect and to refer to any and all tangible and intangible assets and properties, including cash, securities, accounts and contract rights.

(b) In the computation of periods of time from a specified date to a later specified date, the word “from” means “from and including;” the words “to” and “until” each mean “to but excluding;” and the word “through” means “to and including.”

(c) Section headings herein and in the other Loan Documents are included for convenience of reference only and shall not affect the interpretation of this Agreement or any other Loan Document.

Section 1.03 Accounting Terms. Unless otherwise specified herein, all accounting terms used herein shall be interpreted, all accounting determinations hereunder shall be made, and all financial statements required to be delivered hereunder shall be prepared, in accordance with generally accepted accounting principles as in effect from time to time, applied on a basis consistent (except for changes concurred in by the Borrower’s independent public accountants) with the most recent audited Consolidated financial statements of the Borrower delivered to the Agent (“GAAP”). If at any time any change in GAAP or in the interpretation thereof would affect the computation of any financial ratio or requirement set forth in any Loan Document, and either the Borrower or the Required Lenders shall so request, the Agent, the Lenders and the Borrower shall negotiate in good faith to amend such ratio or requirement to preserve the original intent thereof in light of such change in GAAP or in the interpretation thereof (subject to the approval of the Required Lenders); provided that, unless and until so amended, such ratio or requirement shall continue to be computed in accordance with GAAP prior to such change therein.

Section 1.04 Rounding. Any financial ratios required to be maintained by the Borrower pursuant to this Agreement shall be calculated by dividing the appropriate component by the other component, carrying the result to one place more than the number of places by which such ratio is expressed herein and rounding the result up or down to the nearest number (with a rounding-up if there is no nearest number).

Section 1.05 Times of Day. Unless otherwise specified, all references herein to times of day shall be references to Eastern time (daylight or standard, as applicable).

ARTICLE II

AMOUNTS AND TERMS OF THE LOANS

Section 2.01 The Loans.

Subject to the terms and conditions hereof (including, without limitation, Section 3.01), each Lender, by its acceptance hereof, severally agrees to make a one-time loan (individually, a “Loan” and, collectively, the “Loans”) to the Borrower on the Effective Date in Dollars in an aggregate principal amount equal to such Lender’s Commitment. As provided in Section 2.05, the Borrower may elect that each Borrowing of Loans be either Base Rate Loans or Eurodollar Rate Loans. Amounts borrowed by the Borrower hereunder and prepaid or otherwise repaid may not be reborrowed. Unless an earlier maturity is provided for hereunder, all Loans shall mature and be due and payable on the Maturity Date. The Commitments shall immediately and automatically terminate upon the earlier of (i) 5:00 p.m. on the Effective Date and (ii) the making of the Loans pursuant to this Section 2.01.

Section 2.02 Making the Loans.

(a) The Initial Borrowing shall be made on notice, given not later than (x) 12:00 noon on the third Business Day prior to the Effective Date in the case of an Initial Borrowing consisting of Eurodollar Rate Loans or (y) 12:00 noon on the Business Day prior to the Effective Date in the case of an Initial Borrowing consisting of Base Rate Loans, by the Borrower to the Agent, which shall give to each Lender prompt notice thereof by facsimile. Such notice of the Initial Borrowing (the “Notice of Initial Borrowing”) shall be in writing or by facsimile in substantially the form of Exhibit B hereto, specifying therein the requested (i) date of the Initial Borrowing (which shall be the Effective Date and a Business Day), (ii) Type of Loans comprising the Initial Borrowing, (iii) aggregate amount of the Initial Borrowing, and (iv) in the case of an Initial Borrowing consisting of Eurodollar Rate Loans, initial Interest Period for each such Loan. Each Lender shall, before 2:00 p.m. on the date of the Initial Borrowing, make available for the account of its Applicable Lending Office to the Agent at the Agent’s Account, in same day funds, such Lender’s Ratable Share of the Initial Borrowing. After the Agent’s receipt of such funds and upon fulfillment of the applicable conditions set forth in Article III, the Agent will make such funds available to the Borrower at the Agent’s address referred to in Section 8.02 or as requested by the Borrower in the Notice of Initial Borrowing.

(b) Anything in subsection (a) above to the contrary notwithstanding, (i) the Borrower may not select Eurodollar Rate Loans for any Borrowing if the aggregate amount of such Borrowing is less than $5,000,000 (or an integral multiple of $1,000,000 in excess thereof) or if the obligation of the Lenders to make Eurodollar Rate Loans shall then be suspended pursuant to Section 2.06 or 2.10, and (ii) at no time shall there be more than three (3) different Interest Periods outstanding for Eurodollar Rate Loans.

(c) The Notice of Initial Borrowing shall be irrevocable and binding on the Borrower. If the Notice of Initial Borrowing specifies that the Initial Borrowing is to be comprised of Eurodollar Rate Loans, the Borrower shall indemnify each Lender against any loss, cost or expense reasonably incurred by such Lender as a result of any failure (i) to fulfill on or before the date specified in the Notice of Initial Borrowing the applicable conditions set forth in Article III or (ii) to otherwise borrow the Eurodollar Rate Loans requested by the Borrower in the Notice of Initial Borrowing on such date (and shall set forth such indemnification obligation in the Notice of Initial Borrowing), including, without limitation, any loss (excluding loss of anticipated profits), cost or expense incurred by reason of the liquidation or reemployment of deposits or other funds acquired by such Lender to fund the Loan to be made by such Lender as part of the Initial Borrowing when such Loan, as a result of any such failure, is not made on such date.

(d) Unless the Agent shall have received notice from a Lender prior to the time of the Initial Borrowing that such Lender will not make available to the Agent such Lender’s Ratable Share of the Initial Borrowing, the Agent may assume that such Lender has made such portion available to the Agent on the date of the Initial Borrowing in accordance with subsection (a) of this Section 2.02 and the Agent may, in reliance upon such assumption, make available to the Borrower on such date a corresponding amount. If and to the extent that such Lender shall not have so made such Ratable Share available to the Agent, such Lender and the Borrower severally agree to repay to the Agent within one Business Day after demand for such Lender and within three Business Days after demand for the Borrower such corresponding amount together with interest thereon, for each day from the date such amount is made available to the Borrower until the date such amount is repaid to the Agent, at (i) in the case of the Borrower, the interest rate applicable at the time to Loans comprising the Initial Borrowing and (ii) in the case of such Lender, the Federal Funds Rate. If the Borrower and such Lender shall pay such interest to the Agent for the same or an overlapping period, the Agent shall promptly remit to the Borrower the amount of such interest paid by the Borrower for such period. If such Lender shall repay to the Agent such corresponding amount, such amount so repaid shall constitute such Lender’s Loan as part of the Initial Borrowing for purposes of this Agreement.

(e) The failure of any Lender to make the Loan to be made by it as part of the Initial Borrowing shall not relieve any other Lender of its obligation, if any, hereunder to make its Loan on the date of the Initial Borrowing, but no Lender shall be responsible for the failure of any other Lender to make the Loan to be made by such other Lender on the date of the Initial Borrowing.

Section 2.03 Agent’s Fees. The Borrower shall pay to the Agent for its own account such fees as are agreed between the Borrower and the Agent pursuant to the Fee Letter between the Borrower and the Agent.

Section 2.04 Repayment of Loans. The Borrower hereby unconditionally agrees to pay to the Agent on the Maturity Date, for the account of the Lenders and the Agent, the then unpaid principal amount of the Loans, together with all accrued and unpaid interest thereon, and all other outstanding Obligations.

Section 2.05 Interest on Loans.

(a) Scheduled Interest. The Borrower shall pay interest on the unpaid principal amount of each Loan owing to each Lender from the date of such Loan until such principal amount shall be paid in full, at the following rates per annum:

(i) Base Rate Loans. During such periods as such Loan is a Base Rate Loan, a rate per annum equal at all times to the sum of (x) the Base Rate in effect from time to time plus (y) the Applicable Rate for Base Rate Loans in effect from time to time, payable in arrears quarterly on the last day of each March, June, September and December during such periods and on the date such Base Rate Loan shall be Converted or paid in full.

(ii) Eurodollar Rate Loans. During such periods as such Loan is a Eurodollar Rate Loan, a rate per annum equal at all times during each Interest Period for such Loan to the sum of (x) the Eurodollar Rate for such Interest Period for such Loan plus (y) the Applicable Rate for Eurodollar Rate Loans in effect from time to time, payable in arrears on the last day of such Interest Period and, if such Interest Period has a duration of more than three months, on each day that occurs during such Interest Period every three months from the first day of such Interest Period and on the date such Eurodollar Rate Loan shall be Converted or paid in full.

(b) Default Interest. Upon the occurrence and during the continuance of an Event of Default under Section 6.01(a), the Agent may, and upon the request of the Required Lenders shall, require the Borrower to pay interest (“Default Interest”) on (i) the unpaid principal amount of each Loan owing to each Lender, payable in arrears on the dates referred to in clause (a)(i) or (a)(ii) above, at a rate per annum equal at all times to 2% per annum above the rate per annum required to be paid on such Loan pursuant to clause (a)(i) or (a)(ii) above and (ii) to the fullest extent permitted by Law, the amount of any interest, fee or other amount payable hereunder that is not paid when due, from the date such amount shall be due until such amount shall be paid in full, payable in arrears on the date such amount shall be paid in full and on demand, at a rate per annum equal at all times to 2% per annum above the rate per annum required to be paid on Base Rate Loans pursuant to clause (a)(i) above, provided, however, that following acceleration of the Loans pursuant to Section 6.01, Default Interest shall accrue and be payable hereunder whether or not previously required by the Agent.

(c) Interest Rate Limitation. Nothing contained in this Agreement or in any other Loan Document shall be deemed to establish or require the payment of interest to any Lender at a rate in excess of the maximum rate permitted by applicable Law. If the amount of interest payable for the account of any Lender on any interest payment date would exceed the maximum amount permitted by applicable Law to be charged by such Lender, the amount of interest payable for its account on such interest payment date shall be automatically reduced to such maximum permissible amount. In the event of any such reduction affecting any Lender, if from time to time thereafter the amount of interest payable for the account of such Lender on any interest payment date would be less than the maximum amount permitted by applicable Law to be charged by such Lender, then the amount of interest payable for its account on such subsequent interest payment date shall be automatically increased to such maximum permissible amount, provided that at no time shall the aggregate amount by which interest paid for the account of any Lender has been increased pursuant to this sentence exceed the aggregate amount by which interest paid for its account has theretofore been reduced pursuant to the previous sentence.

Section 2.06 Interest Rate Determination.

(a) The Agent shall give prompt notice to the Borrower and the Lenders of the applicable interest rate determined by the Agent for purposes of Section 2.05(a).

(b) If the Required Lenders determine that for any reason in connection with any request for a Eurodollar Rate Loan or a Conversion to or continuation thereof that (a) Dollar deposits are not being offered to banks in the London interbank eurodollar market for the applicable amount and Interest Period of such Eurodollar Rate Loan, (b) adequate and reasonable means do not exist for determining the Eurodollar Rate for any requested Interest Period with respect to a proposed Eurodollar Rate Loan, or (c) the Eurodollar Rate for any requested Interest Period with respect to a proposed Eurodollar Rate Loan does not adequately and fairly reflect the cost to such Lenders of funding such Loan, the Agent will promptly so notify the Borrower and each Lender, whereupon each Eurodollar Rate Loan will automatically on the last day of the then existing Interest Period therefor Convert into a Base Rate Loan. Thereafter, the obligation of the Lenders to make or maintain Eurodollar Rate Loans shall be suspended until the Agent (upon the instruction of the Required Lenders) revokes such notice. Upon receipt of such notice, the Borrower may revoke any pending request for a Borrowing of, Conversion to or continuation of Eurodollar Rate Loans or, failing that, will be deemed to have Converted such request into a request for a Base Rate Loan in the amount specified therein.

(c) If the Borrower shall fail to select the duration of any Interest Period for any Eurodollar Rate Loans in accordance with the provisions contained in the definition of “Interest Period” in Section 1.01, the Agent will forthwith so notify the Borrower and the Lenders and such Loans will automatically, on the last day of the then existing Interest Period therefor, Convert into Base Rate Loans.

(d) On the date on which the aggregate unpaid principal amount of Eurodollar Rate Loans comprising any Borrowing shall be reduced, by payment or prepayment or otherwise, to less than $5,000,000, such Loans shall automatically Convert into Base Rate Loans.

(e) Upon the occurrence and during the continuance of any Event of Default,

(i) with respect to Eurodollar Rate Loans, each such Loan will automatically, on the last day of the then existing Interest Period therefor, Convert into a Base Rate Loan (or if such Loan is then a Base Rate Loan, will continue as a Base Rate Loan); and

(ii) the obligation of the Lenders to Convert Loans into Eurodollar Rate Loans shall be suspended until the Agent shall notify the Borrower and the Lenders that the circumstances causing such suspension no longer exist.

Section 2.07 Optional Conversion of Loans. The Borrower may on any Business Day, upon notice given to the Agent (in the form of an Interest Election Request duly completed and executed by the Borrower) not later than 12:00 noon on the third Business Day prior to the date of the proposed Conversion and subject to the provisions of Section 2.06 and Section 2.10, Convert all or any portion of the Loans of one Type comprising the same Borrowing into Loans of the other Type; provided, however, that (a) any Conversion of Eurodollar Rate Loans into Base Rate Loans shall be made only on the last day of an Interest Period for such Eurodollar Rate Loans, (b) any Conversion of Base Rate Loans into Eurodollar Rate Loans shall be in an amount not less than the minimum amount specified in Section 2.02(b) and (c) no Conversion of any Loans shall result in more separate Borrowings than permitted under Section 2.02(b). Each such notice of a Conversion shall, within the restrictions specified above, specify (i) the date of such Conversion, (ii) the Loans to be Converted and (iii) if such Conversion is into Eurodollar Rate Loans, the duration of the initial Interest Period for each such Loan. Each Interest Election Request shall be irrevocable and binding on the Borrower.

Section 2.08 Prepayments of Loans.

(a) Optional. At any time and from time to time, the Borrower shall have the right to prepay the Loans, in whole or in part, without premium or penalty (except as provided in clause (z) below), upon notice at least two Business Days’ prior to the date of such prepayment, in the case of Eurodollar Rate Loans, and not later than 11:00 a.m. on the date of such prepayment, in the case of Base Rate Loans, to the Agent, which notice shall be in writing or by facsimile in substantially the form of Exhibit E hereto and shall specify the proposed date of such prepayment and the aggregate principal amount and Type of the Loans to be prepaid (and, in the case of Eurodollar Rate Loans, the Interest Period of the Borrowing pursuant to which made); provided, however, that (x) each partial prepayment shall be in an aggregate principal amount of $5,000,000 or an integral multiple of $1,000,000 in excess thereof, (y) accrued interest to the date of prepayment on the principal amount prepaid shall be payable by the Borrower on the date of such prepayment, and (z) in the event of any such prepayment of a Eurodollar Rate Loan, the Borrower shall be obligated to reimburse the Lenders in respect thereof pursuant to Section 8.04(e). Each prepayment of Loans shall be applied ratably to the outstanding principal amount of each Lender’s Loan in accordance with such Lender’s Ratable Share.

(b) Mandatory. The Borrower shall prepay the aggregate principal amount of the Loans, together with accrued interest to the date of prepayment on the principal amount prepaid, without requirement of demand therefor, or shall pay or prepay any other Indebtedness then outstanding at any time, when and to the extent required to comply with applicable Laws of any Governmental Authority, including the 2013 Order and/or any Subsequent Order, or applicable resolutions of the Board of Directors of the Borrower.

Section 2.09 Increased Costs.

(a) Increased Costs Generally. If any Change in Law shall:

(i) impose, modify or deem applicable any reserve, special deposit, compulsory loan, insurance charge or similar requirement against assets of, deposits with or for the account of, or credit extended or participated in by, any Lender (except any reserve requirement contemplated by Section 2.09(e));

(ii) impose on any Lender or the London interbank market any other condition, cost or expense affecting this Agreement or Eurodollar Rate Loans made by such Lender; or

(iii) subject the Agent or any Lender to any Taxes (other than (A) Indemnified Taxes, (B) Excluded Taxes and (C) Other Taxes) on its loans, loan principal, letters of credit, commitments, or other obligations, or its deposits, reserves, other liabilities or capital attributable thereto;

and the result of any of the foregoing shall be to increase the cost to the Agent or such Lender of making or maintaining any Loan (or of maintaining its obligation to make any such Loan), or to reduce the amount of any sum received or receivable by the Agent or such Lender hereunder (whether of principal, interest or any other amount) then, upon request of the Agent or such Lender, the Borrower will pay to the Agent or such Lender such additional amount or amounts as will compensate the Agent or such Lender for such additional costs incurred or reduction suffered.

(b) Capital Requirements. If any Lender determines that any Change in Law affecting such Lender or any Applicable Lending Office of such Lender or such Lender’s holding company, if any, regarding capital or liquidity requirements has or would have the effect of reducing the rate of return on such Lender’s capital or on the capital of such Lender’s holding company, if any, as a consequence of this Agreement, the Commitments of such Lender or the Loans made by such Lender, to a level below that which such Lender or such Lender’s holding company could have achieved but for such Change in Law (taking into consideration such Lender’s policies and the policies of such Lender’s holding company with respect to capital adequacy and liquidity), then from time to time the Borrower will pay to such Lender such additional amount or amounts as will compensate such Lender or such Lender’s holding company for any such reduction suffered.

(c) Certificates for Reimbursement. A certificate of a Lender setting forth the amount or amounts necessary to compensate such Lender or its holding company, as the case may be, as specified in subsection (a) or (b) of this Section and delivered to the Borrower shall be conclusive and binding upon all parties absent manifest error. The Borrower shall pay such Lender the amount shown as due on any such certificate within 30 days after receipt thereof.

(d) Delay in Requests. Failure or delay on the part of any Lender to demand compensation pursuant to the foregoing provisions of this Section shall not constitute a waiver of such Lender’s right to demand such compensation, provided that the Borrower shall not be required to compensate a Lender pursuant to the foregoing provisions of this Section for any increased costs incurred or reductions suffered more than three months prior to the date that such Lender notifies the Borrower of the Change in Law giving rise to such increased costs or reductions and of such Lender’s intention to claim compensation therefor (except that, if the Change in Law giving rise to such increased costs or reductions is retroactive, then the three-month period referred to above shall be extended to include the period of retroactive effect thereof).

(e) Reserves on Eurodollar Rate Loans. The Borrower shall pay to each Lender, as long as such Lender shall be required to maintain reserves with respect to liabilities or assets consisting of or including Eurocurrency funds or deposits (currently known as “Eurocurrency liabilities”), additional interest on the unpaid principal amount of each Eurodollar Rate Loan equal to the actual costs of such reserves allocated to such Loan by such Lender (as determined by such Lender in good faith, which determination shall be conclusive absent manifest error), which shall be due and payable on each date on which interest is payable on such Loan, provided the Borrower shall have received at least 30 days’ prior notice (with a copy to the Agent) of such additional interest from such Lender. If a Lender fails to give notice 30 days prior to the relevant interest payment date, such additional interest shall be due and payable 30 days from receipt of such notice.

Section 2.10 Illegality. If any Lender shall have determined in good faith that the introduction of or any change in any applicable Law or in the interpretation or administration thereof by any Governmental Authority charged with the interpretation or administration thereof, or compliance with any guideline or request from any such Governmental Authority (whether or not having the force of law), makes it unlawful for any Lender or its Applicable Lending Office to make, maintain or fund Eurodollar Rate Loans, or to determine or charge interest rates based upon the Eurodollar Rate, or any Governmental Authority has imposed material restrictions on the authority of such Lender to purchase or sell, or to take deposits of, Dollars in the London interbank market, then, on notice thereof by such Lender to the Borrower through the Agent, any obligation of such Lender to make or continue Eurodollar Rate Loans or to Convert Base Rate Loans to Eurodollar Rate Loans shall be suspended until such Lender notifies the Agent and the Borrower that the circumstances giving rise to such determination no longer exist. Upon receipt of such notice, the Borrower shall, upon demand from such Lender (with a copy to the Agent), prepay or, if applicable, Convert all Eurodollar Rate Loans of such Lender to Base Rate Loans, either on the last day of the Interest Period therefor, if such Lender may lawfully continue to maintain such Eurodollar Rate Loans to such day, or immediately, if such Lender may not lawfully continue to maintain such Eurodollar Rate Loans. Upon any such prepayment or Conversion, the Borrower shall also pay accrued interest on the amount so prepaid or Converted.

Section 2.11 Payments and Computations.

(a) All payments to be made by the Borrower shall be made without condition or deduction for any counterclaim, defense, recoupment or setoff. The Borrower shall make each payment hereunder not later than 1:00 p.m. on the day when due in Dollars to the Agent at the Agent’s Account in same day funds. The Agent will promptly thereafter cause to be distributed like funds relating to the payment of principal, interest or fees ratably (other than amounts payable pursuant to Sections 2.09, 2.10, 2.12, 2.17 or 8.04(e)) to the Lenders for the account of their respective Applicable Lending Offices, and like funds relating to the payment of any other amount payable to any Lender to such Lender for the account of its Applicable Lending Office, in each case to be applied in accordance with the terms of this Agreement. Upon its acceptance of an Assignment and Assumption and recording of the information contained therein in the Register pursuant to Section 8.07(c), from and after the effective date specified in such Assignment and Assumption, the Agent shall make all payments hereunder and under the Notes in respect of the interest assigned thereby to the Lender assignee thereunder, and the parties to such Assignment and Assumption shall make all appropriate adjustments in such payments for periods prior to such effective date directly between themselves.

(b) All computations of interest based on the Base Rate (when the Base Rate is based on the Prime Rate) shall be made by the Agent on the basis of a year of 365 or 366 days, as the case may be, and all other computations of interest and fees hereunder (including computations of interest based on the Eurodollar Rate and the Federal Funds Rate) shall be made by the Agent on the basis of a year of 360 days, in each case for the actual number of days (including the first day but excluding the last day) occurring in the period for which such interest or fees are payable. Each determination by the Agent of an interest rate hereunder shall be conclusive and binding for all purposes, absent manifest error.

(c) Whenever any payment hereunder or under the Notes shall be stated to be due on a day other than a Business Day, such payment shall be made on the next succeeding Business Day, and such extension of time shall in such case be included in the computation of payment of interest or fees, as the case may be; provided, however, that, if such extension would cause payment of interest on or principal of Eurodollar Rate Loans to be made in the next following calendar month, such payment shall be made on the next preceding Business Day.

(d) Unless the Agent shall have received notice from the Borrower prior to the date on which any payment is due to the Lenders hereunder that the Borrower will not make such payment in full, the Agent may assume that the Borrower has made such payment in full to the Agent on such date and the Agent may, in reliance upon such assumption, cause to be distributed to each Lender on such due date an amount equal to the amount then due to such Lender. If and to the extent the Borrower shall not have so made such payment in full to the Agent, each Lender shall repay to the Agent forthwith on demand such amount distributed to such Lender together with interest thereon, for each day from the date such amount is distributed to such Lender until the date such Lender repays such amount to the Agent, at the Federal Funds Rate.

Section 2.12 Taxes.

(a) Payments Free of Taxes; Obligation to Withhold; Payments on Account of Taxes.

(i) Any and all payments by or on account of any obligation of the Borrower hereunder or under any other Loan Document shall to the extent permitted by applicable Laws be made free and clear of and without reduction or withholding for any Taxes. If, however, applicable Laws require the Borrower or the Agent to withhold or deduct any Tax, such Tax shall be withheld or deducted in accordance with such Laws as determined by the Borrower or the Agent, as the case may be, upon the basis of the information and documentation to be delivered pursuant to subsection (e) below.

(ii) If the Borrower or the Agent shall be required by the Internal Revenue Code to withhold or deduct any Taxes, including both United States of America Federal backup withholding and withholding Taxes, from any payment, then (A) the Agent shall withhold or make such deductions as are determined by the Agent to be required based upon the information and documentation it has received pursuant to subsection (e) below, (B) the Agent shall timely pay the full amount withheld or deducted to the relevant Governmental Authority in accordance with the Internal Revenue Code, and (C) to the extent that the withholding or deduction is made on account of Indemnified Taxes or Other Taxes, the sum payable by the Borrower shall be increased as necessary so that after any required withholding or the making of all required deductions (including deductions applicable to additional sums payable under this Section) the Agent or each Lender, as the case may be, receives an amount equal to the sum it would have received had no such withholding or deduction been made.

(b) Payment of Other Taxes by the Borrower. Without limiting the provisions of subsection (a) above, the Borrower shall timely pay any Other Taxes to the relevant Governmental Authority in accordance with applicable Laws.

(i) Without limiting the provisions of subsection (a) or (b) above, the Borrower shall, and does hereby, indemnify the Agent and each Lender, and shall make payment in respect thereof within 30 days after written demand therefor, for the full amount of any Indemnified Taxes or Other Taxes (including Indemnified Taxes or Other Taxes imposed or asserted on or attributable to amounts payable under this Section) withheld or deducted by the Borrower or the Agent or paid by the Agent or such Lender, as the case may be, and any penalties, interest and reasonable expenses arising therefrom or with respect thereto, whether or not such Indemnified Taxes or Other Taxes were correctly or legally imposed or asserted by the relevant Governmental Authority. The Borrower shall also, and does hereby, indemnify the Agent, and shall make payment in respect thereof within 10 days after demand therefor, for any amount which a Lender for any reason fails to pay indefeasibly to the Agent as required by clause (ii) of this subsection. A certificate as to the amount of any such payment or liability delivered to the Borrower by a Lender (with a copy to the Agent), or by the Agent on its own behalf or on behalf of a Lender, shall be conclusive absent manifest error.

(ii) Each Lender shall, within 30 days after demand therefor, severally (A) indemnify the Agent for (x) any Indemnified Taxes and Other Taxes attributable to such Lender (but only to the extent that the Borrower has not already indemnified the Agent for such Indemnified Taxes and Other Taxes and without limiting the obligation of the Borrower to do so), (y) any Taxes attributable to such Lender’s failure to comply with the provisions of Section 8.07(d) relating to the maintenance of a Participant Register and (z) any Excluded Taxes attributable to such Lender, in each case, that are payable or paid by the Agent in connection with any Loan Document, and any reasonable expenses arising therefrom or with respect thereto, whether or not such Taxes were correctly or legally imposed or asserted by the relevant Governmental Authority, and (B) indemnify the Borrower and the Agent against any and all Taxes and any and all related losses, claims, liabilities, penalties, interest and expenses (including the fees, charges and disbursements of any counsel for the Borrower or the Agent) incurred by or asserted against the Borrower or the Agent by any Governmental Authority as a result of the failure by such Lender to deliver, or as a result of the inaccuracy, inadequacy or deficiency of, any documentation required to be delivered by such Lender to the Borrower or the Agent pursuant to subsection (e). A certificate as to the amount of such payment or liability delivered to any Lender by the Agent shall be conclusive absent manifest error. Each Lender hereby authorizes the Agent to set off and apply any and all amounts at any time owing to such Lender under any Loan Document or otherwise payable by the Agent to the Lender from any other source against any amount due to the Agent under this clause (ii). The agreements in this clause (ii) shall survive the resignation and/or replacement of the Agent, any assignment of rights by, or the replacement of, a Lender and the repayment, satisfaction or discharge of all other Obligations.

(d) Evidence of Payments. Upon request by the Borrower or the Agent, as the case may be, after any payment of Taxes by the Borrower or by the Agent to a Governmental Authority as provided in this Section 2.12, the Borrower shall deliver to the Agent or the Agent shall deliver to the Borrower, as the case may be, the original or a certified copy of a receipt issued by such Governmental Authority evidencing such payment, a copy of any return required by Laws to report such payment or other evidence of such payment reasonably satisfactory to the Borrower or the Agent, as the case may be.

(e) Status of Lenders; Tax Documentation.

(i) Each Lender shall deliver to the Borrower and to the Agent, at the time or times prescribed by applicable Laws or when reasonably requested by the Borrower or the Agent, such properly completed and executed documentation prescribed by applicable Laws or by the taxing authorities of any jurisdiction and such other reasonably requested information as will permit the Borrower or the Agent, as the case may be, to determine (A) whether or not payments made hereunder or under any other Loan Document are subject to Taxes, (B) if applicable, the required rate of withholding or deduction, and (C) such Lender’s entitlement to any available exemption from, or reduction of, applicable Taxes in respect of all payments to be made to such Lender by the Borrower pursuant to this Agreement or otherwise to establish such Lender’s status for withholding tax purposes in the applicable jurisdiction.

(ii) Without limiting the generality of the foregoing, if the Borrower is resident for tax purposes in the United States of America,

(A) any Lender that is a “United States person” within the meaning of Section 7701(a)(30) of the Internal Revenue Code shall deliver to the Borrower and the Agent executed originals of Internal Revenue Service Form W-9 or such other documentation or information prescribed by applicable Laws or reasonably requested by the Borrower or the Agent as will enable the Borrower or the Agent, as the case may be, to determine whether or not such Lender is subject to backup withholding or information reporting requirements; and

(B) each Foreign Lender that is entitled under the Internal Revenue Code or any applicable treaty to an exemption from or reduction of withholding tax with respect to payments hereunder or under any other Loan Document shall deliver to the Borrower and the Agent (in such number of copies as shall be requested by the recipient) on or prior to the date on which such Foreign Lender becomes a Lender under this Agreement (and from time to time thereafter upon the request of the Borrower or the Agent, but only if such Foreign Lender is legally entitled to do so), whichever of the following is applicable:

(1) executed originals of Internal Revenue Service Form W-8BEN or Form W-8BEN-E claiming eligibility for benefits of an income tax treaty to which the United States of America is a party,

(2) executed originals of Internal Revenue Service Form W-8ECI,

(3) executed originals of Internal Revenue Service Form W-8IMY and all required supporting documentation,

(4) in the case of a Foreign Lender claiming the benefits of the exemption for portfolio interest under section 881(c) of the Internal Revenue Code, (x) a certificate to the effect that such Foreign Lender is not (A) a “bank” within the meaning of section 881(c)(3)(A) of the Internal Revenue Code, (B) a “10 percent shareholder” of the Borrower within the meaning of section 881(c)(3)(B) of the Internal Revenue Code, or (C) a “controlled foreign corporation” described in section 881(c)(3)(C) of the Internal Revenue Code and (y) executed originals of Internal Revenue Service Form W-8BEN or Form W-8BEN-E, or

(5) executed originals of any other form prescribed by applicable Laws as a basis for claiming exemption from or a reduction in United States of America Federal withholding tax together with such supplementary documentation as may be prescribed by applicable Laws to permit the Borrower or the Agent to determine the withholding or deduction required to be made.

(iii) Each Lender shall promptly (A) notify the Borrower and the Agent of any change in circumstances which would modify or render invalid any claimed exemption or reduction, and (B) take such steps as shall not be materially disadvantageous to it, in the reasonable judgment of such Lender, and as may be reasonably necessary (including the re-designation of its Applicable Lending Office) to avoid any requirement of applicable Laws of any jurisdiction that the Borrower or the Agent make any withholding or deduction for taxes from amounts payable to such Lender.

(iv) If a payment made to a Lender under any Loan Document would be subject to U.S. federal withholding Tax imposed by FATCA if such Lender were to fail to comply with the applicable reporting requirements of FATCA (including those contained in Section 1471(b) or 1472(b) of the Internal Revenue Code, as applicable), such Lender shall deliver to each of the Borrower and the Agent at the time or times prescribed by law and at such time or times reasonably requested by the Borrower or the Agent such documentation prescribed by applicable law (including as prescribed by Section 1471(b)(3)(C)(i) of the Internal Revenue Code) and such additional documentation reasonably requested by the Borrower or the Agent as may be necessary for the Borrower and the Agent to comply with their obligations under FATCA and to determine that such Lender has complied with such Lender’s obligations under FATCA or to determine the amount to deduct and withhold from such payment. Solely for purposes of this clause (iv), “FATCA” shall include any amendments made to FATCA after the date of this Agreement.

(f) Treatment of Certain Refunds. Unless required by applicable Laws, at no time shall the Agent have any obligation to file for or otherwise pursue on behalf of a Lender, or have any obligation to pay to any Lender, any refund of Taxes withheld or deducted from funds paid for the account of such Lender. If the Agent or any Lender determines, in its sole discretion, that it has received a refund of any Taxes or Other Taxes as to which it has been indemnified by the Borrower or with respect to which the Borrower has paid additional amounts pursuant to this Section, it shall pay to the Borrower an amount equal to such refund (but only to the extent of indemnity payments made, or additional amounts paid, by the Borrower under this Section with respect to the Taxes or Other Taxes giving rise to such refund), net of all reasonable out-of-pocket expenses incurred by the Agent or such Lender, as the case may be, and without interest (other than any interest paid by the relevant Governmental Authority with respect to such refund), provided that the Borrower, upon the request of the Agent or such Lender, agrees to repay the amount paid over to the Borrower (plus any penalties, interest or other charges imposed by the relevant Governmental Authority) to the Agent or such Lender in the event the Agent or such Lender is required to repay such refund to such Governmental Authority. This subsection shall not be construed to require the Agent or any Lender to make available its tax returns (or any other information relating to its taxes that it deems confidential) to the Borrower or any other Person.

(g) Payments. Failure or delay on the part of the Agent or any Lender to demand compensation pursuant to the foregoing provisions of this Section 2.12 shall not constitute a waiver of the Agent’s or such Lender’s right to demand such compensation, provided that the Borrower shall not be required to compensate the Agent or a Lender pursuant to the foregoing provisions of this Section 2.12 for any Indemnified Taxes or Other Taxes imposed or asserted by the relevant Governmental Authority more than three months prior to the date that the Agent or such Lender, as the case may be, claims compensation with respect thereto (except that, if a Change in Law giving rise to such Indemnified Taxes or Other Taxes is retroactive, then the three-month period referred to above shall be extended to include the period of retroactive effect thereof).

(h) The Agent and each Lender agrees to cooperate with any reasonable request made by the Borrower in respect of a claim of a refund in respect of Indemnified Taxes as to which it has been indemnified by the Borrower or with respect to which the Borrower has paid additional amounts pursuant to this Section 2.12 if (i) the Borrower has agreed in writing to pay all of the Agent’s or such Lender’s reasonable out-of-pocket costs and expenses relating to such claim, (ii) the Agent or such Lender determines, in its good faith judgment, that it would not be disadvantaged, unduly burdened or prejudiced as a result of such claim and (iii) the Borrower furnishes, upon request of the Agent or such Lender, an opinion of tax counsel (such opinion, which can be reasoned, and such counsel to be reasonably acceptable to such Lender or the Agent) that the Borrower is likely to receive a refund or credit.

Section 2.13 Sharing of Payments, Etc. If any Lender shall obtain any payment (whether voluntary, involuntary, through the exercise of any right of set-off, or otherwise) on account of the Loans owing to it (other than pursuant to Sections 2.09, 2.10, 2.12, 2.17 or 8.04(e) or any payment obtained by a Lender as consideration for the assignment of or sale of a participation in any of its Loans to any assignee or participant, other than to the Borrower or any Subsidiary thereof if permitted hereby (as to which the provisions of this Section 2.13 shall apply) in excess of its Ratable Share of payments on account of the Loans obtained by all the Lenders, such Lender shall forthwith purchase from the other Lenders (for cash at face value) such participations in the Loans owing to them as shall be necessary to cause such purchasing Lender to share the excess payment ratably with each of them; provided, however, that if all or any portion of such excess payment is thereafter recovered from such purchasing Lender, such purchase from each Lender shall be rescinded and such Lender shall repay to the purchasing Lender the purchase price to the extent of such recovery together with an amount equal to such Lender’s ratable share (according to the proportion of (i) the amount of such Lender’s required repayment to (ii) the total amount so recovered from the purchasing Lender) of any interest or other amount paid or payable by the purchasing Lender in respect of the total amount so recovered. The Borrower agrees that any Lender so purchasing a participation from another Lender pursuant to this Section 2.13 may, to the fullest extent permitted by Law, exercise all its rights of payment (including the right of set-off) with respect to such participation as fully as if such Lender were the direct creditor of the Borrower in the amount of such participation.

Section 2.14 Evidence of Debt.

(a) Each Lender shall maintain in accordance with its usual practice an account or accounts evidencing the indebtedness of the Borrower to such Lender resulting from each Loan owing to such Lender from time to time, including the amounts of principal and interest payable and paid to such Lender from time to time hereunder in respect of Loans. The Borrower agrees that upon notice by any Lender to the Borrower (with a copy of such notice to the Agent) to the effect that a Note is required or appropriate in order for such Lender to evidence (whether for purposes of pledge, enforcement or otherwise) the Loans owing to, or to be made by, such Lender, the Borrower shall promptly execute and deliver to such Lender a Note payable to the order of such Lender in a principal amount equal to the Loans owing to, or to be made by, such Lender.

(b) The Register maintained by the Agent pursuant to Section 8.07(c) shall include a control account, and a subsidiary account for each Lender, in which accounts (taken together) shall be recorded (i) the date and amount of each Borrowing made hereunder, the Type of Loans comprising such Borrowing and, if appropriate, the Interest Period applicable thereto, (ii) the terms of each Assignment and Assumption delivered to and accepted by it, (iii) the amount of any principal or interest due and payable or to become due and payable from the Borrower to each Lender hereunder and (iv) the amount of any sum received by the Agent from the Borrower hereunder and each Lender’s share thereof.

(c) Entries made in good faith by the Agent in the Register pursuant to subsection (b) above, and by each Lender in its account or accounts pursuant to subsection (a) above, shall be prima facie evidence of the amount of principal and interest due and payable or to become due and payable from the Borrower to, in the case of the Register, each Lender and, in the case of such account or accounts, such Lender, under this Agreement, absent manifest error; provided, however, that the failure of the Agent or such Lender to make an entry, or any finding that an entry is incorrect, in the Register or such account or accounts shall not limit or otherwise affect the obligations of the Borrower under this Agreement.

Section 2.15 Use of Proceeds. The proceeds of the Loans shall be available (and the Borrower agrees that it shall use such proceeds) to fund working capital and general corporate purposes, including capital expenditures, from time to time and in accordance with Section 4.01(p), subject to such restrictions that are imposed in the 2013 Order and/or any Subsequent Order.

Section 2.16 Affected Lenders. Notwithstanding any provision of this Agreement to the contrary, if any Lender becomes an Affected Lender, then the following provisions shall apply for so long as such Lender is an Affected Lender:

(a) the outstanding principal amount of the Loans of such Affected Lender shall not be included in determining whether the Required Lenders have taken or may take any action hereunder (including any consent to any amendment or waiver pursuant to Section 8.01), other than any waiver, amendment or modification requiring the consent of all Lenders or of each Lender affected;

(b) to the extent the Agent receives any payments or other amounts for the account of an Affected Lender under this Agreement, such Affected Lender shall be deemed to have requested that the Agent use such payment or other amount to fulfill such Affected Lender’s previously unsatisfied obligations to fund a Loan under Section 2.01 or any other unfunded payment obligation of such Affected Lender under this Agreement; and

(c) for the avoidance of doubt, the Borrower, the Agent and each other Lender shall retain and reserve its other rights and remedies respecting each Affected Lender.

In the event that the Agent and the Borrower each agrees that an Affected Lender has adequately remedied all matters that caused such Lender to be an Affected Lender, then this Section 2.16 will no longer apply to such Lender.

Section 2.17 Replacement of Lenders. If any Lender requests compensation under Section 2.09, or if the Borrower is required to pay any additional amount to any Lender or any Governmental Authority for the account of any Lender pursuant to Section 2.12, or if any Lender is an Affected Lender, then the Borrower may, at its sole expense and effort, upon notice to such Lender and the Agent, require such Lender to assign and delegate, without recourse (in accordance with and subject to the restrictions contained in, and consents required by, Section 8.07), all of its interests, rights and obligations under this Agreement and the related Loan Documents to one or more assignees that shall assume such obligations (which any such assignee may be another Lender (other than an Affected Lender), if such Lender accepts such assignment), provided that:

(a) the Borrower shall have paid to the Agent the assignment fee specified in Section 8.07(b);

(b) such Lender shall have received payment of an amount equal to the outstanding principal amount of its Loans, accrued interest thereon, accrued fees and all other amounts payable to it hereunder and under the other Loan Documents (including any amounts under Section 8.04(e)) from the assignee (to the extent of such outstanding principal and accrued interest and fees) or the Borrower (in the case of all other amounts);

(c) in the case of any such assignment resulting from a claim for compensation under Section 2.09 or payments required to be made pursuant to Section 2.12, such assignment will result in a reduction in such compensation or payments thereafter; and

(d) such assignment does not conflict with applicable Laws.

A Lender shall not be required to make any such assignment or delegation if, prior thereto, as a result of a waiver by such Lender or otherwise, the circumstances entitling the Borrower to require such assignment and delegation cease to apply.

ARTICLE III

CONDITIONS PRECEDENT

Section 3.01 Conditions Precedent to Effectiveness. This Agreement shall become effective on and as of the first date (the “Effective Date”) on which the following conditions precedent have been satisfied:

(f) The Lenders shall have been given such access to the management, records, books of account, contracts and properties of the Borrower and its Subsidiaries as they shall have requested.

(g) The Borrower shall have paid all accrued fees and agreed expenses of the Agent, the Arrangers and the Lenders, including but not limited to all fees payable pursuant to the Fee Letter, and the reasonable accrued fees and expenses of one law firm acting as counsel to the Agent that have been invoiced at least one Business Day prior to the Effective Date.

(h) On the Effective Date, the following statements shall be true and the Agent shall have received a certificate signed by a duly authorized officer of the Borrower, dated the Effective Date, stating that:

(iv) The representations and warranties contained in Section 4.01 are true and correct on and as of the Effective Date, both before and after giving effect to the Initial Borrowing and the application of the proceeds thereof, as though made on and as of such date; and

(v) No event has occurred and is continuing, or would result from the Initial Borrowing or the application of the proceeds thereof, that constitutes a Default.

(i) The Agent shall have received the Notice of Initial Borrowing pursuant to Section 2.02.

(j) The Agent shall have received on or before the Effective Date the following, each dated such day, in form and substance satisfactory to the Agent and the Lenders:

(i) Receipt by the Agent of executed counterparts of this Agreement properly executed by a duly authorized officer of the Borrower and by each Lender.

(ii) The Notes, payable to the order of the Lenders to the extent requested by any Lender pursuant to Section 2.14(a).

(iii) The articles of incorporation of the Borrower certified to be true and complete as of a recent date by the appropriate governmental authority of the state or other jurisdiction of its incorporation and certified by a secretary, assistant secretary or associate secretary of the Borrower to be true and correct as of the Effective Date.

(iv) The bylaws of the Borrower certified by a secretary, assistant secretary or associate secretary of the Borrower to be true and correct as of the Effective Date.

(v) Certified copies of the resolutions of the Board of Directors of the Borrower approving this Agreement and the Notes, and of all documents evidencing other necessary corporate action, third party consents and governmental approvals, if any, with respect to this Agreement and the Notes.

(vi) A certificate of the secretary, assistant secretary or associate secretary of the Borrower certifying the names and true signatures of the officers of the Borrower authorized to sign this Agreement and the Notes and the other documents to be delivered hereunder.

(vii) A certificate as of a recent date from the Borrower’s state of incorporation evidencing that the Borrower is in good standing in such state.

(viii) A favorable opinion of counsel for the Borrower, in form and substance reasonably acceptable to the Lenders.

(ix) A written opinion of Sidley Austin LLP, special New York counsel for the Agent, addressed to the Agent and the Lenders, with respect to the enforceability of this Agreement and the Notes, if any, issued on the Effective Date, in form and substance reasonably acceptable to the Agent.

(x) A written certificate of an Authorized Officer certifying (i) all required regulatory authorizations including the 2013 Order and/or any Subsequent Order in respect of such Credit Extension have been obtained, are in full force and effect and, before and after giving effect to the Borrowing on the Closing Date and to the application of the proceeds therefrom, the Borrower is in compliance with the provisions of the applicable order; and (ii) before and after giving effect to the Borrowing on the Closing Date and to the application of the proceeds therefrom, as though made on and as of such date, the Indebtedness of the Borrower does not exceed that permitted by (a) applicable resolutions of the Board of Directors of the Borrower, (b) applicable Arizona Law, or (c) the 2013 Order or any Subsequent Order, whichever is in force and effect at such time.

(k) PATRIOT Act. The Borrower shall have provided to the Agent and the Lenders the documentation and other information reasonably requested by the Agent in order to comply with requirements of the PATRIOT Act.

Section 3.02 Determinations Under Section 3.01. For purposes of determining compliance with the conditions specified in Section 3.01 and the satisfaction of each Lender with respect to letters delivered to it from the Borrower as set forth in Section 4.01(a), 4.01(e) and 4.01(f), each Lender that has signed this Agreement shall be deemed to have consented to, approved or accepted or to be satisfied with each document or other matter required thereunder to be consented to or approved by or acceptable or satisfactory to the Lenders unless an officer of the Agent responsible for the transactions contemplated by this Agreement shall have received notice from such Lender prior to the date that the Borrower designates as the proposed Effective Date, specifying its objection thereto. The Agent shall promptly notify the Lenders and the Borrower of the occurrence of the Effective Date.

ARTICLE IV

REPRESENTATIONS AND WARRANTIES

Section 4.01 Representations and Warranties of the Borrower. The Borrower represents and warrants as follows:

(a) Each of the Borrower and each Material Subsidiary: (i) is a corporation or other entity duly organized and validly existing under the Laws of the jurisdiction of its incorporation or organization; (ii) has all requisite corporate or if the Material Subsidiary is not a corporation, other comparable power necessary to own its assets and carry on its business as presently conducted; (iii) has all governmental licenses, authorizations, consents and approvals necessary to own its assets and carry on its business as presently conducted, if the failure to have any such license, authorization, consent or approval is reasonably likely to have a Material Adverse Effect and except as disclosed to the Agent in the SEC Reports or by means of a letter from the Borrower to the Lenders (such letter, if any, to be delivered to the Agent for prompt distribution to the Lenders) delivered prior to the execution and delivery of this Agreement (which, in each case, shall be satisfactory to each Lender in its sole discretion) and except that (A) the Borrower from time to time may make minor extensions of its lines, plants, services or systems prior to the time a related franchise, certificate of convenience and necessity, license or permit is procured, (B) from time to time communities served by the Borrower may become incorporated and considerable time may elapse before such a franchise is procured, (C) certain such franchises may have expired prior to the renegotiation thereof, (D) certain minor defects and exceptions may exist which, individually and in the aggregate, are not material and (E) certain franchises, certificates, licenses and permits may not be specific as to their geographical scope); and (iv) is qualified to do business in all jurisdictions in which the nature of the business conducted by it makes such qualification necessary and where failure so to qualify is reasonably likely to have a Material Adverse Effect.

(b) The execution, delivery and performance by the Borrower of this Agreement and the other Loan Documents, and the consummation of the transactions contemplated hereby and thereby, are within the Borrower’s corporate powers, have been duly authorized by all necessary corporate action, and do not or did not (i) contravene the Borrower’s articles of incorporation or by-laws, (ii) contravene any Law (including without limitation the 2013 Order and/or any Subsequent Order), decree, writ, injunction or determination of any Governmental Authority, in each case applicable to or binding upon the Borrower or any of its properties, (iii) contravene any contractual restriction binding on or affecting the Borrower or (iv) cause the creation or imposition of any Lien upon the assets of the Borrower or any Material Subsidiary, except for Liens created under this Agreement and except where such contravention or creation or imposition of such Lien is not reasonably likely to have a Material Adverse Effect.

(c) No authorization or approval or other action by, and no notice to or filing with, any Governmental Authority is required for the due execution, delivery and performance by the Borrower of this Agreement or the Notes to be delivered by it, except for the 2013 Order or any Subsequent Order, which has been duly obtained and is in full force and effect, and any notices or compliance filings required therein.

(d) This Agreement has been, and each of the other Loan Documents upon execution and delivery will have been, duly executed and delivered by the Borrower. This Agreement is, and each of the other Loan Documents upon execution and delivery will be, the legal, valid and binding obligation of the Borrower enforceable against the Borrower in accordance with their respective terms, subject, however, to the application by a court of general principles of equity and to the effect of any applicable bankruptcy, insolvency, reorganization, moratorium or similar Laws affecting creditors’ rights generally.

(e) (i) The Consolidated balance sheet of the Borrower as of December 31, 2015, and the related Consolidated statements of income and cash flows of the Borrower for the fiscal year then ended, accompanied by an opinion thereon of Deloitte & Touche LLP, independent registered public accountants, duly certified by the chief financial officer of the Borrower, copies of which have been furnished to the Agent, fairly present in all material respects, the Consolidated financial condition of the Borrower as at such dates and the Consolidated results of the operations of the Borrower for the periods ended on such dates, all in accordance with GAAP (except as disclosed therein); and (ii) except as disclosed to the Agent in the SEC Reports or by means of a letter from the Borrower to the Lenders (such letter, if any, to be delivered to the Agent for prompt distribution to the Lenders) delivered prior to the execution and delivery of this Agreement (which, in each case, shall be satisfactory to each Lender in its sole discretion), since December 31, 2015, there has been no Material Adverse Effect.

(f) There is no pending or, to the knowledge of an Authorized Officer of the Borrower, threatened action, suit, investigation, litigation or proceeding, including, without limitation, any Environmental Action, affecting the Borrower or any of its Subsidiaries before any court, governmental agency or arbitrator that (i) purports to affect the legality, validity or enforceability of this Agreement or any other Loan Document or the consummation of the transactions contemplated hereby or (ii) would be reasonably likely to have a Material Adverse Effect (except as disclosed to the Agent in the SEC Reports or by means of a letter from the Borrower to the Lenders (such letter, if any, to be delivered to the Agent for prompt distribution to the Lenders) delivered prior to the execution and delivery of this Agreement (which, in each case, shall be satisfactory to each Lender in its sole discretion)), and there has been no adverse change in the status, or financial effect on the Borrower or any of its Subsidiaries, of such disclosed litigation that would be reasonably likely to have a Material Adverse Effect.

(g) No proceeds of any Loan will be used to acquire any equity security not issued by the Borrower of a class that is registered pursuant to Section 12 of the Securities Exchange Act of 1934.

(h) The Borrower is not engaged in the business of extending credit for the purpose of purchasing or carrying margin stock (within the meaning of Regulation U issued by the Board of Governors of the Federal Reserve System), and no proceeds of any Loan will be used to purchase or carry any margin stock or to extend credit to others for the purpose of purchasing or carrying any margin stock, in any case in violation of Regulation U. After application of the proceeds of any Loan, not more than 25% of the value of the assets subject to any restriction under this Agreement on the right to sell, pledge, transfer, or otherwise dispose of such assets is represented by margin stock.

(i) The Borrower and its Subsidiaries have filed all United States of America Federal income Tax returns and all other material Tax returns which are required to be filed by them and have paid all Taxes due pursuant to such returns or pursuant to any assessment received by the Borrower or any of its Subsidiaries, except to the extent that (xi) such Taxes are being contested in good faith and by appropriate proceedings and that appropriate reserves for the payment thereof have been maintained by the Borrower and its Subsidiaries in accordance with GAAP or (xii) the failure to make such filings or such payments is not reasonably likely to have a Material Adverse Effect. The charges, accruals and reserves on the books of the Borrower and its Material Subsidiaries as set forth in the most recent financial statements of the Borrower delivered to the Agent pursuant to Section 4.01(e) or Section 5.01(h)(i) or (iii) hereof in respect of Taxes and other governmental charges are, in the opinion of the Borrower, adequate.

(j) Set forth on Schedule 4.01(j) hereto (as such schedule may be modified from time to time by the Borrower by written notice to the Agent) is a complete and accurate list of all the Subsidiaries of the Borrower and, as of the Effective Date, no such Subsidiary of the Borrower is a Material Subsidiary.

(k) Set forth on Schedule 4.01(k) hereto is a complete and accurate list identifying any Indebtedness of the Borrower outstanding in a principal amount equal to or exceeding $5,000,000 and which is not described in the financial statements referred to in Section 4.01(e).

(l) The Borrower is not an “investment company”, or a company “controlled” by an “investment company”, within the meaning of the Investment Company Act of 1940, as amended.

(m) No report, certificate or other written information furnished by the Borrower or any of its Subsidiaries to the Agent, any Arranger or any Lender in connection with the transactions contemplated hereby and the negotiation of this Agreement or delivered hereunder or any other Loan Document (as modified or supplemented by other information so furnished) at the time so furnished, when taken together as a whole with all such written information so furnished, contains an untrue statement of a material fact or omits to state a material fact necessary in order to make the statements therein, in the light of the circumstances under which they were made, not misleading, except as would not reasonably be expected to result in a Material Adverse Effect; provided that with respect to any projected financial information, forecasts, estimates or forward-looking information, the Borrower represents only that such information and materials have been prepared in good faith on the basis of assumptions believed to be reasonable at the time of preparation of such forecasts, and no representation or warranty is made as to the actual attainability of any such projections, forecasts, estimates or forward-looking information.

(n) Neither the Borrower nor any of its Subsidiaries or, to the knowledge of the Borrower, any of their respective Affiliates over which any of the foregoing exercises management control (each, a “Controlled Affiliate”) or any director or officer of the Borrower, any of its Subsidiaries or any of their respective Controlled Affiliates (each, a “Manager”) is a Prohibited Person, and the Borrower, its Subsidiaries and, to the knowledge of the Borrower, such Controlled Affiliates are in compliance with all applicable orders, rules and regulations of OFAC.

(o) Neither the Borrower nor any of its Subsidiaries or, to the knowledge of the Borrower, any of their respective Controlled Affiliates or Managers: (i) is the target of Sanctions; (ii) is owned or controlled by, or acts on behalf of, any Person that is targeted by United States or multilateral economic or trade sanctions currently in force; (iii) is, or is owned or controlled by, a Person who is located, organized or resident in a country, region or territory that is, or whose government is, the subject of Sanctions, including, without limitation, Crimea, Cuba, Iran, North Korea, Sudan and Syria, or (iv) is named, identified or described on any list of Persons with whom United States Persons may not conduct business, including any such blocked persons list, designated nationals list, denied persons list, entity list, debarred party list, unverified list, sanctions list or other such lists published or maintained by the United States, including OFAC, the United States Department of Commerce or the United States Department of State.

(p) None of the Borrower’s or its Subsidiaries’ assets constitute property of, or are beneficially owned, directly or indirectly, by any Person that is the target of Sanctions, including but not limited to, the International Emergency Economic Powers Act, 50 U.S.C. §§ 1701 et seq., The Trading with the Enemy Act, 50 U.S.C. App. 1 et seq. (the “Trading With the Enemy Act”), any of the foreign assets control regulations of the Treasury (31 C.F.R., Subtitle B, Chapter V, as amended) (the “Foreign Assets Control Regulations”) or any enabling legislation or regulations promulgated thereunder or executive order relating thereto (which includes, without limitation, (i) Executive Order No. 13224, effective as of September 24, 2001, and relating to Blocking Property and Prohibiting Transactions With Persons Who Commit, Threaten to Commit, or Support Terrorism (66 Fed. Reg. 49079 (2001)) (the “Executive Order”) and (ii) the PATRIOT Act), if the result of such ownership would be that any Borrowing made by any Lender would be in violation of law (“Embargoed Person”); (a) no Embargoed Person has any interest of any nature whatsoever in the Borrower if the result of such interest would be that any Borrowing would be in violation of law; (b) the Borrower has not engaged in business with Embargoed Persons if the result of such business would be that any Borrowing made by any Lender would be in violation of law; (c) the Borrower will not, directly or indirectly, use the proceeds of the Borrowing, or lend, contribute or otherwise make available such proceeds to any subsidiary, joint venture partner or other Person, (i) to fund any activities or business of or with any Person, or in any country or territory, that, at the time of such funding, is, or whose government is, the subject of Sanctions, or (ii) in any other manner that would result in a violation of Sanctions or Anti-Corruption Laws by any Person (including any Person participating in the Borrowing, whether as a Lender or otherwise), and (d) neither the Borrower nor any Controlled Affiliate (i) is or will become a “blocked person” as described in the Executive Order, the Trading With the Enemy Act or the Foreign Assets Control Regulations or (ii) to the knowledge of the Borrower, engages in any dealings or transactions, or be otherwise associated, with any such “blocked person”. For purposes of determining whether or not a representation is true under this Section 4.01(p), with respect to the securities of the Borrower, the Borrower shall not be required to make any investigation into (x) the ownership of publicly traded stock or other publicly traded securities or (y) the beneficial ownership of any collective investment fund.

(q) Neither the Borrower nor any of its Subsidiaries or, to the knowledge of the Borrower and its Subsidiaries, any of their respective Managers, has failed to comply with the U.S. Foreign Corrupt Practices Act, as amended from time to time (the “FCPA”), or any other applicable Anti-Corruption Law, and it and they have not made, offered, promised or authorized, and will not make, offer, promise or authorize, whether directly or indirectly, any payment, of anything of value to a Government Official while knowing or having a reasonable belief that all or some portion will be used for the purpose of: (a) influencing any act, decision or failure to act by a Government Official in his or her official capacity, (b) inducing a Government Official to use his or her influence with a government or instrumentality to affect any act or decision of such government or entity or (c) securing an improper advantage, in each case in order to obtain, retain or direct business.

(r) Borrower is not an EEA Financial Institution.

ARTICLE V

COVENANTS OF THE BORROWER

Section 5.01 Affirmative Covenants. So long as any Loan or any other Obligations shall remain unpaid, the Borrower shall:

(a) Compliance with Laws, Etc. (i) Comply, and cause each of its Material Subsidiaries to comply, in all material respects, with all applicable Laws of Governmental Authorities, such compliance to include, without limitation, compliance with ERISA and Environmental Laws, unless the failure to so comply is not reasonably likely to have a Material Adverse Effect and (ii) comply at all times with the 2013 Order, any Subsequent Order, Arizona Revised Statutes, Section 40-302 and all similar or comparable Laws, orders, decrees, writs, injunctions or determinations of any Governmental Authority relating to the incurrence or maintenance of Indebtedness by the Borrower, such compliance to include, without limitation, compliance with the PATRIOT Act, all applicable orders, rules and regulations of OFAC, the FCPA, the Racketeer Influenced and Corrupt Organizations Chapter of the Organized Crime Control Act of 1970 and other Anti-Corruption Laws, except (other than in the case of the PATRIOT Act, the applicable orders, rules and regulations of OFAC, or the FCPA) to the extent that the failure to do so could not reasonably be expected to have a Material Adverse Effect.

(b) Payment of Taxes, Etc. Pay and discharge, and cause each of its Subsidiaries to pay and discharge, before the same shall become delinquent, all Taxes, imposed upon it or upon its property; provided, however, that neither the Borrower nor any of its Subsidiaries shall be required to pay or discharge any such Tax (i) that is being contested in good faith and by proper proceedings and as to which appropriate reserves are being maintained in accordance with GAAP or (ii) if the failure to pay such Tax is not reasonably likely to have a Material Adverse Effect.

(c) Maintenance of Insurance. Maintain, and cause each of its Material Subsidiaries to maintain, insurance with responsible and reputable insurance companies or associations in such amounts and covering such risks as is usually carried by companies engaged in similar businesses and owning similar properties in the same general areas in which the Borrower or such Material Subsidiary operates; provided, however, that the Borrower and its Subsidiaries may self-insure to the same extent as other companies engaged in similar businesses and owning similar properties in the same general areas in which the Borrower or such Subsidiary operates and to the extent consistent with prudent business practice.

(d) Preservation of Corporate Existence, Etc. Preserve and maintain, and cause each of its Material Subsidiaries to preserve and maintain, its corporate existence, rights (charter and statutory) and franchises (other than “franchises” as described in Arizona Revised Statutes, Section 40-283 or any successor provision) reasonably necessary in the normal conduct of its business, if the failure to maintain such rights or privileges is reasonably likely to have a Material Adverse Effect, and will use its commercially reasonable efforts to preserve and maintain such franchises reasonably necessary in the normal conduct of its business, except that (i) the Borrower from time to time may make minor extensions of its lines, plants, services or systems prior to the time a related franchise, certificate of convenience and necessity, license or permit is procured, (ii) from time to time communities served by the Borrower may become incorporated and considerable time may elapse before such a franchise is procured, (iii) certain such franchises may have expired prior to the renegotiation thereof, (iv) certain minor defects and exceptions may exist which, individually and in the aggregate, are not material and (v) certain franchises, certificates, licenses and permits may not be specific as to their geographical scope; provided, however, that the Borrower and its Subsidiaries may consummate any merger or consolidation permitted under Section 5.02(b).

(e) Visitation Rights. At any reasonable time and from time to time, permit and cause each of its Subsidiaries to permit the Agent or any of the Lenders or any agents or representatives thereof, to examine and make copies of and abstracts from the records and books of account of, and visit the properties of, the Borrower and any of its Subsidiaries, and to discuss the affairs, finances and accounts of the Borrower and any of its Subsidiaries with any of their officers or directors; provided, however, that the Borrower and its Subsidiaries reserve the right to restrict access to any of its properties in accordance with reasonably adopted procedures relating to safety and security; and provided further that the costs and expenses incurred by such Lender or its agents or representatives in connection with any such examinations, copies, abstracts, visits or discussions shall be, upon the occurrence and during the continuation of a Default, for the account of the Borrower and, in all other circumstances, for the account of such Lender.

(f) Keeping of Books. Keep, and cause each of its Material Subsidiaries to keep, proper books of record and account, in which full and correct entries shall be made of all financial transactions and the assets and business of the Borrower and each such Subsidiary in a manner that permits the preparation of financial statements in accordance with GAAP.

(g) Maintenance of Properties, Etc. Keep, and cause each Material Subsidiary to keep, all property useful and necessary in its business in good working order and condition (ordinary wear and tear excepted), if the failure to do so is reasonably likely to have a Material Adverse Effect, it being understood that this covenant relates only to the working order and condition of such properties and shall not be construed as a covenant not to dispose of properties.

(h) Reporting Requirements. Furnish to the Agent:

(xiii) as soon as available and in any event within 50 days after the end of each of the first three fiscal quarters of each fiscal year of the Borrower commencing with the fiscal quarter ending March 31, 2016, (A) for each such fiscal quarter of the Borrower, Consolidated statements of income and cash flows of the Borrower for such fiscal quarter and the related Consolidated balance sheet of the Borrower as of the end of such fiscal quarter setting forth in each case in comparative form the corresponding figures for the corresponding fiscal quarter in (or, in the case of the balance sheet, as of the end of) the preceding fiscal year and (B) for the period commencing at the end of the previous fiscal year and ending with the end of such fiscal quarter, Consolidated statements of income and cash flows of the Borrower for such period setting forth in each case in comparative form the corresponding figures for the corresponding period in the preceding fiscal year; provided that so long as the Borrower remains subject to the reporting requirements of the Securities Exchange Act of 1934, as amended, the Borrower may provide, in satisfaction of the requirements of this first sentence of this Section 5.01(h)(i), its report on Form 10-Q for such fiscal quarter. Each set of financial statements provided under this Section 5.01(h)(i) shall be accompanied by a certificate of an Authorized Officer, which certificate shall state that said Consolidated financial statements fairly present in all material respects the Consolidated financial condition and results of operations and cash flows of the Borrower in accordance with GAAP (except as disclosed therein), as at the end of, and for, such period (subject to normal year-end audit adjustments) and shall set forth reasonably detailed calculations demonstrating compliance with Section 5.03;

(xiv) as soon as available and in any event within 90 days after the end of each fiscal year of the Borrower, commencing with the fiscal year ending December 31, 2016, audited Consolidated statements of income and cash flows of the Borrower for such year and the related Consolidated balance sheet of the Borrower as at the end of such year, setting forth in each case in comparative form the corresponding figures for the preceding fiscal year; provided that, so long as the Borrower remains subject to the reporting requirements of the Securities Exchange Act of 1934, as amended, the Borrower may provide, in satisfaction of the requirements of this first sentence of this Section 5.01(h)(ii), its report on Form 10-K for such fiscal year. Each set of financial statements provided pursuant to this Section 5.01(h)(ii) shall be accompanied by (A) an opinion thereon of independent certified public accountants of recognized national standing, which opinion shall state that said Consolidated financial statements fairly present in all material respects the Consolidated financial condition and results of operations of the Borrower as at the end of, and for, such fiscal year, in accordance with GAAP (except as disclosed therein) and (B) a certificate of an Authorized Officer, which certificate shall set forth reasonably detailed calculations demonstrating compliance with Section 5.03;

(xv) as soon as possible and in any event within five days after any Authorized Officer of the Borrower knows of the occurrence of each Default continuing on the date of such statement, a statement of an Authorized Officer of the Borrower setting forth details of such Default and the action that the Borrower has taken and proposes to take with respect thereto;

(xvi) promptly after the sending or filing thereof, copies of all reports and registration statements (other than exhibits thereto and registration statements on Form S-8 or its equivalent) that the Borrower or any Subsidiary files with the Securities and Exchange Commission;

(xvii) promptly after an Authorized Officer becomes aware of the commencement thereof, notice of all actions and proceedings before any court, governmental agency or arbitrator affecting the Borrower or any of its Subsidiaries of the type described in Section 4.01(f), except, with respect to any matter referred to in Section 4.01(f)(ii), to the extent disclosed in a report on Form 8-K, Form 10-Q or Form 10-K of the Borrower;

(xviii) promptly after (A) any amendment or modification of the 2013 Order, (B) any amendment or modification of Arizona Revised Statutes, Section 40-302, or the promulgation, amendment or modification of any successor or similar statute, or (C) the promulgation, amendment or modification of any Subsequent Order by the Arizona Corporation Commission or any successor thereto, in any case if such amendment, modification or promulgation could affect the validity or enforceability of the indebtedness of the Borrower pursuant to this Agreement, a copy thereof;

(xix) promptly after an Authorized Officer becomes aware of the occurrence thereof, notice of any change by Moody’s or S&P of its respective Public Debt Rating or of the cessation (or subsequent commencement) by Moody’s or S&P of publication of its respective Public Debt Rating;

(xx) promptly after the occurrence thereof, notice of the occurrence of any ERISA Event, together with (x) a written statement of an Authorized Officer of the Borrower specifying the details of such ERISA Event and the action that the Borrower has taken and proposes to take with respect thereto, (y) a copy of any notice with respect to such ERISA Event that may be required to be filed with the PBGC and (z) a copy of any notice delivered by the PBGC to the Borrower or an ERISA Affiliate with respect to such ERISA Event; and

(xxi) such other information respecting the Borrower or any of its Subsidiaries as any Lender through the Agent may from time to time reasonably request.

Information required to be delivered pursuant to Sections 5.01(h)(i), (ii) and (iv) above shall be deemed to have been delivered on the date on which the Borrower provides notice to the Agent that such information has been posted on the Borrower’s parent’s website on the Internet at www.pinnaclewest.com, at sec.gov/edaux/searches.htm or at another website identified in such notice and accessible by the Lenders without charge; provided that (i) such notice may be included in a certificate delivered pursuant to Section 5.01(h)(i) or (ii) and (ii) the Borrower shall deliver paper copies of the information referred to in Section 5.01(h)(i), (ii), and (iv) to any Lender which requests such delivery.

(i) Change in Nature of Business. Conduct the same general type of business conducted on the date hereof.

Section 5.02 Negative Covenants. So long as any Loan or any other Obligations shall remain unpaid, the Borrower shall not:

(d) Liens, Etc. Create or suffer to exist, or permit any of its Material Subsidiaries to create or suffer to exist, any Lien on or with respect to any of its properties, whether now owned or hereafter acquired, or assign, or permit any of its Material Subsidiaries to assign, any right to receive income, other than:

(iii) Permitted Liens;

(iv) Liens upon or in, or conditional sales agreements or other title retention agreements with respect to, any real or personal property acquired or held by the Borrower or any Subsidiary in the ordinary course of business to secure the purchase price of such property, or the construction of or improvements to such property, or to secure Indebtedness incurred solely for the purpose of financing the acquisition, construction or improvement of such property to be subject to such Liens (including any Liens placed on such property within 180 days after the latest of the acquisition, completion of construction or improvement of such property), or Liens existing on such property at the time of its acquisition (other than any such Liens created in contemplation of such acquisition that were not incurred to finance the acquisition of such property) or extensions, renewals, refundings or replacements of any of the foregoing for the same or a lesser amount, provided, however, that no such Lien shall extend to or cover any properties of any character other than the property being acquired, constructed or improved and proceeds, improvements and replacements thereof and no such extension, renewal, refunding or replacement shall extend to or cover any properties not theretofore subject to the Lien being extended, renewed, refunded or replaced;

(v) assignments of the right to receive income, and Liens on property, of a Person existing at the time such Person is merged into or consolidated with the Borrower or any Subsidiary of the Borrower or becomes a Subsidiary of the Borrower;

(vi) Liens with respect to the leases and related documents entered into by the Borrower in connection with PVNGS Unit 2 and Liens with respect to the leased interests and related rights if the Borrower reacquires ownership in any of those interests or acquires any of the equity or owner participants’ interests in the trusts that hold title to such leased interests, whether or not it also directly assumes any Sale Leaseback Obligation Bonds, and Liens on the Borrower’s interests in the trusts that hold title to such leased interests and related rights in the event that the Borrower acquires any of the equity or owner participants’ interests in such trusts pursuant to a “special transfer” under the Borrower’s existing PVNGS Unit 2 sale and leaseback transactions and any Liens resulting or deemed to have resulted if the PVNGS Unit 2 leases are required to be accounted for as capital leases in accordance with GAAP;

(vii) other assignments of the right to receive income and Liens securing Indebtedness or claims in an aggregate principal amount not to exceed 20% of the Borrower’s total assets as stated on the most recent balance sheet of the Borrower provided pursuant to Section 4.01(e)(i) or Section 5.01(h)(ii) hereof at any time outstanding; and

(viii) the replacement, extension or renewal of any Lien permitted by clause (iii) or (iv) above upon or in the same property theretofore subject thereto or the replacement, extension or renewal (without increase in the amount or change in any direct or contingent obligor) of the Indebtedness secured thereby.

(e) Mergers, Etc. Merge or consolidate with or into any Person, or permit any of its Material Subsidiaries to do so, except that (i) any Material Subsidiary of the Borrower may merge or consolidate with or into any other Material Subsidiary of the Borrower, (ii) any Subsidiary of the Borrower may merge into the Borrower or any Material Subsidiary of the Borrower and (iii) the Borrower or any Material Subsidiary may merge with any other Person so long as the Borrower or such Material Subsidiary is the surviving corporation, provided, in each case, that no Default shall have occurred and be continuing at the time of such proposed transaction or would result therefrom.

(f) Sales, Etc. of Assets. Sell, lease, transfer or otherwise dispose of, or permit any of its Material Subsidiaries to sell, lease, transfer or otherwise dispose of, any assets, or grant any option or other right to purchase, lease or otherwise acquire any assets to any Person other than the Borrower or any Subsidiary of the Borrower, except (i) dispositions in the ordinary course of business, including, without limitation, sales or other dispositions of electricity and related and ancillary services, other commodities, emissions credits and similar mechanisms for reducing pollution, and damaged, obsolete, worn out or surplus property no longer required or useful in the business or operations of the Borrower or any of its Subsidiaries, (ii) sale or other disposition of patents, copyrights, trademarks or other intellectual property that are, in the Borrower’s reasonable judgment, no longer economically practicable to maintain or necessary in the conduct of the business of the Borrower or its Subsidiaries and any license or sublicense of intellectual property that does not interfere with the business of the Borrower or any Material Subsidiary, (iii) in a transaction authorized by subsection (b) of this Section, (iv) individual dispositions occurring in the ordinary course of business which involve assets with a book value not exceeding $5,000,000, (v) sales, leases, transfers or other dispositions of assets during the term of this Agreement having an aggregate book value not to exceed 30% of the total of all assets properly appearing on the most recent balance sheet of the Borrower provided pursuant to Section 4.01(e) or Section 5.01(h)(ii) hereof, (vi) at any time following the consummation of the Four Corners Acquisition, which occurred on December 30, 2013 and the closure by the Borrower of Units 1, 2 and 3 of the Four Corners Power Plant near Farmington, New Mexico, as described in the SEC Reports, disposition of all or any portion of the Borrower’s interests in such Units 1, 2 and 3, and (vii) any Lien permitted under Section 5.02(a).

Section 5.03 Financial Covenant. So long as any Loan or any other Obligations shall remain unpaid, the Borrower will maintain a ratio of (a) Consolidated Indebtedness to (b) the sum of Consolidated Indebtedness plus Consolidated Net Worth of not greater than 0.65 to 1.

ARTICLE VI

EVENTS OF DEFAULT

Section 6.01 Events of Default. If any of the following events (“Events of Default”) shall occur and be continuing:

(g) The Borrower shall fail to pay when due (i) any principal of any Loan or (ii) any interest on any Loan or any fees or other amounts payable under this Agreement or any other Loan Documents, and (in the case of this clause (ii) only) such failure shall continue for a period of three Business Days; or

(h) Any representation or warranty made by the Borrower herein or by the Borrower (or any of its officers) in any certificate or other document delivered in connection with this Agreement or any other Loan Document shall prove to have been incorrect in any material respect when made or deemed made or furnished; or

(i) (i) The Borrower shall fail to perform or observe any term, covenant or agreement contained in Section 2.15, Section 5.01(d) (as to the corporate existence of the Borrower), Section 5.01(h)(iii), Section 5.01(h)(vi), Section 5.02 or Section 5.03; or (ii) the Borrower shall fail to perform or observe any term, covenant or agreement contained in Section 5.01(e) if such failure shall remain unremedied for 15 days after written notice thereof shall have been given to the Borrower by the Agent or any Lender; or (iii) the Borrower shall fail to perform or observe any other term, covenant or agreement contained in this Agreement or any other Loan Document on its part to be performed or observed if such failure shall remain unremedied for 30 days after written notice thereof shall have been given to the Borrower by the Agent or any Lender; or

(j) (i) The Borrower or any of its Material Subsidiaries shall fail to pay (A) any principal of or premium or interest on any Indebtedness that is outstanding in a principal amount of at least $35,000,000 in the aggregate (but excluding Indebtedness outstanding hereunder), or (B) an amount, or post collateral as contractually required in an amount, of at least $35,000,000 in respect of any Hedge Agreement, of the Borrower or such Material Subsidiary (as the case may be), in each case, when the same becomes due and payable (whether by scheduled maturity, required prepayment, acceleration, demand or otherwise), and such failure shall continue after the applicable grace period, if any, specified in the agreement or instrument relating to such Indebtedness or Hedge Agreement; or (ii) any event of default shall exist under any agreement or instrument relating to any such Indebtedness and shall continue after the applicable grace period, if any, specified in such agreement or instrument, if the effect of such event is to accelerate, or to permit the acceleration of, the maturity of such Indebtedness; or

(k) The Borrower or any of its Material Subsidiaries shall fail to pay any principal of or premium or interest in respect of any operating lease in respect of which the payment obligations of the Borrower have a present value of at least $35,000,000, when the same becomes due and payable (whether by scheduled maturity, required prepayment, acceleration, demand or otherwise), and such failure shall continue after the applicable grace period, if any, specified in such operating lease, if the effect of such failure is to terminate, or to permit the termination of, such operating lease; or

(l) The Borrower or any of its Material Subsidiaries shall generally not pay its debts as such debts become due, or shall admit in writing its inability to pay its debts generally, or shall make a general assignment for the benefit of creditors; or any proceeding shall be instituted by or against the Borrower or any of its Material Subsidiaries seeking to adjudicate it a bankrupt or insolvent, or seeking liquidation, winding up, reorganization, arrangement, adjustment, protection, relief, or composition of it or its debts under any Debtor Relief Law, or seeking the entry of an order for relief or the appointment of a receiver, trustee, custodian or other similar official for it or for any substantial part of its property and, in the case of any such proceeding instituted against it (but not instituted by it), either such proceeding shall remain undismissed or unstayed for a period of 60 days, or any of the actions sought in such proceeding (including, without limitation, the entry of an order for relief against, or the appointment of a receiver, trustee, custodian or other similar official for, it or for any substantial part of its property) shall occur; or the Borrower or any of its Material Subsidiaries shall take any corporate action to authorize any of the actions set forth above in this subsection (f); or

(m) Judgments or orders for the payment of money that exceeds any applicable insurance coverage (the insurer of which shall be rated at least “A” by A.M. Best Company) by more than $35,000,000 in the aggregate shall be rendered against the Borrower or any Material Subsidiary and such judgments or orders shall continue unsatisfied or unstayed for a period of 45 days; or

(n) (i) Any “person” or “group” (as such terms are used in Sections 13(d) and 14(d) of the Securities Exchange Act of 1934, but excluding any employee benefit plan of such person or its subsidiaries, and any person or entity acting in its capacity as trustee, agent or other fiduciary or administrator of any such plan) becomes the “beneficial owner” (as defined in Rules 13d-3 and 13d-5 under the Securities Exchange Act of 1934), directly or indirectly, of 30% or more of the equity securities of PWCC entitled to vote for members of the board of directors of PWCC; or (ii) during any period of 24 consecutive months, a majority of the members of the board of directors of PWCC cease (other than due to death or disability) to be composed of individuals (A) who were members of that board on the first day of such period, (B) whose election or nomination to that board was approved by individuals referred to in clause (A) above constituting at the time of such election or nomination at least a majority of that board or (C) whose election or nomination to that board was approved by individuals referred to in clauses (A) and (B) above constituting at the time of such election or nomination at least a majority of that board; or (iii) PWCC shall cease for any reason to own, directly or indirectly, 80% of the Voting Stock of the Borrower; or

(o) (i) An ERISA Event occurs with respect to a Pension Plan or Multiemployer Plan which has resulted or could reasonably be expected to result in liability of the Borrower under Title IV of ERISA to the Pension Plan, Multiemployer Plan or the PBGC in an aggregate amount in excess of $35,000,000; or (ii) the Borrower or any ERISA Affiliate fails to pay when due, after the expiration of any applicable grace period, any installment payment with respect to its withdrawal liability under Section 4201 of ERISA under a Multiemployer Plan in an aggregate amount in excess of $35,000,000;

then, and in any such event, the Agent shall at the request, or may with the consent, of the Required Lenders, by notice to the Borrower, (i) declare the Loans, all interest thereon and all other amounts payable under this Agreement to be forthwith due and payable, whereupon the Loans, all such interest and all such amounts shall become and be forthwith due and payable, without presentment, demand, protest or further notice of any kind, all of which are hereby expressly waived by the Borrower; provided, however, that in the event of an actual or deemed entry of an order for relief with respect to the Borrower under the Bankruptcy Code of the United States of America, the Loans, all such interest and all such amounts shall automatically become and be due and payable, without presentment, demand, protest or any notice of any kind, all of which are hereby expressly waived by the Borrower, and (ii) exercise all rights and remedies available to it under this Agreement, the other Loan Documents and applicable Law.

ARTICLE VII

THE AGENT

Section 7.01 Appointment and Authority. Each of the Lenders hereby irrevocably appoints Toronto Dominion (Texas) LLC to act on its behalf as the Agent hereunder and under the other Loan Documents and authorizes the Agent to take such actions on its behalf and to exercise such powers as are delegated to the Agent by the terms hereof or thereof, together with such actions and powers as are reasonably incidental thereto. Except as set forth in Section 7.06, the provisions of this Article are solely for the benefit of the Agent and the Lenders, and neither the Borrower nor any of its Affiliates shall have rights as a third party beneficiary of any of such provisions.

Section 7.02 Rights as a Lender. The Person serving as the Agent hereunder shall have the same rights and powers in its capacity as a Lender as any other Lender and may exercise the same as though it were not the Agent and the term “Lender” or “Lenders” shall, unless otherwise expressly indicated or unless the context otherwise requires, include the Person serving as the Agent hereunder in its individual capacity. Such Person and its Affiliates may accept deposits from, lend money to, act as the financial advisor or in any other advisory capacity for and generally engage in any kind of business with the Borrower or any Subsidiary or other Affiliate thereof as if such Person were not the Agent hereunder and without any duty to account therefor to the Lenders.

Section 7.03 Exculpatory Provisions. The Agent shall not have any duties or obligations except those expressly set forth herein and in the other Loan Documents. Without limiting the generality of the foregoing, the Agent:

(c) shall not be subject to any fiduciary or other implied duties, regardless of whether a Default has occurred and is continuing;

(d) shall not have any duty to take any discretionary action or exercise any discretionary powers, except discretionary rights and powers expressly contemplated hereby or by the other Loan Documents that the Agent is required to exercise as directed in writing by the Required Lenders (or such other number or percentage of the Lenders as shall be expressly provided for herein), provided that the Agent shall not be required to take any action that, in its opinion or the opinion of its counsel, may expose the Agent to liability or that is contrary to any Loan Document or applicable Law; and

(e) shall not, except as expressly set forth herein and in the other Loan Documents, have any duty to disclose, and shall not be liable for the failure to disclose, any information relating to the Borrower or any of its Affiliates that is communicated to or obtained by the Person serving as the Agent or any of its Affiliates in any capacity.

The Agent shall not be liable for any action taken or not taken by it (i) with the consent or at the request of the Required Lenders (or such other number or percentage of the Lenders as shall be necessary, or as the Agent shall believe in good faith shall be necessary, under the circumstances as provided in Section 6.01 and Section 8.01) or (ii) in the absence of its own gross negligence or willful misconduct. The Agent shall be deemed not to have knowledge of any Default unless and until notice describing such Default is given to the Agent by the Borrower or a Lender.

The Agent shall not be responsible for or have any duty to ascertain or inquire into (i) any statement, warranty or representation made in or in connection with this Agreement or any other Loan Document, (ii) the contents of any certificate, report or other document delivered hereunder or thereunder or in connection herewith or therewith, (iii) the performance or observance of any of the covenants, agreements or other terms or conditions set forth herein or therein or the occurrence of any Default, (iv) the validity, enforceability, effectiveness or genuineness of this Agreement, any other Loan Document or any other agreement, instrument or document or (v) the satisfaction of any condition set forth in Article III or elsewhere herein, other than to confirm receipt of items expressly required to be delivered to the Agent.

Section 7.04 Reliance by Agent. The Agent shall be entitled to rely upon, and shall not incur any liability for relying upon, any notice, request, certificate, consent, statement, instrument, document or other writing (including any electronic message, internet or intranet website posting or other distribution) believed by it to be genuine and to have been signed, sent or otherwise authenticated by the proper Person. The Agent also may rely upon any statement made to it orally or by telephone and believed by it to have been made by the proper Person, and shall not incur any liability for relying thereon. In determining compliance with any condition hereunder to the making of any Loan that by its terms must be fulfilled to the satisfaction of a Lender, the Agent may presume that such condition is satisfactory to such Lender unless the Agent shall have received notice to the contrary from such Lender prior to the making of such Loan. The Agent may consult with legal counsel (who may be counsel for the Borrower), independent accountants and other experts selected by it, and shall not be liable for any action taken or not taken by it in good faith in accordance with the advice of any such counsel, accountants or experts.

Section 7.05 Delegation of Duties. The Agent may perform any and all of its duties and exercise its rights and powers hereunder or under any other Loan Document by or through any one or more sub-agents appointed by the Agent. The Agent and any such sub-agent may perform any and all of its duties and exercise its rights and powers by or through their respective Related Parties. The exculpatory provisions of this Article shall apply to any such sub-agent and to the Related Parties of the Agent and any such sub-agent, and shall apply to their respective activities in connection with the syndication of the credit facilities provided for herein as well as activities as Agent.

Section 7.06 Resignation of Agent. The Agent may at any time give notice of its resignation to the Lenders and the Borrower. Upon receipt of any such notice of resignation, the Required Lenders shall have the right, with the consent of the Borrower so long as no Event of Default has occurred and is continuing, to appoint a successor, which shall be a bank with an office in the United States of America, or an Affiliate of any such bank with an office in the United States of America. If no such successor shall have been so appointed by the Required Lenders and shall have accepted such appointment within 45 days after the retiring Agent gives notice of its resignation, then the retiring Agent may, on behalf of the Lenders, appoint a successor Agent meeting the qualifications set forth above; provided that if the Agent shall notify the Borrower and the Lenders that no qualifying Person has accepted such appointment, then such resignation shall nonetheless become effective in accordance with such notice and (1) the retiring Agent shall be discharged from its duties and obligations hereunder and under the other Loan Documents (except that in the case of any collateral security held by the Agent on behalf of the Lenders under any of the Loan Documents, the retiring Agent shall continue to hold such collateral security until such time as a successor Agent is appointed) and (2) all payments, communications and determinations provided to be made by, to or through the Agent shall instead be made by or to each Lender directly, until such time as the Required Lenders appoint a successor Agent as provided for above in this Section. Upon the acceptance of a successor’s appointment as Agent hereunder, such successor shall succeed to and become vested with all of the rights, powers, privileges and duties of the retiring (or retired) Agent, and the retiring Agent shall be discharged from all of its duties and obligations hereunder or under the other Loan Documents (if not already discharged therefrom as provided above in this Section). The fees payable by the Borrower to a successor Agent shall be as agreed between the Borrower and such successor. After the retiring Agent’s resignation hereunder and under the other Loan Documents, the provisions of this Article and Section 8.04 shall continue in effect for the benefit of such retiring Agent, its sub-agents and their respective Related Parties in respect of any actions taken or omitted to be taken by any of them while the retiring Agent was acting as Agent.

Section 7.07 Non-Reliance on Agent and Other Lenders. Each Lender acknowledges that it has, independently and without reliance upon the Agent or any other Lender or any of their Related Parties and based on such documents and information as it has deemed appropriate, made its own credit analysis and decision to enter into this Agreement. Each Lender also acknowledges that it will, independently and without reliance upon the Agent or any other Lender or any of their Related Parties and based on such documents and information as it shall from time to time deem appropriate, continue to make its own decisions in taking or not taking action under or based upon this Agreement, any other Loan Document or any related agreement or any document furnished hereunder or thereunder.

Section 7.08 No Other Duties, Etc. Anything herein to the contrary notwithstanding, none of the Arrangers or any other agents listed on the cover page hereof shall have any powers, duties or responsibilities under this Agreement or any of the other Loan Documents, except in its capacity, as applicable, as the Agent or a Lender hereunder.

ARTICLE VIII

MISCELLANEOUS

Section 8.01 Amendments, Etc. No amendment or waiver of any provision of this Agreement or any other Loan Document, nor consent to any departure by the Borrower therefrom, shall in any event be effective unless the same shall be in writing and signed by the Required Lenders, and then such waiver or consent shall be effective only in the specific instance and for the specific purpose for which given; provided, however, that no amendment, waiver or consent shall

(a) unless agreed to by each Lender directly affected thereby, (i) reduce or forgive the principal amount of any Loan, reduce the rate of or forgive any interest thereon (provided that only the consent of the Required Lenders shall be required to waive the applicability of any post-default increase in interest rates), or reduce or forgive any fees hereunder (other than fees payable to the Agent or the Arrangers for their own respective accounts), (ii) extend the final scheduled maturity date or any other scheduled date for the payment of any principal of or interest on any Loan, or extend the time of payment of any fees hereunder (other than fees payable to the Agent or the Arrangers for their own respective accounts), or (iii) increase any Commitment of any such Lender over the amount thereof in effect or extend the maturity thereof (it being understood that a waiver of any Default, if agreed to by the Required Lenders or all Lenders (as may be required hereunder with respect to such waiver), shall not constitute such an increase);

(b) unless agreed to by all of the Lenders, (i) reduce the percentage of the aggregate Commitments or of the aggregate unpaid principal amount of the Loans, or the number or percentage of Lenders, that shall be required for the Lenders or any of them to take or approve, or direct the Agent to take, any action hereunder or under any other Loan Document (including as set forth in the definition of “Required Lenders”), (ii) change any other provision of this Agreement or any of the other Loan Documents requiring, by its terms, the consent or approval of all the Lenders for any amendment, modification, waiver, discharge or termination thereof or any consent to any departure by the Borrower therefrom, or (iii) change or waive any provision of Section 2.13, any other provision of this Agreement or any other Loan Document requiring pro rata treatment of any Lenders, or this Section 8.01 or Section 2.17(b); and

(c) unless agreed to by the Agent in addition to the Lenders required as provided hereinabove to take such action, affect the respective rights or obligations of the Agent hereunder or under any of the other Loan Documents.

(d) If, in connection with any proposed amendment, waiver or consent requiring the consent of “each Lender” or “each Lender directly affected thereby,” the consent of the Required Lenders is obtained, but the consent of other necessary Lenders is not obtained (any such Lender whose consent is necessary but not obtained being referred to herein as a “Non-Consenting Lender”), then the Borrower may elect to replace a Non-Consenting Lender as a Lender party to this Agreement, provided that, concurrently with such replacement, (i) another bank or other entity which is reasonably satisfactory to the Borrower and the Agent shall agree, as of such date, to purchase for cash the Loans and other Obligations due to the Non-Consenting Lender pursuant to an Assignment and Assumption and to become a Lender for all purposes under this Agreement and to assume all obligations of the Non-Consenting Lender to be terminated as of such date and to comply with the requirements of clause (b) of Section 8.07, and (ii) the Borrower shall pay to such Non-Consenting Lender in same day funds on the day of such replacement (1) all interest, fees and other amounts then accrued but unpaid to such Non-Consenting Lender by the Borrower hereunder to and including the date of termination, including without limitation payments due to such Non-Consenting Lender under Sections 2.09 and 2.12, and (2) an amount, if any, equal to the payment which would have been due to such Lender on the day of such replacement under Section 8.04(e) had the Loans of such Non-Consenting Lender been prepaid on such date rather than sold to the replacement Lender.

Section 8.02 Notices, Etc.

(f) All notices and other communications provided for hereunder shall be either (x) in writing (including facsimile communication) and mailed, faxed or delivered or (y) delivered, furnished, distributed or made available as and to the extent set forth in Sections 8.02(b) and (c), if to the Borrower, at the address specified on Schedule 8.02; if to any Lender, at its Domestic Lending Office; and if to the Agent, at the address specified on Schedule 8.02; or, as to the Borrower or the Agent, at such other address as shall be designated by such party in a written notice to the other parties and, as to each other party, at such other address as shall be designated by such party in a written notice to the Borrower and the Agent. All such notices and communications shall, when mailed or faxed, be effective when deposited in the mails or faxed, respectively, except that notices and communications to the Agent pursuant to Article II, III or VII shall not be effective until received by the Agent. Delivery by facsimile of an executed counterpart of any amendment or waiver of any provision of this Agreement or the Notes or of any Exhibit hereto to be executed and delivered hereunder shall be effective as delivery of a manually executed counterpart thereof. Notices delivered through electronic communications to the extent provided in subsection (b) below, shall be effective as provided in such subsection (b). Upon request of the Borrower, the Agent will provide to the Borrower (i) copies of each Administrative Questionnaire or (ii) the address of each Lender.

(g) Notices and other communications to the Lenders and the Agent hereunder may be delivered or furnished by electronic communication (including e-mail and Internet or intranet websites) pursuant to procedures approved by the Agent and agreed to by the Borrower, provided that the foregoing shall not apply to notices to any Lender pursuant to Article II if such Lender has notified the Agent and the Borrower that it is incapable of receiving notices under such Article by electronic communication. The Agent or the Borrower may, in its discretion, agree to accept notices and other communications to it hereunder by electronic communications pursuant to procedures approved by it, provided that approval of such procedures may be limited to particular notices or communications. Unless the Agent and the Borrower otherwise agree, (i) notices and other communications sent to an e-mail address shall be deemed received upon the sender’s receipt of an acknowledgement from the intended recipient (such as by the “return receipt requested” function, as available, return e-mail or other written acknowledgement), provided that if such notice or other communication is not sent during the normal business hours of the recipient, such notice or communication shall be deemed to have been sent at the opening of business on the next Business Day for the recipient, and (ii) notices or communications posted to an Internet or intranet website shall be deemed received upon the deemed receipt by the intended recipient at its e-mail address as described in the foregoing clause (i) of notification that such notice or communication is available and identifying the website address therefor.

(h) The Borrower agrees that the Agent may make materials delivered to the Agent pursuant to Sections 5.01(h)(i), (ii) and (iv), as well as any other written information, documents, instruments and other material relating to the Borrower or any of its Subsidiaries and relating to this Agreement, the Notes or the transactions contemplated hereby, or any other materials or matters relating to this Agreement, the Notes or any of the transactions contemplated hereby (collectively, the “Communications”) available to the Lenders by posting such notices on Intralinks or a substantially similar electronic system (the “Platform”). The Borrower acknowledges that (i) the distribution of material through an electronic medium is not necessarily secure and that there are confidentiality and other risks associated with such distribution, (ii) the Platform is provided “as is” and “as available” and (iii) neither the Agent nor any of its Affiliates warrants the accuracy, adequacy or completeness of the Communications or the Platform and each expressly disclaims liability for errors or omissions in the Communications or the Platform. No warranty of any kind, express, implied or statutory, including, without limitation, any warranty of merchantability, fitness for a particular purpose, non-infringement of third party rights or freedom from viruses or other code defects, is made by the Agent or any of its Affiliates in connection with the Platform.

(i) Each Lender agrees that notice to it (as provided in the next sentence) (a “Notice”) specifying that any Communications have been posted to the Platform shall constitute effective delivery of such information, documents or other materials to such Lender for purposes of this Agreement; provided that if requested by any Lender the Agent shall deliver a copy of the Communications to such Lender by e-mail, facsimile or mail. Each Lender agrees (i) to notify the Agent in writing of such Lender’s e-mail address to which a Notice may be sent by electronic transmission (including by electronic communication) on or before the date such Lender becomes a party to this Agreement (and from time to time thereafter to ensure that the Agent has on record an effective e-mail address for such Lender) and (ii) that any Notice may be sent to such e-mail address.

(j) The Borrower hereby acknowledges that certain of the Lenders may be “public-side” Lenders (i.e., Lenders that do not wish to receive material non-public information with respect to the Borrower or its securities) (each, a “Public Lender”). The Borrower hereby agrees that (w) all Communications that are to be made available to Public Lenders shall be clearly and conspicuously marked “PUBLIC” which shall mean that the word “PUBLIC” shall appear prominently on the first page thereof; (x) by marking Communications “PUBLIC,” the Borrower shall be deemed to have authorized the Agent, the Arrangers and the Lenders to treat such Communications as not containing any material non-public information with respect to the Borrower or its securities for purposes of United States of America federal and state securities laws; (y) all Communications marked “PUBLIC” are permitted to be made available through a portion of the Platform designated as “Public Investor;” and (z) the Agent and the Arrangers shall be entitled to treat any Communications that are not marked “PUBLIC” as being suitable only for posting on a portion of the Platform not marked as “Public Investor.” Notwithstanding the foregoing, the Borrower shall be under no obligation to mark any Communications “PUBLIC.” Notwithstanding anything to the contrary herein, the Borrower and the Agent need not provide to any Public Lender any information, notice, or other document hereunder that is not public information, including without limitation, the Notice of Initial Borrowing and any notice of Default.

Section 8.03 No Waiver; Cumulative Remedies; Enforcement. No failure by any Lender or the Agent to exercise, and no delay by any such Person in exercising, any right, remedy, power or privilege hereunder shall operate as a waiver thereof; nor shall any single or partial exercise of any right, remedy, power or privilege hereunder preclude any other or further exercise thereof or the exercise of any other right, remedy, power or privilege. The rights, remedies, powers and privileges herein provided are cumulative and not exclusive of any rights, remedies, powers and privileges provided by Law.

Notwithstanding anything to the contrary contained herein or in any other Loan Document, the authority to enforce rights and remedies hereunder and under the other Loan Documents against the Borrower shall be vested exclusively in, and all actions and proceedings at Law in connection with such enforcement shall be instituted and maintained exclusively by, the Agent in accordance with Article VI for the benefit of all the Lenders; provided, however, that the foregoing shall not prohibit (a) the Agent from exercising on its own behalf the rights and remedies that inure to its benefit (solely in its capacity as Agent) hereunder and under the other Loan Documents, (b) any Lender from exercising setoff rights in accordance with Section 8.05 (subject to the terms of Section 2.13), or (c) any Lender from filing proofs of claim or appearing and filing pleadings on its own behalf during the pendency of a proceeding relative to the Borrower under any Debtor Relief Law; and provided, further, that if at any time there is no Person acting as Agent hereunder and under the other Loan Documents, then (i) the Required Lenders shall have the rights otherwise ascribed to the Agent pursuant to Article VI and (ii) in addition to the matters set forth in clauses (b) and (c) of the preceding proviso and subject to Section 2.13, any Lender may, with the consent of the Required Lenders, enforce any rights and remedies available to it and as authorized by the Required Lenders.

Section 8.04 Costs and Expenses; Indemnity; Damage Waiver.

(a) The Borrower agrees to pay on demand all costs and expenses of the Agent in connection with the administration, modification and amendment of this Agreement, the Notes and the other Loan Documents to be delivered hereunder, including, without limitation, the reasonable fees and expenses of counsel for the Agent with respect thereto and with respect to advising the Agent as to its rights and responsibilities under this Agreement. The Borrower further agrees to pay on demand all costs and expenses of the Agent and the Lenders, if any (including, without limitation, reasonable counsel fees and expenses), in connection with the enforcement (whether through negotiations, legal proceedings or otherwise) of this Agreement, the Notes and the other Loan Documents to be delivered hereunder, including, without limitation, reasonable fees and expenses of counsel for the Agent and each Lender in connection with the enforcement of rights under this Section 8.04(a).

(b) The Borrower agrees to indemnify and hold harmless the Agent (and any sub-agent thereof), each Lender, each Arranger and each Related Party of any of the foregoing (each, an “Indemnified Party”) from and against any and all claims, damages, losses, liabilities and expenses (including, without limitation, reasonable fees and expenses of counsel) incurred by or asserted or awarded against any Indemnified Party, in each case arising out of or in connection with or by reason of (including, without limitation, in connection with any investigation, litigation or proceeding or preparation of a defense in connection therewith, whether based on contract, tort or any other theory) (i) the Notes, this Agreement, any other Loan Document, any of the transactions contemplated herein or the actual or proposed use of the proceeds of any Loan, or (ii) the actual or alleged presence of Hazardous Materials on any property of the Borrower or any of its Subsidiaries or any Environmental Action relating in any way to the Borrower or any of its Subsidiaries, provided that such indemnity shall not, as to any Indemnified Party, be available to the extent (a) such fees and expenses are expressly stated in this Agreement to be payable by the Indemnified Party, included expenses payable under Section 2.12, Section 5.01(e) and Section 8.07(b) or (b) such claim, damage, loss, liability or expense is found in a final, non-appealable judgment by a court of competent jurisdiction to have resulted from such Indemnified Party’s gross negligence, willful misconduct or material breach of its obligations under this Agreement, in which case any fees and expenses previously paid or advanced by the Borrower to such Indemnified Party in respect of such indemnified obligation will be returned by such Indemnified Party. In the case of an investigation, litigation or other proceeding to which the indemnity in this Section 8.04(b) applies, such indemnity shall be effective whether or not such investigation, litigation or proceeding is brought by the Borrower, its directors, equityholders or creditors or an Indemnified Party or any other Person, whether or not any Indemnified Party is otherwise a party thereto, and whether or not the transactions contemplated hereby are consummated, provided that if the Borrower and such Indemnified Party are adverse parties in any such litigation or proceeding, and the Borrower prevails in a final, non-appealable judgment by a court of competent jurisdiction, any amounts under this Section 8.04(b) previously paid or advanced by the Borrower to such Indemnified Party pursuant to this Section 8.04(b) will be returned by such Indemnified Party.

(c) To the extent that the Borrower for any reason fails to indefeasibly pay any amount required under subsection (a) or (b) of this Section to be paid by it to the Agent (or any sub-agent thereof) or any Related Party of any of the foregoing (and without limiting its obligation to do so), each Lender severally agrees to pay to the Agent (or any such sub-agent) or such Related Party, as the case may be, such Lender’s Ratable Share (determined as of the time that the applicable unreimbursed expense or indemnity payment is sought) of such unpaid amount, provided that the unreimbursed expense or indemnified loss, claim, damage, liability or related expense, as the case may be, was incurred by or asserted against the Agent (or any such sub-agent) in its capacity as such, or against any Related Party of any of the foregoing acting for the Agent (or any such sub-agent) in connection with such capacity.

(d) Without limiting the rights of indemnification of the Indemnified Parties set forth in this Agreement with respect to liabilities asserted by third parties, each party hereto also agrees not to assert any claim for special, indirect, consequential or punitive damages against the other parties hereto, or any Related Party of any party hereto, on any theory of liability, arising out of or otherwise relating to the Notes, this Agreement, any other Loan Document, any of the transactions contemplated herein or the actual or proposed use of the proceeds of the Loans. No Indemnified Party shall be liable for any damages arising from the use by unintended recipients of any information or other materials distributed by it through telecommunications, electronic or other information transmission systems (including Intralinks, SyndTrak or similar systems) in connection with this Agreement or the other Loan Documents, provided that such indemnity shall not, as to any Indemnified Party, be available to the extent such damages are found in a final, non-appealable judgment by a court of competent jurisdiction to have resulted from such Indemnified Party’s gross negligence or willful misconduct.

(e) If any payment of principal of, or Conversion of, any Eurodollar Rate Loan is made by the Borrower to or for the account of a Lender other than on the last day of the Interest Period for such Loan, as a result of a payment or Conversion pursuant to Section 2.06(d) or (e), Section 2.08 or Section 2.10, acceleration of the maturity of the Loans pursuant to Section 6.01 or for any other reason, or by an Eligible Assignee to a Lender other than on the last day of the Interest Period for such Loan upon an assignment of rights and obligations under this Agreement pursuant to Section 8.07 as a result of a demand by the Borrower pursuant to Section 2.17, the Borrower shall, upon demand by such Lender (with a copy of such demand to the Agent), pay to the Agent for the account of such Lender any amounts required to compensate such Lender for any additional losses, costs or expenses that it may reasonably incur as a result of such payment or Conversion, including, without limitation, any loss (excluding loss of anticipated profits), cost or expense incurred by reason of the liquidation or reemployment of deposits or other funds acquired by any Lender to fund or maintain such Loan.

(f) Without prejudice to the survival of any other agreement of the Borrower hereunder, the agreements and obligations of the Borrower contained in Sections 2.09, 2.12 and 8.04 shall survive the payment in full of principal, interest and all other amounts payable hereunder and under the Notes.

Section 8.05 Right of Set-off. Upon (i) the occurrence and during the continuance of any Event of Default and (ii) the making of the request or the granting of the consent specified by Section 6.01 to authorize the Agent to declare the Loans due and payable pursuant to the provisions of Section 6.01, each Lender and each of its Affiliates is hereby authorized at any time and from time to time, to the fullest extent permitted by Law, to set off and apply any and all deposits (general or special, time or demand, provisional or final) at any time held and other indebtedness at any time owing by such Lender or any such Affiliate to or for the credit or the account of the Borrower against any and all of the obligations of the Borrower now or hereafter existing under this Agreement or any other Loan Document to such Lender, whether or not such Lender shall have made any demand under this Agreement or such Note and although such obligations may be contingent or unmatured or are owed to a branch or office of such Lender different from the branch or office holding such deposit or obligated on such indebtedness. Each Lender agrees promptly to notify the Borrower after any such set-off and application, provided that the failure to give such notice shall not affect the validity of such set-off and application. The rights of each Lender under this Section are in addition to other rights and remedies (including, without limitation, other rights of set-off) that such Lender may have.

Section 8.06 Effectiveness; Binding Effect. Except as provided in Section 3.01, this Agreement shall become effective when it shall have been executed by the Borrower and the Agent and when the Agent shall have received counterparts hereof that, when taken together, bear the signatures of each of the other parties hereto and thereafter shall be binding upon and inure to the benefit of the Borrower, the Agent and each Lender and their respective successors and assigns, except that the Borrower shall not have the right to assign its rights hereunder or any interest herein without the prior written consent of the Lenders (and any purported assignment without such consent shall be null and void).

Section 8.07 Successors and Assigns.

(a) The provisions of this Agreement shall be binding upon and inure to the benefit of the parties hereto and their respective successors and assigns permitted hereby, except that the Borrower may not assign or otherwise transfer any of its rights or obligations hereunder without the prior written consent of the Agent and each Lender (and any purported assignment or transfer without such consent shall be null and void) and no Lender may assign or otherwise transfer any of its rights or obligations hereunder except (i) to an assignee in accordance with the provisions of subsection (b) of this Section, (ii) by way of participation in accordance with the provisions of subsection (d) of this Section, or (iii) by way of pledge or assignment of a security interest subject to the restrictions of subsection (f) of this Section. Nothing in this Agreement, expressed or implied, shall be construed to confer upon any Person (other than the parties hereto, their respective successors and assigns permitted hereby, Participants to the extent provided in subsection (d) of this Section and, to the extent expressly contemplated hereby, the Related Parties of each of the Agent and the Lenders) any legal or equitable right, remedy or claim under or by reason of this Agreement.

(b) Any Lender may at any time assign to one or more assignees (other than to an Ineligible Institution) all or a portion of its rights and obligations under this Agreement (including all or a portion of the Loans owing to it at such time); provided that any such assignment shall be subject to the following conditions:

(iii) Minimum Amounts.

(A) in the case of an assignment of the entire principal amount of the assigning Lender’s Loans at the time owing to it or in the case of an assignment to a Lender, no minimum amount need be assigned; and

(B) in any case not described in subsection (b)(i)(A) of this Section, the aggregate outstanding principal amount of the Loans of the assigning Lender subject to each such assignment, determined as of the date the Assignment and Assumption with respect to which such assignment is delivered to the Agent or, if “Trade Date” is specified in the Assignment and Assumption, as of the Trade Date, shall not be less than $5,000,000 unless each of the Agent and, so long as no Event of Default has occurred and is continuing, the Borrower otherwise consents (each such consent not to be unreasonably withheld or delayed).

(iv) Proportionate Amounts. Each partial assignment shall be made as an assignment of a proportionate part of all the assigning Lender’s rights and obligations under this Agreement with respect to the Loans assigned, and each such assignment shall be of a constant, and not a varying, percentage of all rights and obligations under this Agreement;

(v) Required Consents. No consent shall be required for any assignment except to the extent required by subsection (b)(i)(B) of this Section and, in addition:

(A) the consent of the Borrower (such consent not to be unreasonably withheld or delayed; provided that the Borrower shall be deemed to have consented to any such assignment unless it shall object thereto by written notice to the Agent within ten (10) Business Days after having received written notice thereof) shall be required unless (1) an Event of Default has occurred and is continuing at the time of such assignment or (2) such assignment is to a Lender, an Affiliate of a Lender or an Approved Fund; and

(B) the consent of the Agent (such consent not to be unreasonably withheld or delayed) shall be required if such assignment is to a Person that is not a Lender, an Affiliate of a Lender or an Approved Fund with respect to such Lender.

(vi) Assignment and Assumption. The parties to each assignment shall execute and deliver to the Agent an Assignment and Assumption, together with a processing and recordation fee in the amount of $3,500; provided, however, that no such fee shall be payable in the case of an assignment made at the request of the Borrower to an existing Lender. The assignee, if it is not a Lender, shall deliver to the Agent an Administrative Questionnaire.

(vii) No Assignment to Ineligible Institutions. No such assignment shall be made to any Ineligible Institution.

Subject to acceptance and recording thereof by the Agent pursuant to subsection (c) of this Section and notice thereof to the Borrower, from and after the effective date specified in each Assignment and Assumption, the assignee thereunder shall be a party to this Agreement and, to the extent of the interest assigned by such Assignment and Assumption, have the rights and obligations of a Lender under this Agreement, and the assigning Lender thereunder shall, to the extent of the interest assigned by such Assignment and Assumption, be released from its obligations under this Agreement (and, in the case of an Assignment and Assumption covering all of the assigning Lender’s rights and obligations under this Agreement, such Lender shall cease to be a party hereto) but shall continue to be entitled to the benefits of Sections 2.09, 2.12 and 8.04 with respect to facts and circumstances occurring prior to the effective date of such assignment. Upon request, the Borrower (at its expense) shall execute and deliver a Note to the assignee Lender. Any assignment or transfer by a Lender of rights or obligations under this Agreement that does not comply with this subsection shall be treated for purposes of this Agreement as a sale by such Lender of a participation in such rights and obligations in accordance with subsection (d) of this Section.

(c) Register. The Agent shall maintain at the Agent’s Office a copy of each Assignment and Assumption delivered to it and a register for the recordation of the names and addresses of the Lenders, and the Commitments of, and principal amounts of the Loans owing to, each Lender pursuant to the terms hereof from time to time (the “Register”). The entries in the Register shall be conclusive, absent manifest error, and the Borrower, the Agent and the Lenders may treat each Person whose name is recorded in the Register pursuant to the terms hereof as a Lender hereunder for all purposes of this Agreement, notwithstanding notice to the contrary. The Register shall be available for inspection by the Borrower and any Lender, at any reasonable time and from time to time upon reasonable prior notice.

(d) Participations. Any Lender may at any time, without the consent of, or notice to, the Borrower or the Agent, sell participations to any Person (other than an Ineligible Institution) (each, a “Participant”) in all or a portion of such Lender’s rights and/or obligations under this Agreement (including all or a portion of the Loans owing to it); provided that (i) such Lender’s obligations under this Agreement shall remain unchanged, (ii) such Lender shall remain solely responsible to the other parties hereto for the performance of such obligations, (iii) the Borrower, the Agent and the Lenders shall continue to deal solely and directly with such Lender in connection with such Lender’s rights and obligations under this Agreement and (iv) no participant under any such participation shall have any right to approve any amendment or waiver of any provision of this Agreement or any Note, or any consent to any departure by the Borrower therefrom, except to the extent that such amendment, waiver or consent would reduce the principal of, or interest on, any Obligations or any fees or other amounts payable hereunder, in each case to the extent subject to such participation, or postpone any date fixed for any payment of principal of, or interest on, any Obligations or any fees or other amounts payable hereunder, in each case to the extent subject to such participation.

Any agreement or instrument pursuant to which a Lender sells such a participation shall provide that such Lender shall retain the sole right to enforce this Agreement and to approve any amendment, modification or waiver of any provision of this Agreement; provided that such agreement or instrument may provide that such Lender will not, without the consent of the Participant, agree to any amendment, waiver or other modification addressing the matters set forth in clause (iv) above to the extent subject to such participation. Subject to subsection (e) of this Section, the Borrower agrees that each Participant shall be entitled to the benefits of Sections 2.09, 2.12 and 8.04(e) to the same extent as if it were a Lender and had acquired its interest by assignment pursuant to subsection (b) of this Section. To the extent permitted by Law, each Participant also shall be entitled to the benefits of Section 8.05 as though it were a Lender, provided such Participant agrees to be subject to Section 2.13 as though it were a Lender. Each Lender that sells a participation shall, acting solely for this purpose as an agent of the Borrower, maintain a register on which it enters the name and address of each Participant and the principal amounts (and stated interest) of each Participant’s interest in the Loans or other obligations under the Loan Documents (the “Participant Register”); provided that no Lender shall have any obligation to disclose all or any portion of the Participant Register (including the identity of any Participant or any information relating to a Participant’s interest in any Loans or its other obligations under any Loan Document) to any Person except to the extent that such disclosure is necessary to establish that such Loan or other obligation is in registered form under Section 5f.103-1(c) of the United States Treasury Regulations. The entries in the Participant Register shall be conclusive absent manifest error, and such Lender shall treat each Person whose name is recorded in the Participant Register as the owner of such participation for all purposes of this Agreement notwithstanding any notice to the contrary. For the avoidance of doubt, the Agent (in its capacity as Agent) shall have no responsibility for maintaining a Participant Register.

(e) Limitations upon Participant Rights. A Participant shall not be entitled to receive any greater payment under Section 2.09 or Section 2.12 than the applicable Lender would have been entitled to receive with respect to the participation sold to such Participant, unless the sale of the participation to such Participant is made with the Borrower’s prior written consent. A Participant that would be a Foreign Lender if it were a Lender shall not be entitled to the benefits of Section 2.12 unless the Borrower is notified of the participation sold to such Participant and such Participant agrees, for the benefit of the Borrower, to comply with Section 2.12(e) as though it were a Lender.

(f) Certain Pledges. Any Lender may at any time pledge or assign a security interest in all or any portion of its rights under this Agreement (including under its Note, if any) to secure obligations of such Lender, including any pledge or assignment to secure obligations to a Federal Reserve Bank or other central banking authority; provided that no such pledge or assignment shall release such Lender from any of its obligations hereunder or substitute any such pledgee or assignee for such Lender as a party hereto.

(g) The words “execution,” “signed,” “signature,” and words of like import in any Assignment and Assumption shall be deemed to include electronic signatures or the keeping of records in electronic form, each of which shall be of the same legal effect, validity or enforceability as a manually executed signature or the use of a paper-based recordkeeping system, as the case may be, to the extent and as provided for in any applicable Law, including the Federal Electronic Signatures in Global and National Commerce Act, the New York State Electronic Signatures and Records Act, or any other similar state Laws based on the Uniform Electronic Transactions Act.

Section 8.08 Confidentiality. Neither the Agent nor any Lender may disclose to any Person any confidential, proprietary or non-public information of the Borrower furnished to the Agent or the Lenders by the Borrower (such information being referred to collectively herein as the “Borrower Information”), except that each of the Agent and each of the Lenders may disclose Borrower Information (i) to its and its Affiliates’ employees, officers, directors, agents and advisors having a need to know in connection with this Agreement (it being understood that the Persons to whom such disclosure is made will be informed of the confidential nature of such Borrower Information and instructed to keep such Borrower Information confidential on substantially the same terms as provided herein), (ii) to the extent requested by any regulatory authority or self regulatory body, (iii) to the extent required by applicable Laws or regulations or by any subpoena or similar legal process, (iv) to any other party to this Agreement, (v) in connection with the exercise of any remedies hereunder or any suit, action or proceeding relating to this Agreement or the enforcement of rights hereunder, (vi) subject to an agreement containing provisions substantially the same as those of this Section 8.08, (A) to any assignee or participant or prospective assignee or participant, (B) to any direct, indirect, actual or prospective counterparty (and its advisor) to any swap, derivative or securitization transaction related to the obligations under this Agreement and (C) to any credit insurance provider relating to the Borrower and its Obligations, (vii) to the extent such Borrower Information (A) is or becomes generally available to the public on a non-confidential basis other than as a result of a breach of this Section 8.08 by the Agent or such Lender or their Related Parties, or (B) is or becomes available to the Agent or such Lender on a nonconfidential basis from a source other than the Borrower (provided that the source of such information was not known by the recipient after inquiry to be bound by a confidentiality agreement with or other contractual, legal or fiduciary obligation of confidentiality to the Borrower or any other Person with respect to such information) and (viii) with the consent of the Borrower. The obligations under this Section 8.08 shall survive for two calendar years after the date of the termination of this Agreement.

Section 8.09 Governing Law. This Agreement and the Notes shall be governed by, and construed in accordance with, the Laws of the State of New York.

Section 8.10 Counterparts; Integration. This Agreement may be executed in counterparts (and by different parties hereto in different counterparts), each of which shall constitute an original, but all of which when taken together shall constitute a single contract. Delivery of an executed counterpart of a signature page of this Agreement by telecopy or other electronic imaging means shall be effective as delivery of a manually executed counterpart of this Agreement. This Agreement and the other Loan Documents constitute the entire contract among the parties relating to the subject matter hereof and supersede any and all previous agreements and understandings, oral or written, relating to the subject matter hereof.

Section 8.11 Jurisdiction, Etc.

(e) Each of the parties hereto hereby submits to the exclusive jurisdiction of any New York State court or federal court of the United States of America sitting in the Borough of Manhattan in New York City, and any appellate court from any thereof, in any action or proceeding arising out of or relating to this Agreement or the other Loan Documents, or for recognition or enforcement of any judgment, and each of the parties hereto hereby agrees that all claims in respect of any such action or proceeding may be heard and determined in any such New York State court or, to the extent permitted by Law, in such federal court. Except to the extent expressly set forth in the preceding sentence, nothing in this Agreement shall affect any right that any party may otherwise have to bring any action or proceeding relating to this Agreement or the Notes in the courts of any jurisdiction.

(f) Each of the parties hereto irrevocably and unconditionally waives, to the fullest extent it may legally and effectively do so, any objection that it may now or hereafter have to the laying of venue of any suit, action or proceeding arising out of or relating to this Agreement or the Notes in any New York State court or federal court of the United States of America sitting in the Borough of Manhattan in New York City, and any appellate court from any thereof. Each of the parties hereto hereby irrevocably waives, to the fullest extent permitted by Law, the defense of an inconvenient forum to the maintenance of such action or proceeding in any such court.

Section 8.12 Payments Set Aside. To the extent that any payment by or on behalf of the Borrower is made to the Agent or any Lender, or the Agent or any Lender exercises its right of setoff, and such payment or the proceeds of such setoff or any part thereof is subsequently invalidated, declared to be fraudulent or preferential, set aside or required (including pursuant to any settlement entered into by the Agent or such Lender in its discretion) to be repaid to a trustee, receiver or any other party, in connection with any proceeding under any Debtor Relief Law or otherwise, then (a) to the extent of such recovery, the obligation or part thereof originally intended to be satisfied shall be revived and continued in full force and effect as if such payment had not been made or such setoff had not occurred, and (b) each Lender severally agrees to pay to the Agent upon demand its applicable share (without duplication) of any amount so recovered from or repaid by the Agent, plus interest thereon from the date of such demand to the date such payment is made at a rate per annum equal to the Federal Funds Rate from time to time in effect. The obligations of the Lenders under clause (b) of the preceding sentence shall survive the payment in full of the Obligations and the termination of this Agreement.

Section 8.13 Patriot Act. The Agent and each Lender hereby notifies the Borrower that pursuant to the requirements of the PATRIOT Act, it is required to obtain, verify and record information that identifies each borrower (including the Borrower), guarantor or grantor (the “Loan Parties”), which information includes the name and address of each Loan Party and other information that will allow such Lender to identify such Loan Party in accordance with the PATRIOT Act. The Borrower shall provide, to the extent commercially reasonable, such information and take such actions as are reasonably requested by the Agent or any Lender in order to assist the Agent and such Lender in maintaining compliance with the PATRIOT Act.

Section 8.14 Waiver of Jury Trial. EACH OF THE BORROWER, THE AGENT AND THE LENDERS HEREBY IRREVOCABLY WAIVES ALL RIGHT TO TRIAL BY JURY IN ANY ACTION, PROCEEDING OR COUNTERCLAIM (WHETHER BASED ON CONTRACT, TORT OR OTHERWISE) ARISING OUT OF OR RELATING TO THIS AGREEMENT, THE NOTES OR ANY OTHER LOAN DOCUMENT OR THE ACTIONS OF THE BORROWER, THE AGENT OR ANY LENDER IN THE NEGOTIATION, ADMINISTRATION, PERFORMANCE OR ENFORCEMENT THEREOF.

Section 8.15 No Advisory or Fiduciary Responsibility. In connection with all aspects of each transaction contemplated hereby, the Borrower acknowledges and agrees that: (i) the credit facilities provided for hereunder and any related arranging or other services in connection therewith (including in connection with any amendment, waiver or other modification hereof or of any other Loan Document) are an arm’s-length commercial transaction between the Borrower, on the one hand, and the Agent, each of the Lenders and each of the Arrangers, on the other hand, and the Borrower is capable of evaluating and understanding and understands and accepts the terms, risks and conditions of the transactions contemplated hereby and by the other Loan Documents (including any amendment, waiver or other modification hereof or thereof); (ii) in connection with the process leading to such transaction, each of the Agent, the Lenders and the Arrangers is and has been acting solely as a principal and is not the financial advisor, agent or fiduciary, for the Borrower or any of its Affiliates, stockholders, creditors or employees or any other Person; (iii) neither the Agent nor any Lender or Arranger has assumed or will assume an advisory, agency or fiduciary responsibility in favor of the Borrower with respect to any of the transactions contemplated hereby or the process leading thereto, including with respect to any amendment, waiver or other modification hereof or of any other Loan Document (irrespective of whether the Agent or any Lender or Arranger has advised or is currently advising the Borrower or any of its Affiliates on other matters) and neither the Agent nor any Lender or Arranger has any obligation to the Borrower with respect to the transactions contemplated hereby except those obligations expressly set forth herein and in the other Loan Documents; (iv) the Agent, each of the Lenders and the Arrangers and their respective Affiliates may be engaged in a broad range of transactions that involve interests that differ from those of the Borrower and its Affiliates, and neither the Agent nor any Lender or Arranger has any obligation to disclose any of such interests by virtue of any advisory, agency or fiduciary relationship; and (v) the Agent and each Lender and Arranger have not provided and will not provide any legal, accounting, regulatory or tax advice with respect to any of the transactions contemplated hereby (including any amendment, waiver or other modification hereof or of any other Loan Document) and the Borrower has consulted its own legal, accounting, regulatory and tax advisors to the extent it has deemed appropriate. The Borrower hereby waives and releases, to the fullest extent permitted by Law, any claims that it may have against the Agent and each Lender and Arranger with respect to any breach or alleged breach of agency or fiduciary duty in connection with the Loan Documents.

Section 8.16 Survival of Representations and Warranties. All representations and warranties made hereunder and in any other Loan Document or other document delivered pursuant hereto or thereto or in connection herewith or therewith shall survive the execution and delivery hereof and thereof. Such representations and warranties have been or will be relied upon by the Agent and each Lender, regardless of any investigation made by the Agent or any Lender or on their behalf, and shall continue in full force and effect as long as any Loan or any other Obligation hereunder shall remain unpaid or unsatisfied.

Section 8.17 Severability. If any provision of this Agreement or the other Loan Documents is held to be illegal, invalid or unenforceable, (a) the legality, validity and enforceability of the remaining provisions of this Agreement and the other Loan Documents shall not be affected or impaired thereby and (b) the parties shall endeavor in good faith negotiations to replace the illegal, invalid or unenforceable provisions with valid provisions the economic effect of which comes as close as possible to that of the illegal, invalid or unenforceable provisions. The invalidity of a provision in a particular jurisdiction shall not invalidate or render unenforceable such provision in any other jurisdiction.

Section 8.18 Acknowledgement and Consent to Bail-In of EEA Financial Institutions. Notwithstanding anything to the contrary in any Loan Document or in any other agreement, arrangement or understanding among any such parties, each party hereto acknowledges that any liability of any EEA Financial Institution arising under any Loan Document, to the extent such liability is unsecured, may be subject to the write-down and conversion powers of an EEA Resolution Authority and agrees and consents to, and acknowledges and agrees to be bound by:

(a) the application of any Write-Down and Conversion Powers by an EEA Resolution Authority to any such liabilities arising hereunder which may be payable to it by any party hereto that is an EEA Financial Institution; and

(b) the effects of any Bail-in Action on any such liability, including, if applicable:

(i) a reduction in full or in part or cancellation of any such liability;

(ii) a conversion of all, or a portion of, such liability into shares or other instruments of ownership in such EEA Financial Institution, its parent undertaking, or a bridge institution that may be issued to it or otherwise conferred on it, and that such shares or other instruments of ownership will be accepted by it in lieu of any rights with respect to any such liability under this Agreement or any other Loan Document; or

(iii) the variation of the terms of such liability in connection with the exercise of the write-down and conversion powers of any EEA Resolution Authority.

[REMAINDER OF PAGE INTENTIONALLY LEFT BLANK; SIGNATURE PAGES FOLLOW]

ACTIVE 213961984v.8

IN WITNESS WHEREOF, the parties hereto have caused this Agreement to be executed by their respective officers thereunto duly authorized, as of the date first above written.

ARIZONA PUBLIC SERVICE COMPANY

By: /s/ Lee R. Nickloy

Name: Lee R. Nickloy

Title: Vice President and Treasurer

Signature Page to

Arizona Public Service Company Term Loan Agreement


ADMINISTRATIVE AGENT:	TORONTO DOMINION (TEXAS) LLC, as Agent

By: /s/ Alice Mare

Name: Alice Mare

Title: Authorized Signatory

Signature Page to

Arizona Public Service Company Term Loan Agreement


LENDERS:	TD BANK, N.A., as a Lender

By: /s/ Vijay Prasad

Name: Vijay Prasad

Title: Senior Vice President

Signature Page to

Arizona Public Service Company Term Loan Agreement

CITIBANK, N.A., as a Lender

By: /s/ Hans Y. Lin

Name: Hans Y. Lin

Title: Senior Vice President

Signature Page to

Arizona Public Service Company Term Loan Agreement

THE BANK OF NEW YORK MELLON, as a Lender

By: /s/ Mark A. Rogers

Name: Mark A. Rogers

Title: Vice President

Signature Page to

Arizona Public Service Company Term Loan Agreement

SCHEDULE 1.01

COMMITMENTS AND RATABLE SHARES



Lender	Commitment		Ratable Share
TD Bank, N.A. Citibank, N.A. The Bank of New York Mellon	$42,000,000 $25,000,000 $33,000,000		42% 25% 33%
TOTAL		$100,000,000	100%

Signature Page to

Arizona Public Service Company Term Loan Agreement

SCHEDULE 4.01(j)

SUBSIDIARIES¹


1.	Bixco, Inc.


2.	Axiom Power Solutions, Inc.


3.	PWE Newco, Inc.

-------------------------------------------

¹The Borrower's three nuclear decommissioning trusts relating to PVNGS may also be deemed to be subsidiaries under a literal reading of the definition.

SCHEDULE 4.01(k)

EXISTING INDEBTEDNESS


1.	Commercial Paper.

SCHEDULE 8.02

CERTAIN ADDRESSES FOR NOTICES

BORROWER:

Arizona Public Service Company

400 North 5th Street

Mail Station 9040

Phoenix, AZ 85004

Attention: Treasurer

Telephone: (602) 250-3300

Telecopier: (602) 250-3902

Electronic lee.nickloy@pinnaclewest.com

AGENT:

Notices relating to Borrowing requests or Interest Election Requests:

Toronto Dominion (Texas) LLC
31 W. 52^nd Street

New York, NY 10019
Facsimile: (416) 982-5535

Telephone: (416) 982-3567
Attention: Vice President
Electronic: TDSAgencyAdmin@tdsecurities.com

Notices other than with respect to Borrowing requests or Interest Election Requests:

Toronto Dominion (Texas) LLC
31 W. 52^nd Street,

New York, NY 10019
Facsimile: (212) 827-7234

Telephone: (212) 827-7731
Attention: Director
Electronic: Michael.Hutchings@tdsecurities.com

With a copy to Administration Team:

Toronto Dominion (Texas) LLC
31 W. 52^nd Street,

New York, NY 10019
Facsimile: (416) 982-5535

Telephone: (416) 982-3567
Attention: Vice President
Electronic: TDSAgencyAdmin@tdsecurities.com

Exhibit

Exhibit 12.1

PINNACLE WEST CAPITAL CORPORATION

RATIO OF EARNINGS TO FIXED CHARGES

(dollars in thousands)



	Three Months Ended March 31,		Twelve Months Ended December 31,
	2016		2015		2014		2013		2012		2011
Earnings:
Income from continuing operations attributable to common shareholders	$	4,453	$	437,257	$	397,595	$	406,074	$	387,380	$	328,110
Income taxes	1,914		237,720		220,705		230,591		237,317		183,604
Fixed charges	53,072		202,465		208,226		206,089		219,437		246,462
Total earnings	$	59,439	$	877,442	$	826,526	$	842,754	$	844,134	$	758,176
Fixed Charges:
Interest expense	$	50,744	$	194,964	$	200,950	$	201,888	$	214,616	$	241,995
Estimated interest portion of annual rents	2,328		7,501		7,276		4,201		4,821		4,467
Total fixed charges	$	53,072	$	202,465	$	208,226	$	206,089	$	219,437	$	246,462
Ratio of Earnings to Fixed Charges (rounded down)	1.11		4.33		3.96		4.08		3.84		3.07

Exhibit

Exhibit 12.2

ARIZONA PUBLIC SERVICE COMPANY

RATIO OF EARNINGS TO FIXED CHARGES

(dollars in thousands)



	Three Months Ended March 31,		Twelve Months Ended December 31,
	2016		2015		2014		2013		2012		2011
Earnings:
Income from continuing operations attributable to common shareholders	$	7,253	$	450,274	$	421,219	$	424,969	$	395,497	$	336,249
Income taxes	4,035		245,841		237,360		245,095		244,396		192,542
Fixed charges	52,362		199,458		204,198		202,457		214,227		238,286
Total earnings	$	63,650	$	895,573	$	862,777	$	872,521	$	854,120	$	767,077
Fixed Charges:
Interest charges	$	48,896	$	187,499	$	193,119	$	194,616	$	205,533	$	229,326
Amortization of debt discount	1,139		4,793		4,168		4,046		4,215		4,616
Estimated interest portion of annual rents	2,327		7,166		6,911		3,795		4,479		4,344
Total fixed charges	$	52,362	$	199,458	$	204,198	$	202,457	$	214,227	$	238,286
Ratio of Earnings to Fixed Charges (rounded down)	1.21		4.49		4.22		4.30		3.98		3.21

Exhibit

Exhibit 12.3

PINNACLE WEST CAPITAL CORPORATION

RATIO OF EARNINGS TO COMBINED FIXED CHARGES AND PREFERRED

STOCK DIVIDEND REQUIREMENTS

(dollars in thousands)



	Three Months Ended March 31,		Twelve Months Ended December 31,
	2016		2015		2014		2013		2012		2011
Earnings:
Income from continuing operations attributable to common shareholders	$	4,453	$	437,257	$	397,595	$	406,074	$	387,380	$	328,110
Income taxes	1,914		237,720		220,705		230,591		237,317		183,604
Fixed charges	53,072		202,465		208,226		206,089		219,437		246,462
Total earnings	$	59,439	$	877,442	$	826,526	$	842,754	$	844,134	$	758,176
Fixed Charges:
Interest expense	$	50,744	$	194,964	$	200,950	$	201,888	$	214,616	$	241,995
Estimated interest portion of annual rents	2,328		7,501		7,276		4,201		4,821		4,467
Total fixed charges	$	53,072	$	202,465	$	208,226	$	206,089	$	219,437	$	246,462
Preferred Stock Dividend Requirements:
Income before income taxes attributable to common shareholders	$	6,367	$	674,977	$	618,300	$	636,665	$	624,697	$	511,714
Net income from continuing operations attributable to common shareholders	4,453		437,257		397,595		406,074		387,380		328,110
Ratio of income before income taxes to net income	1.43		1.54		1.56		1.57		1.61		1.56
Preferred stock dividends	—		—		—		—		—		—
Preferred stock dividend requirements — ratio (above) times preferred stock dividends	$	—	$	—	$	—	$	—	$	—	$	—
Fixed Charges and Preferred Stock Dividend Requirements:
Fixed charges	$	53,072	$	202,465	$	208,226	$	206,089	$	219,437	$	246,462
Preferred stock dividend requirements	—		—		—		—		—		—
Total	$	53,072	$	202,465	$	208,226	$	206,089	$	219,437	$	246,462
Ratio of Earnings to Fixed Charges (rounded down)	1.11		4.33		3.96		4.08		3.84		3.07

Exhibit

Exhibit 31.1

CERTIFICATION

I, Donald E. Brandt, certify that:


1.	I have reviewed this Quarterly Report on Form 10-Q of Pinnacle West Capital Corporation;


2.	Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;


3.	Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;


4.	The registrant’s other certifying officer and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:


a)	designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;


b)	designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;


c)	evaluated the effectiveness of the registrant’s disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and


d)	disclosed in this report any change in the registrant’s internal control over financial reporting that occurred during the registrant’s most recent fiscal quarter (the registrant’s fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant’s internal control over financial reporting; and


5.	The registrant’s other certifying officer and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant’s auditors and the audit committee of the registrant’s board of directors (or persons performing the equivalent functions):


a)	all significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant’s ability to record, process, summarize and report financial information; and


b)	any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant’s internal control over financial reporting.

Date: April 29, 2016



	/s/ Donald E. Brandt
	Donald E. Brandt
	Chairman, President and Chief Executive Officer

Exhibit

Exhibit 31.2

CERTIFICATION

I, James R. Hatfield, certify that:


1.	I have reviewed this Quarterly Report on Form 10-Q of Pinnacle West Capital Corporation;


2.	Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;


3.	Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;


4.	The registrant’s other certifying officer and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:


a)	designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;


b)	designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;


c)	evaluated the effectiveness of the registrant’s disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and


d)	disclosed in this report any change in the registrant’s internal control over financial reporting that occurred during the registrant’s most recent fiscal quarter (the registrant’s fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant’s internal control over financial reporting; and


5.	The registrant’s other certifying officer and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant’s auditors and the audit committee of the registrant’s board of directors (or persons performing the equivalent functions):


a)	all significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant’s ability to record, process, summarize and report financial information; and


b)	any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant’s internal control over financial reporting.

Date: April 29, 2016



	/s/ James R. Hatfield
	James R. Hatfield
	Executive Vice President and Chief Financial Officer

Exhibit

Exhibit 31.3

CERTIFICATION

I, Donald E. Brandt, certify that:


1.	I have reviewed this Quarterly Report on Form 10-Q of Arizona Public Service Company;


2.	Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;


3.	Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;


4.	The registrant’s other certifying officer and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:


a)	designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;


b)	designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;


c)	evaluated the effectiveness of the registrant’s disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and


d)	disclosed in this report any change in the registrant’s internal control over financial reporting that occurred during the registrant’s most recent fiscal quarter (the registrant’s fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant’s internal control over financial reporting; and


5.	The registrant’s other certifying officer and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant’s auditors and the audit committee of the registrant’s board of directors (or persons performing the equivalent functions):


a)	all significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant’s ability to record, process, summarize and report financial information; and


b)	any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant’s internal control over financial reporting.

Date: April 29, 2016



	/s/ Donald E. Brandt
	Donald E. Brandt
	Chairman, President and Chief Executive Officer

Exhibit

Exhibit 31.4

CERTIFICATION

I, James R. Hatfield, certify that:


1.	I have reviewed this Quarterly Report on Form 10-Q of Arizona Public Service Company;


2.	Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;


3.	Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;


4.	The registrant’s other certifying officer and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:


a)	designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;


b)	designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;


c)	evaluated the effectiveness of the registrant’s disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and


d)	disclosed in this report any change in the registrant’s internal control over financial reporting that occurred during the registrant’s most recent fiscal quarter (the registrant’s fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant’s internal control over financial reporting; and


5.	The registrant’s other certifying officer and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant’s auditors and the audit committee of the registrant’s board of directors (or persons performing the equivalent functions):


a)	all significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant’s ability to record, process, summarize and report financial information; and


b)	any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant’s internal control over financial reporting.

Date: April 29, 2016



	/s/ James R. Hatfield
	James R. Hatfield
	Executive Vice President and Chief Financial Officer

Exhibit

Exhibit 32.1

CERTIFICATION

CHIEF EXECUTIVE OFFICER

AND

CHIEF FINANCIAL OFFICER

PURSUANT TO 18 U.S.C. 1350,

AS ADOPTED PURSUANT TO

SECTION 906 OF THE SARBANES-OXLEY ACT OF 2002

I, Donald E. Brandt, certify, pursuant to 18 U.S.C. 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, that the Quarterly Report on Form 10-Q of Pinnacle West Capital Corporation for the quarter ended September 30, 2015 fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934 and that information contained in such Quarterly Report on Form 10-Q fairly presents, in all material respects, the financial condition and results of operations of Pinnacle West Capital Corporation.

Date: April 29, 2016



	/s/ Donald E. Brandt
	Donald E. Brandt
	Chairman, President and
	Chief Executive Officer

I, James R. Hatfield, certify, pursuant to 18 U.S.C. 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, that the Quarterly Report on Form 10-Q of Pinnacle West Capital Corporation for the quarter ended September 30, 2015 fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934 and that information contained in such Quarterly Report on Form 10-Q fairly presents, in all material respects, the financial condition and results of operations of Pinnacle West Capital Corporation.

Date: April 29, 2016



	/s/ James R. Hatfield
	James R. Hatfield
	Executive Vice President and
	Chief Financial Officer

Exhibit

Exhibit 32.2

CERTIFICATION

CHIEF EXECUTIVE OFFICER

AND

CHIEF FINANCIAL OFFICER

PURSUANT TO 18 U.S.C. 1350,

AS ADOPTED PURSUANT TO

SECTION 906 OF THE SARBANES-OXLEY ACT OF 2002

I, Donald E. Brandt, certify, pursuant to 18 U.S.C. 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, that the Quarterly Report on Form 10-Q of Arizona Public Service Company for the quarter ended September 30, 2015 fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934 and that information contained in such Quarterly Report on Form 10-Q fairly presents, in all material respects, the financial condition and results of operations of Arizona Public Service Company.

Date: April 29, 2016



	/s/ Donald E. Brandt
	Donald E. Brandt
	Chairman, President and
	Chief Executive Officer

I, James R. Hatfield, certify, pursuant to 18 U.S.C. 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, that the Quarterly Report on Form 10-Q of Arizona Public Service Company for the quarter ended September 30, 2015 fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934 and that information contained in such Quarterly Report on Form 10-Q fairly presents, in all material respects, the financial condition and results of operations of Arizona Public Service Company.

Date: April 29, 2016



	/s/ James R. Hatfield
	James R. Hatfield
	Executive Vice President and
	Chief Financial Officer

pnw-20160331.xml
Attachment: XBRL INSTANCE DOCUMENT

pnw-20160331.xsd
Attachment: XBRL TAXONOMY EXTENSION SCHEMA DOCUMENT

pnw-20160331_cal.xml
Attachment: XBRL TAXONOMY EXTENSION CALCULATION LINKBASE DOCUMENT

pnw-20160331_def.xml
Attachment: XBRL TAXONOMY EXTENSION DEFINITION LINKBASE DOCUMENT

pnw-20160331_lab.xml
Attachment: XBRL TAXONOMY EXTENSION LABEL LINKBASE DOCUMENT

pnw-20160331_pre.xml
Attachment: XBRL TAXONOMY EXTENSION PRESENTATION LINKBASE DOCUMENT

Document and Entity Information - shares	3 Months Ended
Document and Entity Information - shares	Mar. 31, 2016	Apr. 22, 2016
Entity Information [Line Items]
Entity Registrant Name	PINNACLE WEST CAPITAL CORP
Entity Central Index Key	0000764622
Document Type	10-Q
Document Period End Date	Mar. 31, 2016
Amendment Flag	false
Current Fiscal Year End Date	--12-31
Entity Current Reporting Status	Yes
Entity Filer Category	Large Accelerated Filer
Entity Common Stock, Shares Outstanding		111,139,995
Document Fiscal Year Focus	2016
Document Fiscal Period Focus	Q1
Arizona Public Service Company
Entity Information [Line Items]
Entity Registrant Name	ARIZONA PUBLIC SERVICE COMPANY
Entity Central Index Key	0000007286
Document Type	10-Q
Document Period End Date	Mar. 31, 2016
Amendment Flag	false
Current Fiscal Year End Date	--12-31
Entity Current Reporting Status	Yes
Entity Filer Category	Non-accelerated Filer
Entity Common Stock, Shares Outstanding		71,264,947
Document Fiscal Year Focus	2016
Document Fiscal Period Focus	Q1

CONDENSED CONSOLIDATED STATEMENTS OF INCOME (Unaudited) - USD ($) shares in Thousands, $ in Thousands	3 Months Ended
	Mar. 31, 2016	Mar. 31, 2015
OPERATING REVENUES	$ 677,167	$ 671,219
OPERATING EXPENSES
Fuel and purchased power	221,285	223,237
Operations and maintenance	243,195	214,944
Depreciation and amortization	119,476	120,949
Taxes other than income taxes	42,501	43,216
Other expenses	548	1,189
Total	627,005	603,535
OPERATING INCOME	50,162	67,684
OTHER INCOME (DEDUCTIONS)
Allowance for equity funds used during construction	10,516	9,224
Other income (Note 8)	117	235
Other expense (Note 8)	(4,038)	(4,286)
Total	6,595	5,173
INTEREST EXPENSE
Interest charges	50,744	48,399
Allowance for borrowed funds used during construction	(5,227)	(4,216)
Total	45,517	44,183
INCOME BEFORE INCOME TAXES	11,240	28,674
INCOME TAXES	1,914	7,947
NET INCOME	9,326	20,727
Less: Net income attributable to noncontrolling interests (Note 5)	4,873	4,605
NET INCOME ATTRIBUTABLE TO COMMON SHAREHOLDERS	$ 4,453	$ 16,122
WEIGHTED-AVERAGE COMMON SHARES OUTSTANDING
WEIGHTED-AVERAGE COMMON SHARES OUTSTANDING - BASIC (in shares)	111,296	110,916
WEIGHTED-AVERAGE COMMON SHARES OUTSTANDING - DILUTED (in shares)	111,847	111,377
EARNINGS PER WEIGHTED-AVERAGE COMMON SHARE OUTSTANDING
Net income attributable to common shareholders - basic (in dollars per share)	$ 0.04	$ 0.15
Net income attributable to common shareholders - diluted (in dollars per share)	$ 0.04	$ 0.14
Arizona Public Service Company
ELECTRIC OPERATING REVENUES	$ 676,632	$ 670,668
OPERATING EXPENSES
Fuel and purchased power	221,285	223,237
Operations and maintenance	238,711	209,947
Depreciation and amortization	119,446	120,926
Income taxes	5,850	12,239
Taxes other than income taxes	42,410	42,986
Total	627,702	609,335
OPERATING INCOME	48,930	61,333
OTHER INCOME (DEDUCTIONS)
Income taxes	1,815	2,151
Allowance for equity funds used during construction	10,516	9,224
Other income (Note 8)	610	639
Other expense (Note 8)	(4,750)	(5,354)
Total	8,191	6,660
INTEREST EXPENSE
Interest on long-term debt	46,819	45,428
Interest on short-term borrowings	2,077	1,174
Debt discount, premium and expense	1,139	1,134
Allowance for borrowed funds used during construction	(5,040)	(4,216)
Total	44,995	43,520
NET INCOME	12,126	24,473
Less: Net income attributable to noncontrolling interests (Note 5)	4,873	4,605
NET INCOME ATTRIBUTABLE TO COMMON SHAREHOLDERS	$ 7,253	$ 19,868

CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (Unaudited) - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2016	Mar. 31, 2015
NET INCOME	$ 9,326	$ 20,727
Derivative instruments:
Net unrealized gain (loss), net of tax benefit (expense)	(693)	(800)
Reclassification of net realized loss, net of tax benefit	1,141	1,976
Pension and other postretirement benefits activity, net of tax benefit (expense)	530	583
Total other comprehensive income	978	1,759
COMPREHENSIVE INCOME	10,304	22,486
Less: Comprehensive income attributable to noncontrolling interests	4,873	4,605
COMPREHENSIVE INCOME ATTRIBUTABLE TO COMMON SHAREHOLDERS	5,431	17,881
Arizona Public Service Company
NET INCOME	12,126	24,473
Derivative instruments:
Net unrealized gain (loss), net of tax benefit (expense)	(693)	(800)
Reclassification of net realized loss, net of tax benefit	1,141	1,976
Pension and other postretirement benefits activity, net of tax benefit (expense)	611	681
Total other comprehensive income	1,059	1,857
COMPREHENSIVE INCOME	13,185	26,330
Less: Comprehensive income attributable to noncontrolling interests	4,873	4,605
COMPREHENSIVE INCOME ATTRIBUTABLE TO COMMON SHAREHOLDERS	$ 8,312	$ 21,725

CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (Unaudited) (Parenthetical) - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2016	Mar. 31, 2015
Net unrealized loss, tax expense	$ 546	$ 473
Reclassification of net realized loss, tax (expense) benefit	(200)	367
Pension and other postretirement benefits activity, tax expense	645	867
Arizona Public Service Company
Net unrealized loss, tax expense	546	473
Reclassification of net realized loss, tax (expense) benefit	(200)	367
Pension and other postretirement benefits activity, tax expense	$ 558	$ 769

CONDENSED CONSOLIDATED BALANCE SHEETS (Unaudited) - USD ($) $ in Thousands	Mar. 31, 2016	Dec. 31, 2015
CURRENT ASSETS
Cash and cash equivalents	$ 14,484	$ 39,488
Customer and other receivables	215,808	274,691
Accrued unbilled revenues	89,795	96,240
Allowance for doubtful accounts	(2,427)	(3,125)
Materials and supplies (at average cost)	234,179	234,234
Fossil fuel (at average cost)	44,227	45,697
Income tax receivable	4,637	589
Assets from risk management activities (Note 6)	16,089	15,905
Regulatory assets (Note 3)	168,753	149,555
Other current assets	40,480	37,242
Total current assets	826,025	890,516
INVESTMENTS AND OTHER ASSETS
Assets from risk management activities (Note 6)	8,612	12,106
Nuclear decommissioning trust (Note 11)	751,954	735,196
Other assets	52,679	52,518
Total investments and other assets	813,245	799,820
PROPERTY, PLANT AND EQUIPMENT
Plant in service and held for future use	16,285,916	16,222,232
Accumulated depreciation and amortization	(5,670,884)	(5,594,094)
Net	10,615,032	10,628,138
Construction work in progress	1,038,046	816,307
Palo Verde sale leaseback, net of accumulated depreciation (Note 5)	116,418	117,385
Intangible assets, net of accumulated amortization	116,014	123,975
Nuclear fuel, net of accumulated amortization	138,424	123,139
Total property, plant and equipment	12,023,934	11,808,944
DEFERRED DEBITS
Regulatory assets (Note 3)	1,203,474	1,214,146
Assets for other postretirement benefits (Note 4)	190,458	185,997
Other	127,965	128,835
Total deferred debits	1,521,897	1,528,978
TOTAL ASSETS	15,185,101	15,028,258
CURRENT LIABILITIES
Accounts payable	234,946	297,480
Accrued taxes	181,889	138,600
Accrued interest	44,489	56,305
Common dividends payable	0	69,363
Short-term borrowings (Note 2)	261,800	0
Current maturities of long-term debt (Note 2)	357,580	357,580
Customer deposits	78,825	73,073
Liabilities from risk management activities (Note 6)	93,283	77,716
Liabilities for asset retirements	17,217	28,573
Deferred fuel and purchased power regulatory liability (Note 3)	13,083	9,688
Other regulatory liabilities (Note 3)	122,471	136,078
Other current liabilities	180,319	197,861
Total current liabilities	1,585,902	1,442,317
LONG-TERM DEBT LESS CURRENT MATURITIES (Note 2)	3,463,032	3,462,391
DEFERRED CREDITS AND OTHER
Deferred income taxes	2,726,220	2,723,425
Regulatory liabilities (Note 3)	1,009,418	994,152
Liabilities for asset retirements	429,626	415,003
Liabilities for pension benefits (Note 4)	441,605	480,998
Liabilities from risk management activities (Note 6)	85,603	89,973
Customer advances	110,056	115,609
Coal mine reclamation	202,069	201,984
Deferred investment tax credit	186,966	187,080
Unrecognized tax benefits	9,631	9,524
Other	194,560	186,345
Total deferred credits and other	$ 5,395,754	$ 5,404,093
COMMITMENTS AND CONTINGENCIES (SEE NOTES)
EQUITY
Common stock, no par value; authorized 150,000,000 shares, 111,147,524 and 111,095,402 issued at respective dates	$ 2,547,065	$ 2,541,668
Treasury stock at cost; 7,936 and 115,030 shares at respective dates	(542)	(5,806)
Total common stock	2,546,523	2,535,862
Retained earnings	2,097,246	2,092,803
Accumulated other comprehensive loss:
Pension and other postretirement benefits	(37,063)	(37,593)
Derivative instruments	(6,707)	(7,155)
Total accumulated other comprehensive loss	(43,770)	(44,748)
Total shareholders’ equity	4,599,999	4,583,917
Noncontrolling interests (Note 5)	140,414	135,540
Total equity	4,740,413	4,719,457
TOTAL LIABILITIES AND EQUITY	15,185,101	15,028,258
Arizona Public Service Company
CURRENT ASSETS
Cash and cash equivalents	4,904	22,056
Customer and other receivables	215,351	274,428
Accrued unbilled revenues	89,795	96,240
Allowance for doubtful accounts	(2,427)	(3,125)
Materials and supplies (at average cost)	234,179	234,234
Fossil fuel (at average cost)	44,227	45,697
Assets from risk management activities (Note 6)	16,089	15,905
Regulatory assets (Note 3)	168,753	149,555
Other current assets	39,043	35,765
Total current assets	809,914	870,755
INVESTMENTS AND OTHER ASSETS
Assets from risk management activities (Note 6)	8,612	12,106
Nuclear decommissioning trust (Note 11)	751,954	735,196
Other assets	34,927	34,455
Total investments and other assets	795,493	781,757
PROPERTY, PLANT AND EQUIPMENT
Plant in service and held for future use	16,282,405	16,218,724
Accumulated depreciation and amortization	(5,667,713)	(5,590,937)
Net	10,614,692	10,627,787
Construction work in progress	1,025,868	812,845
Palo Verde sale leaseback, net of accumulated depreciation (Note 5)	116,418	117,385
Intangible assets, net of accumulated amortization	115,859	123,820
Nuclear fuel, net of accumulated amortization	138,424	123,139
Total property, plant and equipment	12,011,261	11,804,976
DEFERRED DEBITS
Regulatory assets (Note 3)	1,203,474	1,214,146
Assets for other postretirement benefits (Note 4)	187,069	182,625
Other	127,086	127,923
Total deferred debits	1,517,629	1,524,694
TOTAL ASSETS	15,134,297	14,982,182
CURRENT LIABILITIES
Accounts payable	232,484	291,574
Accrued taxes	183,272	144,488
Accrued interest	44,224	56,003
Common dividends payable	0	69,400
Short-term borrowings (Note 2)	261,800	0
Current maturities of long-term debt (Note 2)	357,580	357,580
Customer deposits	78,825	73,073
Liabilities from risk management activities (Note 6)	93,283	77,716
Liabilities for asset retirements	13,083	9,688
Deferred fuel and purchased power regulatory liability (Note 3)	17,217	28,573
Other regulatory liabilities (Note 3)	122,471	136,078
Other current liabilities	172,249	180,535
Total current liabilities	1,576,488	1,424,708
DEFERRED CREDITS AND OTHER
Deferred income taxes	2,767,124	2,764,489
Regulatory liabilities (Note 3)	1,009,418	994,152
Liabilities for asset retirements	429,626	415,003
Liabilities for pension benefits (Note 4)	420,110	459,065
Liabilities from risk management activities (Note 6)	85,603	89,973
Customer advances	110,056	115,609
Coal mine reclamation	202,069	201,984
Deferred investment tax credit	186,966	187,080
Unrecognized tax benefits	35,356	35,251
Other	145,469	142,683
Total deferred credits and other	$ 5,391,797	$ 5,405,289
COMMITMENTS AND CONTINGENCIES (SEE NOTES)
EQUITY
Total common stock	$ 178,162	$ 178,162
Additional paid-in capital	2,379,696	2,379,696
Retained earnings	2,155,746	2,148,493
Accumulated other comprehensive loss:
Pension and other postretirement benefits	(19,331)	(19,942)
Derivative instruments	(6,707)	(7,155)
Total shareholders’ equity	4,687,566	4,679,254
Noncontrolling interests (Note 5)	140,414	135,540
Total equity	4,827,980	4,814,794
Long-term debt less current maturities (Note 2)	3,338,032	3,337,391
Total capitalization	8,166,012	8,152,185
TOTAL LIABILITIES AND EQUITY	$ 15,134,297	$ 14,982,182

CONDENSED CONSOLIDATED BALANCE SHEETS (Unaudited) (Parenthetical) - $ / shares	Mar. 31, 2016	Dec. 31, 2015
Stockholders' Equity, Including Portion Attributable to Noncontrolling Interest [Abstract]
Common stock, par value (in dollars per share)
Common stock, authorized shares	150,000,000	150,000,000
Common stock, issued shares	111,147,524	111,095,402
Treasury stock at cost, shares	7,936	115,030

CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS (Unaudited) - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2016	Mar. 31, 2015
CASH FLOWS FROM OPERATING ACTIVITIES
NET INCOME	$ 9,326	$ 20,727
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation and amortization including nuclear fuel	140,759	141,494
Deferred fuel and purchased power	1,007	17,671
Deferred fuel and purchased power amortization	2,388	5,614
Allowance for equity funds used during construction	(10,516)	(9,224)
Deferred income taxes	3,468	6,978
Deferred investment tax credit	(114)	(294)
Change in derivative instruments fair value	(111)	(104)
Changes in current assets and liabilities:
Customer and other receivables	47,282	39,174
Accrued unbilled revenues	6,445	6,133
Materials, supplies and fossil fuel	1,525	(9,995)
Income tax receivable	(4,048)	(219)
Other current assets	(8,131)	(9,631)
Accounts payable	(38,443)	(35,673)
Accrued taxes	43,289	48,111
Other current liabilities	(38,040)	(56,747)
Change in margin and collateral accounts — assets	681	(276)
Change in margin and collateral accounts — liabilities	410	(13,420)
Change in other long-term assets	(17,504)	(13,126)
Change in other long-term liabilities	4,536	6,955
Net cash flow provided by operating activities	144,209	144,148
CASH FLOWS FROM INVESTING ACTIVITIES
Capital expenditures	(378,500)	(251,041)
Contributions in aid of construction	12,464	27,222
Allowance for borrowed funds used during construction	(5,227)	(4,216)
Proceeds from nuclear decommissioning trust sales	141,809	115,282
Investment in nuclear decommissioning trust	(142,379)	(119,594)
Other	(472)	(470)
Net cash flow used for investing activities	(372,305)	(232,817)
CASH FLOWS FROM FINANCING ACTIVITIES
Issuance of long-term debt	0	250,000
Short-term borrowings and payments — net	261,800	(102,900)
Dividends paid on common stock	(67,611)	(64,061)
Common stock equity issuance - net of purchases	8,902	9,690
Other	1	0
Net cash flow provided by financing activities	203,092	92,729
NET INCREASE (DECREASE) IN CASH AND CASH EQUIVALENTS	(25,004)	4,060
CASH AND CASH EQUIVALENTS AT BEGINNING OF PERIOD	39,488	7,604
CASH AND CASH EQUIVALENTS AT END OF PERIOD	14,484	11,664
Cash paid during the period for:
Income taxes, net of refunds	2,502	1,832
Interest, net of amounts capitalized	56,139	53,555
Significant non-cash investing and financing activities:
Accrued capital expenditures	59,707	56,165
Arizona Public Service Company
CASH FLOWS FROM OPERATING ACTIVITIES
NET INCOME	12,126	24,473
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation and amortization including nuclear fuel	140,729	141,471
Deferred fuel and purchased power	1,007	17,671
Deferred fuel and purchased power amortization	2,388	5,614
Allowance for equity funds used during construction	(10,516)	(9,224)
Deferred income taxes	3,394	2,427
Deferred investment tax credit	(114)	(294)
Change in derivative instruments fair value	(111)	(104)
Changes in current assets and liabilities:
Customer and other receivables	47,575	43,070
Accrued unbilled revenues	6,445	6,133
Materials, supplies and fossil fuel	1,525	(9,995)
Other current assets	(8,172)	(9,116)
Accounts payable	(34,999)	(35,604)
Accrued taxes	38,784	59,057
Other current liabilities	(28,748)	(65,290)
Change in margin and collateral accounts — assets	681	(276)
Change in margin and collateral accounts — liabilities	410	(13,421)
Change in other long-term assets	(17,375)	(16,253)
Change in other long-term liabilities	(1,102)	12,635
Net cash flow provided by operating activities	153,927	152,974
CASH FLOWS FROM INVESTING ACTIVITIES
Capital expenditures	(369,861)	(250,930)
Contributions in aid of construction	12,464	27,222
Allowance for borrowed funds used during construction	(5,040)	(4,216)
Proceeds from nuclear decommissioning trust sales	141,809	115,282
Investment in nuclear decommissioning trust	(142,379)	(119,594)
Other	(472)	(470)
Net cash flow used for investing activities	(363,479)	(232,706)
CASH FLOWS FROM FINANCING ACTIVITIES
Issuance of long-term debt	0	250,000
Short-term borrowings and payments — net	261,800	(102,900)
Dividends paid on common stock	(69,400)	(65,800)
Net cash flow provided by financing activities	192,400	81,300
NET INCREASE (DECREASE) IN CASH AND CASH EQUIVALENTS	(17,152)	1,568
CASH AND CASH EQUIVALENTS AT BEGINNING OF PERIOD	22,056	4,515
CASH AND CASH EQUIVALENTS AT END OF PERIOD	4,904	6,083
Cash paid during the period for:
Income taxes, net of refunds	8,772	184
Interest, net of amounts capitalized	55,580	52,825
Significant non-cash investing and financing activities:
Accrued capital expenditures	$ 59,707	$ 56,165

CONDENSED CONSOLIDATED STATEMENTS OF CHANGES IN EQUITY (Unaudited) - USD ($)
$ in Thousands

Total

Common Stock

Treasury Stock

Retained Earnings

Accumulated Other Comprehensive Income (Loss)

Noncontrolling Interests

Arizona Public Service Company

Common Stock

Arizona Public Service Company

Additional Paid-In Capital

Arizona Public Service Company

Retained Earnings

Arizona Public Service Company

Accumulated Other Comprehensive Income (Loss)

Arizona Public Service Company

Noncontrolling Interests

Beginning balance (in shares) at Dec. 31, 2014

110,649,762

78,400

71,264,947

Balance at end of period at Dec. 31, 2014

$ 4,519,102

$ 2,512,970

$ (3,401)

$ 1,926,065

$ (68,141)

$ 151,609

$ 4,629,852

$ 178,162

$ 2,379,696

$ 1,968,718

$ (48,333)

$ 151,609

Increase (Decrease) in Shareholders' Equity

Net income

20,727

16,122

4,605

24,473

19,868

4,605

Other comprehensive income

1,759

1,857

Other

Issuance of common stock (in shares)

159,730

Issuance of common stock

10,277

$ 10,277

Purchase of treasury stock (in shares)

^[1]

(93,280)

Purchase of treasury stock

^[1]

(6,095)

$ (6,095)

Reissuance of treasury stock for stock-based compensation and other (in shares)

109,896

Reissuance of treasury stock for stock-based compensation and other

7,237

$ 7,230

Ending balance (in shares) at Mar. 31, 2015

110,809,492

61,784

71,264,947

Balance at beginning of period at Mar. 31, 2015

$ 4,553,007

$ 2,523,247

$ (2,266)

1,942,194

(66,382)

156,214

4,656,183

$ 178,162

2,379,696

1,988,587

(46,476)

156,214

Beginning balance (in shares) at Dec. 31, 2015

111,095,402

115,030

71,264,947

Balance at end of period at Dec. 31, 2015

$ 4,719,457

$ 2,541,668

$ (5,806)

2,092,803

(44,748)

135,540

4,814,794

$ 178,162

2,379,696

2,148,493

(27,097)

135,540

Increase (Decrease) in Shareholders' Equity

Net income

9,326

4,453

4,873

12,126

7,253

4,873

Other comprehensive income

978

1,059

Other

Issuance of common stock (in shares)

52,122

Issuance of common stock

5,397

$ 5,397

Purchase of treasury stock (in shares)

^[1]

(71,962)

Purchase of treasury stock

^[1]

(4,880)

$ (4,880)

Reissuance of treasury stock for stock-based compensation and other (in shares)

179,056

Reissuance of treasury stock for stock-based compensation and other

$ 10,135

$ 10,144

(10)

Ending balance (in shares) at Mar. 31, 2016

111,147,524

7,936

71,264,947

Balance at beginning of period at Mar. 31, 2016

$ 4,740,413

$ 2,547,065

$ (542)

$ 2,097,246

$ (43,770)

$ 140,414

$ 4,827,980

$ 178,162

$ 2,379,696

$ 2,155,746

$ (26,038)

$ 140,414

[1]	Primarily represents shares of common stock withheld from certain stock awards for tax purposes.

Consolidation and Nature of Operations

3 Months Ended

Mar. 31, 2016

Organization, Consolidation and Presentation of Financial Statements [Abstract]

Consolidation and Nature of Operations

Supplemental Cash Flow Information

The following table summarizes supplemental Pinnacle West cash flow information (dollars in thousands):



	Three Months Ended March 31,
	2016		2015
Cash paid during the period for:
Income taxes, net of refunds	$	2,502	$	1,832
Interest, net of amounts capitalized	56,139		53,555
Significant non-cash investing and financing activities:
Accrued capital expenditures	$	59,707	$	56,165

Long-Term Debt and Liquidity Matters

3 Months Ended

Mar. 31, 2016

Debt Disclosure [Abstract]

Long-Term Debt and Liquidity Matters

Pinnacle West

APS

During the first quarter of 2016, APS increased its commercial paper program from $250 million to $500 million.

See "Financial Assurances" in Note 7 for a discussion of APS’s separate outstanding letters of credit.

Debt Fair Value



	As of March 31, 2016				As of December 31, 2015
	Carrying Amount		Fair Value		Carrying Amount		Fair Value
Pinnacle West	$	125,000	$	125,000	$	125,000	$	125,000
APS	3,695,612		4,136,022		3,694,971		3,981,367
Total	$	3,820,612	$	4,261,022	$	3,819,971	$	4,106,367

Debt Provisions

An existing ACC order requires APS to maintain a common equity ratio of at least 40%. As defined in the ACC order, the common equity ratio is total shareholder equity divided by the sum of total shareholder equity and long-term debt, including current maturities of long-term debt. At March 31, 2016, APS was in compliance with this common equity ratio requirement. Its total shareholder equity was approximately $4.7 billion, and total capitalization was approximately $8.6 billion. APS would be prohibited from paying dividends if the payment would reduce its total shareholder equity below approximately $3.4 billion, assuming APS’s total capitalization remains the same.

Regulatory Matters

3 Months Ended

Mar. 31, 2016

Regulated Operations [Abstract]

Regulatory Matters

Retail Rate Case Filings with the Arizona Corporation Commission

Upcoming Rate Case Filing

Prior Rate Case Filing

Settlement Agreement

Other key provisions of the 2012 Settlement Agreement include the following:


•	An authorized return on common equity of 10.0%;


•	A capital structure comprised of 46.1% debt and 53.9% common equity;


•	A test year ended December 31, 2010, adjusted to include plant that is in service as of March 31, 2012;


•	Deferral for future recovery or refund of property taxes above or below a specified 2010 test year level caused by changes to the Arizona property tax rate as follows:


•	Deferral of increases in property taxes of 25% in 2012, 50% in 2013 and 75% for 2014 and subsequent years if Arizona property tax rates increase; and


•	Deferral of 100% in all years if Arizona property tax rates decrease;


•	A procedure to allow APS to request rate adjustments prior to its next general rate case related to APS’s acquisition of additional interests in Units 4 and 5 and the related closure of Units 1-3 of the Four Corners Power Plant ("Four Corners") (APS made its filing under this provision on December 30, 2013, see "Four Corners" below);


•	Implementation of a Lost Fixed Cost Recovery ("LFCR") rate mechanism to support energy efficiency and distributed renewable generation;


•	Modifications to the Environmental Improvement Surcharge ("EIS") to allow for the recovery of carrying costs for capital expenditures associated with government-mandated environmental controls, subject to an existing cents per kWh cap on cost recovery that could produce up to approximately $5 million in revenues annually;


•	Modifications to the Power Supply Adjustor ("PSA"), including the elimination of the 90/10 sharing provision;


•	A limitation on the use of the RES surcharge and the Demand Side Management Adjustor Charge ("DSMAC") to recoup capital expenditures not required under the terms of APS’s 2009 retail rate case settlement agreement (the "2009 Settlement Agreement");


•	Modification of the Transmission Cost Adjustor ("TCA") to streamline the process for future transmission-related rate changes; and


•	Implementation of various changes to rate schedules, including the adoption of an experimental "buy-through" rate that could allow certain large commercial and industrial customers to select alternative sources of generation to be supplied by APS.

Cost Recovery Mechanisms

APS has received regulatory decisions that allow for more timely recovery of certain costs through the following recovery mechanisms.

On July 1, 2015, APS filed its 2016 RES implementation plan and proposed a RES budget of approximately $148 million. On January 12, 2016, the ACC approved APS’s plan and requested budget.



	Three Months Ended March 31,
	2016			2015
Beginning balance	$	(9,688	)	$	6,925
Deferred fuel and purchased power costs — current period	(1,007		)	(17,671		)
Amounts charged to customers	(2,388		)	(5,614		)
Ending balance	$	(13,083	)	$	(16,360	)

Net Metering

Appellate Review of Third-Party Regulatory Decision ("System Improvement Benefits" or "SIB")

Four Corners

As part of APS’s acquisition of SCE’s interest in Units 4 and 5, APS and SCE agreed, via a "Transmission Termination Agreement" that, upon closing of the acquisition, the companies would terminate an existing transmission agreement ("Transmission Agreement") between the parties that provides transmission capacity on a system (the "Arizona Transmission System") for SCE to transmit its portion of the output from Four Corners to California. APS previously submitted a request to FERC related to this termination, which resulted in a FERC order denying rate recovery of $40 million that APS agreed to pay SCE associated with the termination. On December 22, 2015, APS and SCE agreed to terminate the Transmission Termination Agreement and allow for the Transmission Agreement to expire according to its terms, which includes settling obligations in accordance with the terms of the Transmission Agreement. APS established a regulatory asset of $12 million in 2015 in connection with the payment required under the terms of the Transmission Agreement, which it expects to recover through its FERC-jurisdictional rates.

Cholla

Regulatory Assets and Liabilities

The detail of regulatory assets is as follows (dollars in thousands):



	Amortization Through	March 31, 2016				December 31, 2015
	Amortization Through	Current		Non-Current		Current		Non-Current
Pension	(a)	$	—	$	610,569	$	—	$	619,223
Retired power plant costs	2033	9,913		125,037		9,913		127,518
Income taxes — allowance for funds used during construction ("AFUDC") equity	2046	5,419		132,149		5,495		133,712
Deferred fuel and purchased power — mark-to-market (Note 6)	2019	86,160		69,708		71,852		69,697
Four Corners cost deferral (b)	2024	6,689		61,910		6,689		63,582
Income taxes — investment tax credit basis adjustment	2045	1,852		48,347		1,766		48,462
Lost fixed cost recovery (b)	2017	48,702		—		45,507		—
Palo Verde VIEs (Note 5)	2046	—		18,311		—		18,143
Deferred compensation	2036	—		35,871		—		34,751
Deferred property taxes	(c)	—		56,589		—		50,453
Loss on reacquired debt	2034	1,515		15,996		1,515		16,375
Tax expense of Medicare subsidy	2024	1,512		12,073		1,520		12,163
Transmission vegetation management	2016	2,272		—		4,543		—
Mead-Phoenix transmission line CIAC	2050	332		10,957		332		11,040
Transmission cost adjustor (b)	2018	3,969		462		—		2,942
Coal reclamation	2026	418		5,495		418		6,085
Other	Various	—		—		5		—
Total regulatory assets (d)		$	168,753	$	1,203,474	$	149,555	$	1,214,146


(a)	This asset represents the future recovery of pension benefit obligations through retail rates. If these costs are disallowed by the ACC, this regulatory asset would be charged to Other Comprehensive Income ("OCI") and result in lower future revenues. See Note 4 for further discussion.


(b)	See "Cost Recovery Mechanisms" discussion above.


(c)	Per the provision of the 2012 Settlement Agreement.


(d)	There are no regulatory assets for which the ACC has allowed recovery of costs, but not allowed a return by exclusion from rate base. FERC rates are set using a formula rate as described in "Transmission Rates, Transmission Cost Adjustor and Other Transmission Matters."

The detail of regulatory liabilities is as follows (dollars in thousands):



	Amortization Through	March 31, 2016				December 31, 2015
	Amortization Through	Current		Non-Current		Current		Non-Current
Asset retirement obligations	2057	$	—	$	289,485	$	—	$	277,554
Removal costs	(a)	32,473		244,724		39,746		240,367
Other postretirement benefits	(d)	34,100		171,029		34,100		179,521
Income taxes — deferred investment tax credit	2045	3,774		96,940		3,604		97,175
Income taxes — change in rates	2046	1,771		71,756		1,113		72,454
Spent nuclear fuel	2047	31		71,235		3,051		67,437
Renewable energy standard (b)	2017	41,518		3,274		43,773		4,365
Demand side management (b)	2017	6,628		19,115		6,079		19,115
Sundance maintenance	2030	—		14,080		—		13,678
Deferred fuel and purchased power (b) (c)	2017	13,083		—		9,688		—
Deferred gains on utility property	2019	2,062		5,501		2,062		6,001
Four Corners coal reclamation	2031	—		14,725		—		8,920
Other	Various	114		7,554		2,550		7,565
Total regulatory liabilities		$	135,554	$	1,009,418	$	145,766	$	994,152


(a)	In accordance with regulatory accounting guidance, APS accrues for removal costs for its regulated assets, even if there is no legal obligation for removal.


(b)	See "Cost Recovery Mechanisms" discussion above.


(c)	Subject to a carrying charge.


(d)	See Note 4.

Retirement Plans and Other Postretirement Benefits

3 Months Ended

Mar. 31, 2016

Compensation and Retirement Disclosure [Abstract]

Retirement Plans and Other Postretirement Benefits



	Pension Benefits						Other Benefits
	Three Months Ended March 31,						Three Months Ended March 31,
	2016			2015			2016			2015
Service cost — benefits earned during the period	$	14,266		$	15,824		$	3,937		$	4,346
Interest cost on benefit obligation	32,945			31,189			7,341			7,184
Expected return on plan assets	(43,792		)	(45,149		)	(9,122		)	(9,147		)
Amortization of:
Prior service cost	132			149			(9,471		)	(9,492		)
Net actuarial loss	9,731			7,761			946			1,561
Net periodic benefit cost	$	13,282		$	9,774		$	(6,369	)	$	(5,548	)
Portion of cost charged to expense	$	6,519		$	5,987		$	(3,126	)	$	(1,788	)

Contributions

Palo Verde Sale Leaseback Variable Interest Entities

3 Months Ended

Mar. 31, 2016

Variable Interest Entities [Abstract]

Palo Verde Sale Leaseback Variable Interest Entities

Our Condensed Consolidated Balance Sheets at March 31, 2016 and December 31, 2015 include the following amounts relating to the VIEs (in thousands):



	March 31, 2016		December 31, 2015
Palo Verde sale leaseback property plant and equipment, net of accumulated depreciation	$	116,418	$	117,385
Equity — Noncontrolling interests	140,414		135,540

For regulatory ratemaking purposes, the agreements continue to be treated as operating leases and, as a result, we have recorded a regulatory asset relating to the arrangements.

Derivative Accounting

3 Months Ended

Mar. 31, 2016

Derivative Instruments and Hedging Activities Disclosure [Abstract]

Derivative Accounting

As of March 31, 2016, we had the following outstanding gross notional volume of derivatives, which represent both purchases and sales (does not reflect net position):



Commodity	Quantity
Power	2,239	GWh
Gas	179	Billion cubic feet

Gains and Losses from Derivative Instruments



	Financial Statement Location	Three Months Ended March 31,
Commodity Contracts	Financial Statement Location	2016			2015
Loss recognized in OCI on derivative instruments (effective portion)	OCI — derivative instruments	$	(147	)	$	(327	)
Loss reclassified from accumulated OCI into income (effective portion realized) (a)	Fuel and purchased power (b)	(941		)	(2,343		)


(a)	During the three months ended March 31, 2016 and 2015, we had no losses reclassified from accumulated OCI to earnings related to discontinued cash flow hedges.


(b)	Amounts are before the effect of PSA deferrals.

During the next twelve months, we estimate that a net loss of $4 million before income taxes will be reclassified from accumulated OCI as an offset to the effect of market price changes for the related hedged transactions. In accordance with the PSA, most of these amounts will be recorded as either a regulatory asset or liability and have no immediate effect on earnings.



	Financial Statement Location	Three Months Ended March 31,
Commodity Contracts	Financial Statement Location	2016			2015
Net loss recognized in income	Operating revenues	$	(102	)	$	(48	)
Net loss recognized in income	Fuel and purchased power (a)	(30,936		)	(44,803		)
Total		$	(31,038	)	$	(44,851	)


(a)	Amounts are before the effect of PSA deferrals.

Derivative Instruments in the Condensed Consolidated Balance Sheets



As of March 31, 2016: (dollars in thousands)	Gross Recognized Derivatives (a)			Amounts Offset (b)			Net Recognized Derivatives			Other (c)			Amount Reported on Balance Sheet
Current assets	$	25,365		$	(9,268	)	$	16,097		$	(8	)	$	16,089
Investments and other assets	11,248			(2,636		)	8,612			—			8,612
Total assets	36,613			(11,904		)	24,709			(8		)	24,701

Current liabilities	(115,822		)	26,868			(88,954		)	(4,329		)	(93,283		)
Deferred credits and other	(88,239		)	2,636			(85,603		)	—			(85,603		)
Total liabilities	(204,061		)	29,504			(174,557		)	(4,329		)	(178,886		)
Total	$	(167,448	)	$	17,600		$	(149,848	)	$	(4,337	)	$	(154,185	)


(a)	All of our gross recognized derivative instruments were subject to master netting arrangements.


(b)	Includes cash collateral provided to counterparties of $17,600.


(c)	Represents cash collateral and cash margin that is not subject to offsetting. Amounts relate to non-derivative instruments, derivatives qualifying for scope exceptions, or collateral and margin posted in excess of the recognized derivative instrument. Includes cash collateral received from counterparties of $4,329, and cash margin provided to counterparties of $(8).



As of December 31, 2015: (dollars in thousands)	Gross Recognized Derivatives (a)			Amounts Offset (b)			Net Recognized Derivatives			Other (c)			Amount Reported on Balance Sheet
Current assets	$	37,396		$	(22,163	)	$	15,233		$	672		$	15,905
Investments and other assets	15,960			(3,854		)	12,106			—			12,106
Total assets	53,356			(26,017		)	27,339			672			28,011

Current liabilities	(113,560		)	40,223			(73,337		)	(4,379		)	(77,716		)
Deferred credits and other	(93,827		)	3,854			(89,973		)	—			(89,973		)
Total liabilities	(207,387		)	44,077			(163,310		)	(4,379		)	(167,689		)
Total	$	(154,031	)	$	18,060		$	(135,971	)	$	(3,707	)	$	(139,678	)


(a)	All of our gross recognized derivative instruments were subject to master netting arrangements.


(b)	Includes cash collateral provided to counterparties of $18,060.


(c)	Represents cash collateral and cash margin that is not subject to offsetting. Amounts relate to non-derivative instruments, derivatives qualifying for scope exceptions, or collateral and margin posted in excess of the recognized derivative instrument. Includes cash collateral received from counterparties of $4,379, and cash margin provided to counterparties of $672.

Credit Risk and Credit Related Contingent Features

We are exposed to losses in the event of nonperformance or nonpayment by counterparties. We have risk management contracts with many counterparties, including one counterparty for which our exposure represents approximately 87% of Pinnacle West’s $25 million of risk management assets as of March 31, 2016. This exposure relates to a long-term traditional wholesale contract with a counterparty that has a high credit quality. Our risk management process assesses and monitors the financial exposure of all counterparties. Despite the fact that the great majority of trading counterparties’ debt is rated as investment grade by the credit rating agencies, there is still a possibility that one or more of these companies could default, resulting in a material impact on consolidated earnings for a given period. Counterparties in the portfolio consist principally of financial institutions, major energy companies, municipalities and local distribution companies. We maintain credit policies that we believe minimize overall credit risk to within acceptable limits. Determination of the credit quality of our counterparties is based upon a number of factors, including credit ratings and our evaluation of their financial condition. To manage credit risk, we employ collateral requirements and standardized agreements that allow for the netting of positive and negative exposures associated with a single counterparty. Valuation adjustments are established representing our estimated credit losses on our overall exposure to counterparties.

The following table provides information about our derivative instruments that have credit-risk-related contingent features at March 31, 2016 (dollars in thousands):



	March 31, 2016
Aggregate fair value of derivative instruments in a net liability position	$	204,061
Cash collateral posted	17,600
Additional cash collateral in the event credit-risk-related contingent features were fully triggered (a)	133,688


(a)	This amount is after counterparty netting and includes those contracts which qualify for scope exceptions, which are excluded from the derivative details above.

Commitments and Contingencies	3 Months Ended
Commitments and Contingencies	Mar. 31, 2016
Commitments and Contingencies Disclosure [Abstract]
Commitments and Contingencies	Commitments and Contingencies Palo Verde Nuclear Generating Station Spent Nuclear Fuel and Waste Disposal On December 19, 2012, APS, acting on behalf of itself and the participant owners of Palo Verde, filed a second breach of contract lawsuit against the United States Department of Energy ("DOE") in the United States Court of Federal Claims ("Court of Federal Claims"). The lawsuit sought to recover damages incurred due to DOE’s breach of the Contract for Disposal of Spent Nuclear Fuel and/or High Level Radioactive Waste ("Standard Contract") for failing to accept Palo Verde's spent nuclear fuel and high level waste from January 1, 2007 through June 30, 2011, as it was required to do pursuant to the terms of the Standard Contract and the Nuclear Waste Policy Act. On August 18, 2014, APS and DOE entered into a settlement agreement, stipulating to a dismissal of the lawsuit and payment of $57.4 million by DOE to the Palo Verde owners for certain specified costs incurred by Palo Verde during the period January 1, 2007 through June 30, 2011. APS’s share of this amount is $16.7 million. Amounts recovered in the lawsuit and settlement were recorded as adjustments to a regulatory liability and had no impact on the amount of reported net income. In addition, the settlement agreement provides APS with a method for submitting claims and getting recovery for costs incurred through December 31, 2016. APS has submitted two claims pursuant to the terms of the August 18, 2014 settlement agreement, for two separate time periods during July 1, 2011 through June 30, 2015. The DOE has approved and paid $53.9 million for these claims (APS’s share is $15.7 million). The amounts recovered were primarily recorded as adjustments to a regulatory liability and had no impact on reported net income. Nuclear Insurance Public liability for incidents at nuclear power plants is governed by the Price-Anderson Nuclear Industries Indemnity Act ("Price-Anderson Act"), which limits the liability of nuclear reactor owners to the amount of insurance available from both commercial sources and an industry retrospective payment plan. In accordance with the Price-Anderson Act, the Palo Verde participants are insured against public liability for a nuclear incident up to $13.5 billion per occurrence. Palo Verde maintains the maximum available nuclear liability insurance in the amount of $375 million, which is provided by American Nuclear Insurers ("ANI"). The remaining balance of $13.1 billion of liability coverage is provided through a mandatory industry-wide retrospective assessment program. If losses at any nuclear power plant covered by the program exceed the accumulated funds, APS could be assessed retrospective premium adjustments. The maximum retrospective premium assessment per reactor under the program for each nuclear liability incident is approximately $127.3 million, subject to an annual limit of $19 million per incident, to be periodically adjusted for inflation. Based on APS’s ownership interest in the three Palo Verde units, APS’s maximum potential retrospective premium assessment per incident for all three units is approximately $111 million, with a maximum annual retrospective premium assessment of approximately $16.6 million. The Palo Verde participants maintain "all risk" (including nuclear hazards) insurance for property damage to, and decontamination of, property at Palo Verde in the aggregate amount of $2.8 billion, a substantial portion of which must first be applied to stabilization and decontamination. APS has also secured insurance against portions of any increased cost of replacement generation or purchased power and business interruption resulting from a sudden and unforeseen accidental outage of any of the three units. The property damage, decontamination, and replacement power coverages are provided by Nuclear Electric Insurance Limited ("NEIL"). APS is subject to retrospective premium assessments under all NEIL policies if NEIL’s losses in any policy year exceed accumulated funds. The maximum amount APS could incur under the current NEIL policies totals approximately $23.1 million for each retrospective premium assessment declared by NEIL’s Board of Directors due to losses. In addition, NEIL policies contain rating triggers that would result in APS providing approximately $61.7 million of collateral assurance within 20 business days of a rating downgrade to non-investment grade. The insurance coverage discussed in this and the previous paragraph is subject to certain policy conditions, sublimits and exclusions. Contractual Obligations There have been no material changes, as of March 31, 2016, outside the normal course of business in contractual obligations from the information provided in our 2015 Form 10-K. See Note 2 for discussion regarding changes in our long-term debt obligations. Superfund-Related Matters The Comprehensive Environmental Response Compensation and Liability Act ("Superfund") establishes liability for the cleanup of hazardous substances found contaminating the soil, water or air. Those who generated, transported or disposed of hazardous substances at a contaminated site are among those who are potentially responsible parties ("PRPs"). PRPs may be strictly, and often are jointly and severally, liable for clean-up. On September 3, 2003, EPA advised APS that EPA considers APS to be a PRP in the Motorola 52^nd Street Superfund Site, Operable Unit 3 ("OU3") in Phoenix, Arizona. APS has facilities that are within this Superfund site. APS and Pinnacle West have agreed with EPA to perform certain investigative activities of the APS facilities within OU3. In addition, on September 23, 2009, APS agreed with EPA and one other PRP to voluntarily assist with the funding and management of the site-wide groundwater remedial investigation and feasibility study work plan. We estimate that our costs related to this investigation and study will be approximately $2 million. We anticipate incurring additional expenditures in the future, but because the overall investigation is not complete and ultimate remediation requirements are not yet finalized, at the present time expenditures related to this matter cannot be reasonably estimated. On August 6, 2013, the Roosevelt Irrigation District ("RID") filed a lawsuit in Arizona District Court against APS and 24 other defendants, alleging that RID’s groundwater wells were contaminated by the release of hazardous substances from facilities owned or operated by the defendants. The lawsuit also alleges that, under Superfund laws, the defendants are jointly and severally liable to RID. The allegations against APS arise out of APS’s current and former ownership of facilities in and around OU3. As part of a state governmental investigation into groundwater contamination in this area, on January 25, 2015, the Arizona Department of Environmental Quality ("ADEQ") sent a letter to APS seeking information concerning the degree to which, if any, APS’s current and former ownership of these facilities may have contributed to groundwater contamination in this area. APS responded to ADEQ on May 4, 2015. We are unable to predict the outcome of these matters; however, we do not expect the outcome to have a material impact on our financial position, results of operations or cash flows. Southwest Power Outage On September 8, 2011 at approximately 3:30 PM, a 500 kilovolt ("kV") transmission line running between the Hassayampa and North Gila substations in southwestern Arizona tripped out of service due to a fault that occurred at a switchyard operated by APS. Approximately ten minutes after the transmission line went off-line, generation and transmission resources for the Yuma area were lost, resulting in approximately 69,700 APS customers losing service. On September 6, 2013, a purported consumer class action complaint was filed in Federal District Court in San Diego, California, naming APS and Pinnacle West as defendants and seeking damages for loss of perishable inventory and sales as a result of interruption of electrical service. APS and Pinnacle West filed a motion to dismiss, which the court granted on December 9, 2013. On January 13, 2014, the plaintiffs appealed the lower court’s decision. On March 2, 2016, the United States Court of Appeals for the Ninth Circuit unanimously affirmed the District Court's decision. The plaintiffs filed a Petition for Rehearing En Banc, which was denied on April 11, 2016. Environmental Matters APS is subject to numerous environmental laws and regulations affecting many aspects of its present and future operations, including air emissions, water quality, wastewater discharges, solid waste, hazardous waste, and coal combustion residuals ("CCRs"). These laws and regulations can change from time to time, imposing new obligations on APS resulting in increased capital, operating, and other costs. Associated capital expenditures or operating costs could be material. APS intends to seek recovery of any such environmental compliance costs through our rates, but cannot predict whether it will obtain such recovery. The following proposed and final rules involve material compliance costs to APS. Regional Haze Rules. APS has received the final rulemaking imposing new requirements on Four Corners, Cholla and the Navajo Generating Station ("Navajo Plant"). EPA and ADEQ will require these plants to install pollution control equipment that constitutes best available retrofit technology ("BART") to lessen the impacts of emissions on visibility surrounding the plants. Four Corners. Based on EPA’s final standards, APS estimates that its 63% share of the cost of these controls for Four Corners Units 4 and 5 would be approximately $400 million. In addition, APS and El Paso Electric Company ("El Paso") entered into an asset purchase agreement providing for the purchase by APS, or an affiliate of APS, of El Paso's 7% interest in Four Corners Units 4 and 5. When APS, or an affiliate of APS, ultimately acquires El Paso's interest in Four Corners, Navajo Transitional Energy Company, LLC ("NTEC") has the option to purchase the interest within a certain timeframe pursuant to an option granted by APS to NTEC. In December 2015, NTEC notified APS of its intent to exercise the option. APS is negotiating a definitive purchase agreement with NTEC for the purchase of the 7% interest. The cost of the pollution controls related to the 7% interest is approximately $45 million, which will be assumed by the ultimate owner of the 7% interest. Navajo Plant. APS estimates that its share of costs for upgrades at the Navajo Plant, based on EPA’s Federal Implementation Plan ("FIP"), could be up to approximately $200 million. In October 2014, a coalition of environmental groups, an Indian tribe and others filed petitions for review in the United States Court of Appeals for the Ninth Circuit asking the Court to review EPA's final BART rule for the Navajo Plant. We cannot predict the outcome of this review process. Cholla. APS believes that EPA’s final rule as it applies to Cholla, which would require installation of selective catalytic reduction ("SCR") controls with a cost to APS of approximately $100 million (excludes costs related to Cholla Unit 2 which was closed on October 1, 2015), is unsupported and that EPA had no basis for disapproving Arizona’s State Implementation Plan ("SIP") and promulgating a FIP that is inconsistent with the state’s considered BART determinations under the regional haze program. Accordingly, on February 1, 2013, APS filed a Petition for Review of the final BART rule in the United States Court of Appeals for the Ninth Circuit. Briefing in the case was completed in February 2014. In September 2014, APS met with EPA to propose a compromise BART strategy wherein, pending certain regulatory approvals, APS would permanently close Cholla Unit 2 and cease burning coal at Units 1 and 3 by the mid-2020s. (See Note 3 for details related to the resulting regulatory asset.) APS made the proposal with the understanding that additional emission control equipment is unlikely to be required in the future because retiring and/or converting the units as contemplated in the proposal is more cost effective than, and will result in increased visibility improvement over, the current BART requirements for NOx imposed on the Cholla units under EPA's BART FIP. APS’s proposal involves state and federal rulemaking processes. In light of these ongoing administrative proceedings, on February 19, 2015, APS, PacifiCorp (owner of Cholla Unit 4), and EPA jointly moved the court to sever and hold in abeyance those claims in the litigation pertaining to Cholla pending regulatory actions by the state and EPA. The court granted the parties' unopposed motion on February 20, 2015. On October 16, 2015, ADEQ issued the Cholla permit, which incorporates APS's proposal, and subsequently submitted a proposed revision to the SIP to the EPA, which would incorporate the new permit terms. APS is unable to predict when or whether APS's proposal may ultimately be approved by the EPA. Mercury and Air Toxic Standards ("MATS"). In 2011, EPA issued rules establishing maximum achievable control technology standards to regulate emissions of mercury and other hazardous air pollutants from fossil-fired plants. APS estimates that the cost for the remaining equipment necessary to meet these standards is approximately $8 million for Cholla (excludes costs related to Cholla Unit 2 which was closed on October 1, 2015). No additional equipment is needed for Four Corners Units 4 and 5 to comply with these rules. Salt River Project Agricultural Improvement and Power District ("SRP"), the operating agent for the Navajo Plant, estimates that APS's share of costs for equipment necessary to comply with the rules is approximately $1 million. The United States Supreme Court’s 2015 decision in Michigan vs. EPA reversed and remanded the MATS proceeding back to the DC Circuit Court. The Circuit Court then remanded the MATS rule back to EPA to address rulemaking deficiencies identified by the Supreme Court. On April 14, 2016, EPA took action to resolve these deficiencies by issuing a revised "appropriate and necessary" finding, which is a prerequisite to regulating hazardous air pollutants emitted by power plants under the Clean Air Act, to expressly evaluate the costs of the MATS regulation. Further litigation concerning the propriety of this finding is expected. These proceedings do not materially impact APS. Regardless of the results from further judicial or administrative proceedings concerning the MATS rulemaking, the Arizona State Mercury Rule, the stringency of which is roughly equivalent to that of MATS, would still apply to Cholla. Coal Combustion Waste. On December 19, 2014, EPA issued its final regulations governing the handling and disposal of CCR, such as fly ash and bottom ash. The rule regulates CCR as a non-hazardous waste under Subtitle D of the Resource Conservation and Recovery Act ("RCRA") and establishes national minimum criteria for existing and new CCR landfills and surface impoundments and all lateral expansions consisting of location restrictions, design and operating criteria, groundwater monitoring and corrective action, closure requirements and post closure care, and recordkeeping, notification, and Internet posting requirements. The rule generally requires any existing unlined CCR surface impoundment that is contaminating groundwater above a regulated constituent’s groundwater protection standard to stop receiving CCR and either retrofit or close, and further requires the closure of any CCR landfill or surface impoundment that cannot meet the applicable performance criteria for location restrictions or structural integrity. Because the Subtitle D rule is self-implementing, the CCR standards apply directly to the regulated facility, and facilities are directly responsible for ensuring that their operations comply with the rule’s requirements. While EPA has chosen to regulate the disposal of CCR in landfills and surface impoundments as non-hazardous waste under the final rule, the agency makes clear that it will continue to evaluate any risks associated with CCR disposal and leaves open the possibility that it may regulate CCR as a hazardous waste under RCRA Subtitle C in the future. APS currently disposes of CCR in ash ponds and dry storage areas at Cholla and Four Corners. APS estimates that its share of incremental costs to comply with the CCR rule for Four Corners is approximately $15 million, and its share of incremental costs for Cholla is approximately $40 million. The Navajo Plant currently disposes of CCR in a dry landfill storage area. APS estimates that its share of incremental costs to comply with the CCR rule for the Navajo Plant is approximately $1 million. Additionally, the CCR rule requires on-going groundwater monitoring. Depending upon the results of such monitoring at each of Cholla, Four Corners and the Navajo Plant, we may be required to take corrective actions. Because the initial monitoring at these plants is not yet complete, at the present time expenditures related to potential corrective actions cannot be reasonably estimated. Clean Power Plan. On August 3, 2015, EPA finalized carbon pollution standards for existing, new, modified, and reconstructed electric generating units ("EGUs"). EPA’s final rules require newly built fossil fuel-fired EGUs, along with those undergoing modification or reconstruction, to meet CO₂ performance standards based on a combination of best operating practices and equipment upgrades. EPA established separate performance standards for two types of EGUs: stationary combustion turbines, typically natural gas; and electric utility steam generating units, typically coal. With respect to existing power plants, EPA’s recently finalized “Clean Power Plan” imposes state-specific goals or targets to achieve reductions in CO₂ emission rates from existing EGUs measured from a 2012 baseline. In a significant change from the proposed rule, EPA’s final performance standards apply directly to specific units based upon their fuel-type and configuration (i.e., coal- or oil-fired steam plants versus combined cycle natural gas plants). As such, each state’s goal is an emissions performance standard that reflects the fuel mix employed by the EGUs in operation in those states. The final rule provides guidelines to states to help develop their plans for meeting the interim (2022-2029) and final (2030 and beyond) emission performance standards, with three distinct compliance periods within that timeframe. States were originally required to submit their plans to EPA by September 2016, with an optional two-year extension provided to states establishing a need for additional time; however, it is expected that this timing will be impacted by the court-imposed stay described below. Prior to the court-imposed stay described below, ADEQ, with input from a technical working group comprised of Arizona utilities and other stakeholders, was working to develop a compliance plan for submittal to EPA. Since the imposition of the stay, ADEQ reports that it is continuing to assess its options while completing outreach and soliciting feedback from stakeholders. In addition to these on-going state proceedings, EPA has taken public comments on proposed model rules and a proposed federal compliance plan, which included consideration as to how the Clean Power Plan will apply to EGUs on tribal land such as the Navajo Nation. The legality of the Clean Power Plan is being challenged in the U.S. Court of Appeals for the D.C. Circuit; the parties raising this challenge include, among others, the ACC. On February 9, 2016, the U.S. Supreme Court granted a stay of the Clean Power Plan pending judicial review of the rule, which temporarily delays compliance obligations under the Clean Power Plan. We cannot predict the extent of such a delay. With respect to our Arizona generating units, we are currently evaluating the range of compliance options available to ADEQ, including whether Arizona deploys a rate- or mass-based compliance plan. Based on the fuel-mix and location of our Arizona EGUs, and the significant investments we have made in renewable generation and demand-side energy efficiency, if ADEQ selects a rate-based compliance plan, we believe that we will be able to comply with the Clean Power Plan for our Arizona generating units in a manner that will not have material financial or operational impacts to the Company. On the other hand, if ADEQ selects a mass-based approach to compliance with the Clean Power Plan, our annual cost of compliance could be material. These costs could include costs to acquire mass-based compliance allowances. As to our facilities on the Navajo Nation, EPA has yet to determine whether or to what extent EGUs on the Navajo Nation will be required to comply with the Clean Power Plan. EPA has proposed to determine that it is necessary or appropriate to impose a federal plan on the Navajo Nation for compliance with the Clean Power Plan. In response, we filed comments with EPA advocating that such a federal plan is neither necessary nor appropriate to protect air quality on the Navajo Nation. If EPA reaches a determination that is consistent with our preferred approach for the Navajo Nation, we believe the Clean Power Plan will not have material financial or operational impacts on our operations within the Navajo Nation. Alternatively, if EPA determines that a federal plan is necessary or appropriate for the Navajo Nation, and depending on our need for future operations at our EGUs located there, we may be unable to comply with the federal plan unless we acquire mass-based allowances or emission rate credits within established carbon trading markets, or curtail our operations. Subject to the uncertainties set forth below, and assuming that EPA establishes a federal plan for the Navajo Nation that requires carbon allowances or credits to be surrendered for plan compliance, it is possible we will be required to purchase some quantity of credits or allowances, the cost of which could be material. Because ADEQ has not issued its plan for Arizona, and because we do not know whether EPA will decide to impose a plan or, if so, what that plan will require, there are a number of uncertainties associated with our potential cost exposure. These uncertainties include: whether judicial review will result in the Clean Power Plan being vacated in whole or in part or, if not, the extent of any resulting compliance deadline delays; whether any plan will be imposed for EGUs on the Navajo Nation; the future existence and liquidity of allowance or credit compliance trading markets; the applicability of existing contractual obligations with current and former owners of our participant-owned coal-fired EGUs; the type of federal or state compliance plan (either rate- or mass-based); whether or not the trading of allowances or credits will be authorized mechanisms for compliance with any final EPA or ADEQ plan; and how units that have been closed will be treated for allowance or credit allocation purposes. In the event that the incurrence of compliance costs is not economically viable or prudent for our operations in Arizona or on the Navajo Nation, or if we do not have the option of acquiring allowances to account for the emissions from our operations, we may explore other options, including reduced levels of output, as an alternative to purchasing allowances. Given these uncertainties, our analysis of the available compliance options remains on-going, and additional information or considerations may arise that change our expectations. Other environmental rules that could involve material compliance costs include those related to effluent limitations, the ozone national ambient air quality standard and other rules or matters involving the Clean Air Act, Clean Water Act, Endangered Species Act, the Navajo Nation, and water supplies for our power plants. The financial impact of complying with current and future environmental rules could jeopardize the economic viability of our coal plants or the willingness or ability of power plant participants to fund any required equipment upgrades or continue their participation in these plants. The economics of continuing to own certain resources, particularly our coal plants, may deteriorate, warranting early retirement of those plants, which may result in asset impairments. APS would seek recovery in rates for the book value of any remaining investments in the plants as well as other costs related to early retirement, but cannot predict whether it would obtain such recovery. Federal Agency Environmental Lawsuit Related to Four Corners On December 21, 2015, several environmental groups filed a notice of intent to sue with Office of Surface Mining Reclamation and Enforcement ("OSM") and other federal agencies under the Endangered Species Act (“ESA”) alleging that OSM’s reliance on the Biological Opinion and Incidental Take Statement prepared in connection with a federal environmental review were not in accordance with applicable law. The environmental review was undertaken as part of the United States Department of the Interior's ("DOI's") review process necessary to allow for the effectiveness of lease amendments and related rights-of-way renewals for Four Corners. This review process also required separate environmental impact evaluations under the National Environmental Policy Act (“NEPA”) and culminated in the issuance of a Record of Decision justifying the agency action extending the life of the plant and the adjacent mine. On April 20, 2016, the same environmental groups followed through with their notice of intent to sue by filing a lawsuit against OSM and other federal agencies in the District of Arizona. Expanding upon the December 2015 ESA notice, the lawsuit alleges that these federal agencies violated both the ESA and NEPA in providing the federal approvals necessary to extend operations at the Four Corners Power Plant and the adjacent Navajo Mine past July 6, 2016. We are monitoring the proceedings and intend to request the right to intervene in the litigation. We cannot predict the outcome of this matter or its potential effect on Four Corners. New Mexico Tax Matter On May 23, 2013, the New Mexico Taxation and Revenue Department ("NMTRD") issued a notice of assessment for coal severance surtax, penalty, and interest totaling approximately $30 million related to coal supplied under the coal supply agreement for Four Corners (the "Assessment"). APS’s share of the Assessment is approximately $12 million. For procedural reasons, on behalf of the Four Corners co-owners, including APS, the coal supplier made a partial payment of the Assessment in the amount of $0.8 million and immediately filed a refund claim with respect to that partial payment in August 2013. The NMTRD denied the refund claim. On December 19, 2013, the coal supplier and APS, on its own behalf and as operating agent for Four Corners, filed a complaint with the New Mexico District Court contesting both the validity of the Assessment and the refund claim denial. On June 30, 2015, the court ruled that the Assessment was not valid and further ruled that APS and the other Four Corners co-owners receive a refund of all of the contested amounts previously paid under the applicable tax statute. The NMTRD filed an appeal of the decision on August 31, 2015. On March 16, 2016, APS and the coal supplier entered into a final settlement agreement with the NMTRD with respect to the Assessment. Pursuant to the final settlement agreement, the NMTRD agreed to release the Assessment, dismiss its filed appeal, and release its rights to any other surtax claims with respect to the coal supply agreement. APS and the other Four Corners co-owners agreed to forgo refund rights with respect to all of the contested amounts previously paid under the applicable tax statute, as well as pay $1 million. APS's share of this settlement payment, together with its share of the partial payment described above is approximately $0.8 million. Financial Assurances In the normal course of business, we obtain standby letters of credit and surety bonds from financial institutions and other third parties. These instruments guarantee our own future performance and provide third parties with financial and performance assurance in the event we do not perform. These instruments support certain debt arrangements, commodity contract collateral obligations, and other transactions. As of March 31, 2016, standby letters of credit totaled $79 million and will expire in 2016. As of March 31, 2016, surety bonds expiring through 2018 totaled $150 million. The underlying liabilities insured by these instruments are reflected on our balance sheets, where applicable. Therefore, no additional liability is reflected for the letters of credit and surety bonds themselves. We enter into agreements that include indemnification provisions relating to liabilities arising from or related to certain of our agreements. Most significantly, APS has agreed to indemnify the equity participants and other parties in the Palo Verde sale leaseback transactions with respect to certain tax matters. Generally, a maximum obligation is not explicitly stated in the indemnification provisions and, therefore, the overall maximum amount of the obligation under such indemnification provisions cannot be reasonably estimated. Based on historical experience and evaluation of the specific indemnities, we do not believe that any material loss related to such indemnification provisions is likely. Pinnacle West has issued parental guarantees and has provided indemnification under certain surety bonds for APS which were not material at March 31, 2016.

Other Income and Other Expense

3 Months Ended

Mar. 31, 2016

Component of Other Income and Other Expense Nonoperating [Line Items]

Other Income and Other Expense

The following table provides detail of Pinnacle West's Consolidated other income and other expense for the three months ended March 31, 2016 and 2015 (dollars in thousands):



	Three Months Ended March 31,
	2016			2015
Other income:
Interest income	$	117		$	110
Miscellaneous	—			125
Total other income	$	117		$	235
Other expense:
Non-operating costs	$	(2,049	)	$	(2,249	)
Investment losses — net	(518		)	(495		)
Miscellaneous	(1,471		)	(1,542		)
Total other expense	$	(4,038	)	$	(4,286	)

Arizona Public Service Company

Component of Other Income and Other Expense Nonoperating [Line Items]

Other Income and Other Expense

The following table provides detail of APS’s other income and other expense for the three months ended March 31, 2016 and 2015 (dollars in thousands):



	Three Months Ended March 31,
	2016			2015
Other income:
Interest income	$	73		$	67
Gain on disposition of property	332			207
Miscellaneous	205			365
Total other income	$	610		$	639
Other expense:
Non-operating costs (a)	$	(1,966	)	$	(2,517	)
Loss on disposition of property	(426		)	(643		)
Miscellaneous	(2,358		)	(2,194		)
Total other expense	$	(4,750	)	$	(5,354	)

(a) As defined by FERC, includes below-the-line non-operating utility expense (items excluded from utility rate recovery).

Earnings Per Share

3 Months Ended

Mar. 31, 2016

Earnings Per Share [Abstract]

Earnings Per Share

The following table presents the calculation of Pinnacle West’s basic and diluted earnings per share for the three months ended March 31, 2016 and 2015 (in thousands, except per share amounts):



	Three Months Ended March 31,
	2016		2015
Net income attributable to common shareholders	$	4,453	$	16,122
Weighted average common shares outstanding — basic	111,296		110,916
Net effect of dilutive securities:
Contingently issuable performance shares and restricted stock units	551		461
Weighted average common shares outstanding — diluted	111,847		111,377
Earnings per weighted-average common share outstanding
Net income attributable to common shareholders — basic	$	0.04	$	0.15
Net income attributable to common shareholders — diluted	$	0.04	$	0.14

Fair Value Measurements

3 Months Ended

Mar. 31, 2016

Fair Value Disclosures [Abstract]

Fair Value Measurements

Assets and liabilities are classified in their entirety based on the lowest level of input that is significant to the fair value measurement. Thus, a valuation may be classified in Level 3 even though the valuation may include significant inputs that are readily observable. We maximize the use of observable inputs and minimize the use of unobservable inputs. We rely primarily on the market approach of using prices and other market information for identical and/or comparable assets and liabilities. If market data is not readily available, inputs may reflect our own assumptions about the inputs market participants would use. Our assessment of the inputs and the significance of a particular input to the fair value measurement requires judgment and may affect the valuation of fair value assets and liabilities as well as their placement within the fair value hierarchy levels. We assess whether a market is active by obtaining observable broker quotes, reviewing actual market activity, and assessing the volume of transactions. We consider broker quotes observable inputs when the quote is binding on the broker, we can validate the quote with market activity, or we can determine that the inputs the broker used to arrive at the quoted price are observable.

Recurring Fair Value Measurements

Cash Equivalents

Cash equivalents represent short-term investments with original maturities of three months or less in exchange traded money market funds that are valued using quoted prices in active markets.

Risk Management Activities — Derivative Instruments

Investments Held in our Nuclear Decommissioning Trust

Fair Value Tables

The following table presents the fair value at March 31, 2016, of our assets and liabilities that are measured at fair value on a recurring basis (dollars in thousands):



	Quoted Prices in Active Markets for Identical Assets (Level 1)		Significant Other Observable Inputs (Level 2)			Significant Unobservable Inputs (a) (Level 3)			Other				Balance at March 31, 2016
Assets
Risk management activities — derivative instruments:
Commodity contracts	$	—	$	12,613		$	23,847		$	(11,759	)	(b)	$	24,701
Nuclear decommissioning trust:
U.S. commingled equity funds	—		—			—			319,971			(c)	319,971
Fixed income securities:
Cash and cash equivalent funds	11,535		—			—			(1,898		)	(d)	9,637
U.S. Treasury	107,698		—			—			—				107,698
Corporate debt	—		101,687			—			—				101,687
Mortgage-backed securities	—		109,298			—			—				109,298
Municipal bonds	—		80,344			—			—				80,344
Other	—		23,319			—			—				23,319
Subtotal nuclear decommissioning trust	119,233		314,648			—			318,073				751,954
Total	$	119,233	$	327,261		$	23,847		$	306,314			$	776,655
Liabilities
Risk management activities — derivative instruments:
Commodity contracts	$	—	$	(140,554	)	$	(63,354	)	$	25,022		(b)	$	(178,886	)


(a)	Primarily consists of heat rate options and other long-dated electricity contracts.


(b)	Represents counterparty netting, margin and collateral. See Note 6.


(c)	Valued using NAV as a practical expedient, and therefore not classified in the fair value hierarchy.


(d)	Represents nuclear decommissioning trust net pending securities sales and purchases.

The following table presents the fair value at December 31, 2015, of our assets and liabilities that are measured at fair value on a recurring basis (dollars in thousands):



	Quoted Prices in Active Markets for Identical Assets (Level 1)		Significant Other Observable Inputs (Level 2)			Significant Unobservable Inputs (a) (Level 3)			Other				Balance at December 31, 2015
Assets
Risk management activities — derivative instruments:
Commodity contracts	$	—	$	22,992		$	30,364		$	(25,345	)	(b)	$	28,011
Nuclear decommissioning trust:
U.S. commingled equity funds	—		—			—			314,957			(c)	314,957
Fixed income securities:
Cash and cash equivalent funds	12,260		—			—			(335		)	(d)	11,925
U.S. Treasury	117,245		—			—			—				117,245
Corporate debt	—		96,243			—			—				96,243
Mortgage-backed securities	—		99,065			—			—				99,065
Municipal bonds	—		72,206			—			—				72,206
Other	—		23,555			—			—				23,555
Subtotal nuclear decommissioning trust	129,505		291,069			—			314,622				735,196
Total	$	129,505	$	314,061		$	30,364		$	289,277			$	763,207
Liabilities
Risk management activities — derivative instruments:
Commodity contracts	$	—	$	(144,044	)	$	(63,343	)	$	39,698		(b)	$	(167,689	)


(a)	Primarily consists of heat rate options and other long-dated electricity contracts.


(b)	Represents counterparty netting, margin and collateral. See Note 6.


(c)	Valued using NAV as a practical expedient, and therefore not classified in the fair value hierarchy.


(d)	Represents nuclear decommissioning trust net pending securities sales and purchases.

Fair Value Measurements Classified as Level 3

The following tables provide information regarding our significant unobservable inputs used to value our risk management derivative Level 3 instruments at March 31, 2016 and December 31, 2015:



	March 31, 2016 Fair Value (thousands)				Valuation Technique	Significant Unobservable Input		Weighted-Average
Commodity Contracts	Assets		Liabilities		Valuation Technique	Significant Unobservable Input	Range	Weighted-Average
Electricity:
Forward Contracts (a)	$	21,606	$	51,305	Discounted cash flows	Electricity forward price (per MWh)	$13.97 - $39.61	$	26.45
Option Contracts (b)	—		5,880		Option model	Electricity forward price (per MWh)	$19.46 - $37.93	$	29.39
						Electricity price volatilities	47% - 72%	63		%
						Natural gas price volatilities	38% - 45%	41		%
Natural Gas:
Forward Contracts (a)	2,241		6,169		Discounted cash flows	Natural gas forward price (per MMBtu)	$1.65 - $3.11	$	2.67
Total	$	23,847	$	63,354


(a)	Includes swaps and physical and financial contracts.


(b)	Electricity and natural gas price volatilities are estimated based on historical forward price movements due to lack of market quotes for implied volatilities.



	December 31, 2015 Fair Value (thousands)				Valuation Technique	Significant Unobservable Input		Weighted-Average
Commodity Contracts	Assets		Liabilities		Valuation Technique	Significant Unobservable Input	Range	Weighted-Average
Electricity:
Forward Contracts (a)	$	24,543	$	54,679	Discounted cash flows	Electricity forward price (per MWh)	$15.92 - $40.73	$	26.86
Option Contracts (b)	—		5,628		Option model	Electricity forward price (per MWh)	$23.87 - $44.13	$	33.91
						Electricity price volatilities	40% - 59%	52		%
						Natural gas price volatilities	32% - 40%	35		%
Natural Gas:
Forward Contracts (a)	5,821		3,036		Discounted cash flows	Natural gas forward price (per MMBtu)	$2.18 - $3.14	$	2.61
Total	$	30,364	$	63,343


(a)	Includes swaps and physical and financial contracts.


(b)	Electricity and natural gas price volatilities are estimated based on historical forward price movements due to lack of market quotes for implied volatilities.



	Three Months Ended March 31,
Commodity Contracts	2016			2015
Net derivative balance at beginning of period	$	(32,979	)	$	(41,386	)
Total net gains (losses) realized/unrealized:
Included in OCI	—			(262		)
Deferred as a regulatory asset or liability	(9,103		)	(10,747		)
Settlements	1,765			310
Transfers into Level 3 from Level 2	262			(402		)
Transfers from Level 3 into Level 2	548			3,673
Net derivative balance at end of period	$	(39,507	)	$	(48,814	)

Net unrealized gains included in earnings related to instruments still held at end of period	$	—		$	—

Amounts included in earnings are recorded in either operating revenues or fuel and purchased power depending on the nature of the underlying contract.

Transfers reflect the fair market value at the beginning of the period and are triggered by a change in the lowest significant input as of the end of the period. We had no significant Level 1 transfers to or from any other hierarchy level. Transfers in or out of Level 3 are typically related to our long-dated energy transactions that extend beyond available quoted periods.

Financial Instruments Not Carried at Fair Value

Nuclear Decommissioning Trusts

3 Months Ended

Mar. 31, 2016

Investments, Debt and Equity Securities [Abstract]

Nuclear Decommissioning Trusts



	Fair Value			Total Unrealized Gains		Total Unrealized Losses
March 31, 2016
Equity securities	$	319,971		$	159,790	$	(65	)
Fixed income securities	433,881			18,250		(676		)
Net payables (a)	(1,898		)	—		—
Total	$	751,954		$	178,040	$	(741	)



	Fair Value			Total Unrealized Gains		Total Unrealized Losses
December 31, 2015
Equity securities	$	314,957		$	157,098	$	(115	)
Fixed income securities	420,574			11,955		(2,645		)
Net payables (a)	(335		)	—		—
Total	$	735,196		$	169,053	$	(2,760	)


(a)	Net payables relate to pending purchases and sales of securities.



	Three Months Ended March 31,
	2016			2015
Realized gains	$	2,438		$	1,195
Realized losses	(1,786		)	(525		)
Proceeds from the sale of securities (a)	141,809			115,282


(a)	Proceeds are reinvested in the trust.

The fair value of fixed income securities, summarized by contractual maturities, at March 31, 2016 is as follows (dollars in thousands):



	Fair Value
Less than one year	$	11,633
1 year – 5 years	126,221
5 years – 10 years	101,773
Greater than 10 years	194,254
Total	$	433,881

New Accounting Standards	3 Months Ended
New Accounting Standards	Mar. 31, 2016
New Accounting Pronouncements and Changes in Accounting Principles [Abstract]
New Accounting Standards	New Accounting Standards In May 2014, a new revenue recognition accounting standard was issued. This standard provides a single comprehensive model for entities to use in accounting for revenue arising from contracts with customers and supersedes most current revenue recognition guidance. The new revenue standard will be effective for us on January 1, 2018. The guidance may be adopted using a full retrospective application or a simplified transition method that allows entities to record a cumulative effect adjustment in retained earnings at the date of initial application. We are currently evaluating this new standard and the impacts it may have on our financial statements. In January 2016, a new accounting standard was issued relating to the recognition and measurement of financial instruments. The new guidance will require certain investments in equity securities to be measured at fair value with changes in fair value recognized in net income, and modifies the impairment assessment of certain equity securities. The new guidance is effective for us on January 1, 2018. Certain aspects of the guidance may require a cumulative-effect adjustment and other aspects of the guidance are required to be adopted prospectively. We are currently evaluating this new accounting standard and the impacts it may have on our financial statements. In February 2016, a new lease accounting standard was issued. This new standard supersedes the existing lease accounting model, and modifies both lessee and lessor accounting. The new guidance will require a lessee to reflect most operating lease arrangements on the balance sheet by recording a right-of-use asset and a lease liability that will initially be measured at the present value of lease payments. Among other changes, the new standard also modifies the definition of a lease, and requires expanded lease disclosures. The new standard will be effective for us on January 1, 2019, with early application permitted. The guidance must be adopted using a modified retrospective approach, with various optional practical expedients provided to facilitate transition. We are currently evaluating this new accounting standard and the impacts it may have on our financial statements. In March 2016, new stock compensation accounting guidance was issued that modifies the accounting for employee share-based payments. The new guidance will require all tax benefits and deficiencies arising from share-based payments to be recognized in net income, modifies the tax withholding threshold for awards to qualify for equity classification, simplifies accounting for forfeitures, and clarifies certain cash flow presentation matters. The new guidance is effective for us on January 1, 2017, with early application permitted. Certain aspects of the guidance must be adopted using a prospective approach and other aspects will be adopted using a retrospective approach. We are currently evaluating this new accounting standard and the impacts it may have on our financial statements. In February 2015, new consolidation accounting guidance was issued that amends many aspects of the guidance relating to the analysis and consolidation of variable interest entities. We adopted this new guidance during the first quarter of 2016. The adoption did not impact our financial statements.

Changes in Accumulated Other Comprehensive Loss

3 Months Ended

Mar. 31, 2016

Accumulated Other Comprehensive Income (Loss) [Line Items]

Changes in Accumulated Other Comprehensive Loss



	Three Months Ended
	March 31,
	2016			2015
Balance at beginning of period	$	(44,748	)	$	(68,141	)
Derivative Instruments
OCI (loss) before reclassifications	(693		)	(800		)
Amounts reclassified from accumulated other comprehensive loss (a)	1,141			1,976
Net current period OCI (loss)	448			1,176
Pension and Other Postretirement Benefits
Amounts reclassified from accumulated other comprehensive loss (b)	530			583
Net current period OCI (loss)	530			583
Balance at end of period	$	(43,770	)	$	(66,382	)


(a)	These amounts represent realized gains and losses and are included in the computation of fuel and purchased power costs and are subject to the PSA. See Note 6.


(b)	These amounts primarily represent amortization of actuarial loss, and are included in the computation of net periodic pension cost. See Note 4.

Arizona Public Service Company

Accumulated Other Comprehensive Income (Loss) [Line Items]

Changes in Accumulated Other Comprehensive Loss



	Three Months Ended
	March 31,
	2016			2015
Balance at beginning of period	$	(27,097	)	$	(48,333	)
Derivative Instruments
OCI (loss) before reclassifications	(693		)	(800		)
Amounts reclassified from accumulated other comprehensive loss (a)	1,141			1,976
Net current period OCI (loss)	448			1,176
Pension and Other Postretirement Benefits
Amounts reclassified from accumulated other comprehensive loss (b)	611			681
Net current period OCI (loss)	611			681
Balance at end of period	$	(26,038	)	$	(46,476	)


(a)	These amounts represent realized gains and losses and are included in the computation of fuel and purchased power costs and are subject to the PSA. See Note 6.


(b)	These amounts primarily represent amortization of actuarial loss and are included in the computation of net periodic pension cost. See Note 4.

New Accounting Standards (Policies)	3 Months Ended
New Accounting Standards (Policies)	Mar. 31, 2016
New Accounting Pronouncements and Changes in Accounting Principles [Abstract]
New Accounting Standards	In May 2014, a new revenue recognition accounting standard was issued. This standard provides a single comprehensive model for entities to use in accounting for revenue arising from contracts with customers and supersedes most current revenue recognition guidance. The new revenue standard will be effective for us on January 1, 2018. The guidance may be adopted using a full retrospective application or a simplified transition method that allows entities to record a cumulative effect adjustment in retained earnings at the date of initial application. We are currently evaluating this new standard and the impacts it may have on our financial statements. In January 2016, a new accounting standard was issued relating to the recognition and measurement of financial instruments. The new guidance will require certain investments in equity securities to be measured at fair value with changes in fair value recognized in net income, and modifies the impairment assessment of certain equity securities. The new guidance is effective for us on January 1, 2018. Certain aspects of the guidance may require a cumulative-effect adjustment and other aspects of the guidance are required to be adopted prospectively. We are currently evaluating this new accounting standard and the impacts it may have on our financial statements. In February 2016, a new lease accounting standard was issued. This new standard supersedes the existing lease accounting model, and modifies both lessee and lessor accounting. The new guidance will require a lessee to reflect most operating lease arrangements on the balance sheet by recording a right-of-use asset and a lease liability that will initially be measured at the present value of lease payments. Among other changes, the new standard also modifies the definition of a lease, and requires expanded lease disclosures. The new standard will be effective for us on January 1, 2019, with early application permitted. The guidance must be adopted using a modified retrospective approach, with various optional practical expedients provided to facilitate transition. We are currently evaluating this new accounting standard and the impacts it may have on our financial statements. In March 2016, new stock compensation accounting guidance was issued that modifies the accounting for employee share-based payments. The new guidance will require all tax benefits and deficiencies arising from share-based payments to be recognized in net income, modifies the tax withholding threshold for awards to qualify for equity classification, simplifies accounting for forfeitures, and clarifies certain cash flow presentation matters. The new guidance is effective for us on January 1, 2017, with early application permitted. Certain aspects of the guidance must be adopted using a prospective approach and other aspects will be adopted using a retrospective approach. We are currently evaluating this new accounting standard and the impacts it may have on our financial statements. In February 2015, new consolidation accounting guidance was issued that amends many aspects of the guidance relating to the analysis and consolidation of variable interest entities. We adopted this new guidance during the first quarter of 2016. The adoption did not impact our financial statements.

Consolidation and Nature of Operations (Tables)

3 Months Ended

Mar. 31, 2016

Organization, Consolidation and Presentation of Financial Statements [Abstract]

Summary of supplemental cash flow information

The following table summarizes supplemental Pinnacle West cash flow information (dollars in thousands):



	Three Months Ended March 31,
	2016		2015
Cash paid during the period for:
Income taxes, net of refunds	$	2,502	$	1,832
Interest, net of amounts capitalized	56,139		53,555
Significant non-cash investing and financing activities:
Accrued capital expenditures	$	59,707	$	56,165

Long-Term Debt and Liquidity Matters (Tables)

3 Months Ended

Mar. 31, 2016

Debt Disclosure [Abstract]

Schedule of estimated fair value of long-term debt, including current maturities

The following table presents the estimated fair value of our long-term debt, including current maturities (dollars in thousands):



	As of March 31, 2016				As of December 31, 2015
	Carrying Amount		Fair Value		Carrying Amount		Fair Value
Pinnacle West	$	125,000	$	125,000	$	125,000	$	125,000
APS	3,695,612		4,136,022		3,694,971		3,981,367
Total	$	3,820,612	$	4,261,022	$	3,819,971	$	4,106,367

Regulatory Matters (Tables)

3 Months Ended

Mar. 31, 2016

Regulated Operations [Abstract]

Schedule of changes in the deferred fuel and purchased power regulatory asset

The following table shows the changes in the deferred fuel and purchased power regulatory asset (liability) for 2016 and 2015 (dollars in thousands):



	Three Months Ended March 31,
	2016			2015
Beginning balance	$	(9,688	)	$	6,925
Deferred fuel and purchased power costs — current period	(1,007		)	(17,671		)
Amounts charged to customers	(2,388		)	(5,614		)
Ending balance	$	(13,083	)	$	(16,360	)

Schedule of regulatory assets

The detail of regulatory assets is as follows (dollars in thousands):



	Amortization Through	March 31, 2016				December 31, 2015
	Amortization Through	Current		Non-Current		Current		Non-Current
Pension	(a)	$	—	$	610,569	$	—	$	619,223
Retired power plant costs	2033	9,913		125,037		9,913		127,518
Income taxes — allowance for funds used during construction ("AFUDC") equity	2046	5,419		132,149		5,495		133,712
Deferred fuel and purchased power — mark-to-market (Note 6)	2019	86,160		69,708		71,852		69,697
Four Corners cost deferral (b)	2024	6,689		61,910		6,689		63,582
Income taxes — investment tax credit basis adjustment	2045	1,852		48,347		1,766		48,462
Lost fixed cost recovery (b)	2017	48,702		—		45,507		—
Palo Verde VIEs (Note 5)	2046	—		18,311		—		18,143
Deferred compensation	2036	—		35,871		—		34,751
Deferred property taxes	(c)	—		56,589		—		50,453
Loss on reacquired debt	2034	1,515		15,996		1,515		16,375
Tax expense of Medicare subsidy	2024	1,512		12,073		1,520		12,163
Transmission vegetation management	2016	2,272		—		4,543		—
Mead-Phoenix transmission line CIAC	2050	332		10,957		332		11,040
Transmission cost adjustor (b)	2018	3,969		462		—		2,942
Coal reclamation	2026	418		5,495		418		6,085
Other	Various	—		—		5		—
Total regulatory assets (d)		$	168,753	$	1,203,474	$	149,555	$	1,214,146


(a)	This asset represents the future recovery of pension benefit obligations through retail rates. If these costs are disallowed by the ACC, this regulatory asset would be charged to Other Comprehensive Income ("OCI") and result in lower future revenues. See Note 4 for further discussion.


(b)	See "Cost Recovery Mechanisms" discussion above.


(c)	Per the provision of the 2012 Settlement Agreement.


(d)	There are no regulatory assets for which the ACC has allowed recovery of costs, but not allowed a return by exclusion from rate base. FERC rates are set using a formula rate as described in "Transmission Rates, Transmission Cost Adjustor and Other Transmission Matters."

Schedule of regulatory liabilities

The detail of regulatory liabilities is as follows (dollars in thousands):



	Amortization Through	March 31, 2016				December 31, 2015
	Amortization Through	Current		Non-Current		Current		Non-Current
Asset retirement obligations	2057	$	—	$	289,485	$	—	$	277,554
Removal costs	(a)	32,473		244,724		39,746		240,367
Other postretirement benefits	(d)	34,100		171,029		34,100		179,521
Income taxes — deferred investment tax credit	2045	3,774		96,940		3,604		97,175
Income taxes — change in rates	2046	1,771		71,756		1,113		72,454
Spent nuclear fuel	2047	31		71,235		3,051		67,437
Renewable energy standard (b)	2017	41,518		3,274		43,773		4,365
Demand side management (b)	2017	6,628		19,115		6,079		19,115
Sundance maintenance	2030	—		14,080		—		13,678
Deferred fuel and purchased power (b) (c)	2017	13,083		—		9,688		—
Deferred gains on utility property	2019	2,062		5,501		2,062		6,001
Four Corners coal reclamation	2031	—		14,725		—		8,920
Other	Various	114		7,554		2,550		7,565
Total regulatory liabilities		$	135,554	$	1,009,418	$	145,766	$	994,152


(a)	In accordance with regulatory accounting guidance, APS accrues for removal costs for its regulated assets, even if there is no legal obligation for removal.


(b)	See "Cost Recovery Mechanisms" discussion above.


(c)	Subject to a carrying charge.


(d)	See Note 4.

Retirement Plans and Other Postretirement Benefits (Tables)

3 Months Ended

Mar. 31, 2016

Compensation and Retirement Disclosure [Abstract]

Schedule of net periodic benefit costs and the portion of these costs charged to expense (including administrative costs and excluding amounts capitalized as overhead construction, billed to electric plant participants or charged or amortized to the regulatory asset)



	Pension Benefits						Other Benefits
	Three Months Ended March 31,						Three Months Ended March 31,
	2016			2015			2016			2015
Service cost — benefits earned during the period	$	14,266		$	15,824		$	3,937		$	4,346
Interest cost on benefit obligation	32,945			31,189			7,341			7,184
Expected return on plan assets	(43,792		)	(45,149		)	(9,122		)	(9,147		)
Amortization of:
Prior service cost	132			149			(9,471		)	(9,492		)
Net actuarial loss	9,731			7,761			946			1,561
Net periodic benefit cost	$	13,282		$	9,774		$	(6,369	)	$	(5,548	)
Portion of cost charged to expense	$	6,519		$	5,987		$	(3,126	)	$	(1,788	)

Palo Verde Sale Leaseback Variable Interest Entities (Tables)

3 Months Ended

Mar. 31, 2016

Variable Interest Entities [Abstract]

Amounts relating to the VIEs included in Condensed Consolidated Balance Sheets

Our Condensed Consolidated Balance Sheets at March 31, 2016 and December 31, 2015 include the following amounts relating to the VIEs (in thousands):



	March 31, 2016		December 31, 2015
Palo Verde sale leaseback property plant and equipment, net of accumulated depreciation	$	116,418	$	117,385
Equity — Noncontrolling interests	140,414		135,540

Derivative Accounting (Tables)

3 Months Ended

Mar. 31, 2016

Derivative Instruments and Hedging Activities Disclosure [Abstract]

Outstanding gross notional amount of derivatives, which represents both purchases and sales (does not reflect net position)

As of March 31, 2016, we had the following outstanding gross notional volume of derivatives, which represent both purchases and sales (does not reflect net position):



Commodity	Quantity
Power	2,239	GWh
Gas	179	Billion cubic feet

Gains and losses from derivative instruments in designated cash flow accounting hedges relationships



	Financial Statement Location	Three Months Ended March 31,
Commodity Contracts	Financial Statement Location	2016			2015
Loss recognized in OCI on derivative instruments (effective portion)	OCI — derivative instruments	$	(147	)	$	(327	)
Loss reclassified from accumulated OCI into income (effective portion realized) (a)	Fuel and purchased power (b)	(941		)	(2,343		)


(a)	During the three months ended March 31, 2016 and 2015, we had no losses reclassified from accumulated OCI to earnings related to discontinued cash flow hedges.


(b)	Amounts are before the effect of PSA deferrals.

Gains and losses from derivative instruments not designated as accounting hedges instruments



	Financial Statement Location	Three Months Ended March 31,
Commodity Contracts	Financial Statement Location	2016			2015
Net loss recognized in income	Operating revenues	$	(102	)	$	(48	)
Net loss recognized in income	Fuel and purchased power (a)	(30,936		)	(44,803		)
Total		$	(31,038	)	$	(44,851	)


(a)	Amounts are before the effect of PSA deferrals.

Schedule of offsetting assets



As of March 31, 2016: (dollars in thousands)	Gross Recognized Derivatives (a)			Amounts Offset (b)			Net Recognized Derivatives			Other (c)			Amount Reported on Balance Sheet
Current assets	$	25,365		$	(9,268	)	$	16,097		$	(8	)	$	16,089
Investments and other assets	11,248			(2,636		)	8,612			—			8,612
Total assets	36,613			(11,904		)	24,709			(8		)	24,701

Current liabilities	(115,822		)	26,868			(88,954		)	(4,329		)	(93,283		)
Deferred credits and other	(88,239		)	2,636			(85,603		)	—			(85,603		)
Total liabilities	(204,061		)	29,504			(174,557		)	(4,329		)	(178,886		)
Total	$	(167,448	)	$	17,600		$	(149,848	)	$	(4,337	)	$	(154,185	)


(a)	All of our gross recognized derivative instruments were subject to master netting arrangements.


(b)	Includes cash collateral provided to counterparties of $17,600.


(c)	Represents cash collateral and cash margin that is not subject to offsetting. Amounts relate to non-derivative instruments, derivatives qualifying for scope exceptions, or collateral and margin posted in excess of the recognized derivative instrument. Includes cash collateral received from counterparties of $4,329, and cash margin provided to counterparties of $(8).



As of December 31, 2015: (dollars in thousands)	Gross Recognized Derivatives (a)			Amounts Offset (b)			Net Recognized Derivatives			Other (c)			Amount Reported on Balance Sheet
Current assets	$	37,396		$	(22,163	)	$	15,233		$	672		$	15,905
Investments and other assets	15,960			(3,854		)	12,106			—			12,106
Total assets	53,356			(26,017		)	27,339			672			28,011

Current liabilities	(113,560		)	40,223			(73,337		)	(4,379		)	(77,716		)
Deferred credits and other	(93,827		)	3,854			(89,973		)	—			(89,973		)
Total liabilities	(207,387		)	44,077			(163,310		)	(4,379		)	(167,689		)
Total	$	(154,031	)	$	18,060		$	(135,971	)	$	(3,707	)	$	(139,678	)


(a)	All of our gross recognized derivative instruments were subject to master netting arrangements.


(b)	Includes cash collateral provided to counterparties of $18,060.


(c)	Represents cash collateral and cash margin that is not subject to offsetting. Amounts relate to non-derivative instruments, derivatives qualifying for scope exceptions, or collateral and margin posted in excess of the recognized derivative instrument. Includes cash collateral received from counterparties of $4,379, and cash margin provided to counterparties of $672.

Schedule of offsetting liabilities



As of March 31, 2016: (dollars in thousands)	Gross Recognized Derivatives (a)			Amounts Offset (b)			Net Recognized Derivatives			Other (c)			Amount Reported on Balance Sheet
Current assets	$	25,365		$	(9,268	)	$	16,097		$	(8	)	$	16,089
Investments and other assets	11,248			(2,636		)	8,612			—			8,612
Total assets	36,613			(11,904		)	24,709			(8		)	24,701

Current liabilities	(115,822		)	26,868			(88,954		)	(4,329		)	(93,283		)
Deferred credits and other	(88,239		)	2,636			(85,603		)	—			(85,603		)
Total liabilities	(204,061		)	29,504			(174,557		)	(4,329		)	(178,886		)
Total	$	(167,448	)	$	17,600		$	(149,848	)	$	(4,337	)	$	(154,185	)


(a)	All of our gross recognized derivative instruments were subject to master netting arrangements.


(b)	Includes cash collateral provided to counterparties of $17,600.


(c)	Represents cash collateral and cash margin that is not subject to offsetting. Amounts relate to non-derivative instruments, derivatives qualifying for scope exceptions, or collateral and margin posted in excess of the recognized derivative instrument. Includes cash collateral received from counterparties of $4,329, and cash margin provided to counterparties of $(8).



As of December 31, 2015: (dollars in thousands)	Gross Recognized Derivatives (a)			Amounts Offset (b)			Net Recognized Derivatives			Other (c)			Amount Reported on Balance Sheet
Current assets	$	37,396		$	(22,163	)	$	15,233		$	672		$	15,905
Investments and other assets	15,960			(3,854		)	12,106			—			12,106
Total assets	53,356			(26,017		)	27,339			672			28,011

Current liabilities	(113,560		)	40,223			(73,337		)	(4,379		)	(77,716		)
Deferred credits and other	(93,827		)	3,854			(89,973		)	—			(89,973		)
Total liabilities	(207,387		)	44,077			(163,310		)	(4,379		)	(167,689		)
Total	$	(154,031	)	$	18,060		$	(135,971	)	$	(3,707	)	$	(139,678	)


(a)	All of our gross recognized derivative instruments were subject to master netting arrangements.


(b)	Includes cash collateral provided to counterparties of $18,060.


(c)	Represents cash collateral and cash margin that is not subject to offsetting. Amounts relate to non-derivative instruments, derivatives qualifying for scope exceptions, or collateral and margin posted in excess of the recognized derivative instrument. Includes cash collateral received from counterparties of $4,379, and cash margin provided to counterparties of $672.

Information about derivative instruments that have credit-risk-related contingent features

The following table provides information about our derivative instruments that have credit-risk-related contingent features at March 31, 2016 (dollars in thousands):



	March 31, 2016
Aggregate fair value of derivative instruments in a net liability position	$	204,061
Cash collateral posted	17,600
Additional cash collateral in the event credit-risk-related contingent features were fully triggered (a)	133,688


(a)	This amount is after counterparty netting and includes those contracts which qualify for scope exceptions, which are excluded from the derivative details above.

Other Income and Other Expense (Tables)

3 Months Ended

Mar. 31, 2016

Component of Other Income and Other Expense Nonoperating [Line Items]

Detail of other income and other expense

The following table provides detail of Pinnacle West's Consolidated other income and other expense for the three months ended March 31, 2016 and 2015 (dollars in thousands):



	Three Months Ended March 31,
	2016			2015
Other income:
Interest income	$	117		$	110
Miscellaneous	—			125
Total other income	$	117		$	235
Other expense:
Non-operating costs	$	(2,049	)	$	(2,249	)
Investment losses — net	(518		)	(495		)
Miscellaneous	(1,471		)	(1,542		)
Total other expense	$	(4,038	)	$	(4,286	)

Arizona Public Service Company

Component of Other Income and Other Expense Nonoperating [Line Items]

Detail of other income and other expense

The following table provides detail of APS’s other income and other expense for the three months ended March 31, 2016 and 2015 (dollars in thousands):



	Three Months Ended March 31,
	2016			2015
Other income:
Interest income	$	73		$	67
Gain on disposition of property	332			207
Miscellaneous	205			365
Total other income	$	610		$	639
Other expense:
Non-operating costs (a)	$	(1,966	)	$	(2,517	)
Loss on disposition of property	(426		)	(643		)
Miscellaneous	(2,358		)	(2,194		)
Total other expense	$	(4,750	)	$	(5,354	)

(a) As defined by FERC, includes below-the-line non-operating utility expense (items excluded from utility rate recovery).

Earnings Per Share (Tables)

3 Months Ended

Mar. 31, 2016

Earnings Per Share [Abstract]

Schedule of earnings per weighted average common share outstanding

The following table presents the calculation of Pinnacle West’s basic and diluted earnings per share for the three months ended March 31, 2016 and 2015 (in thousands, except per share amounts):



	Three Months Ended March 31,
	2016		2015
Net income attributable to common shareholders	$	4,453	$	16,122
Weighted average common shares outstanding — basic	111,296		110,916
Net effect of dilutive securities:
Contingently issuable performance shares and restricted stock units	551		461
Weighted average common shares outstanding — diluted	111,847		111,377
Earnings per weighted-average common share outstanding
Net income attributable to common shareholders — basic	$	0.04	$	0.15
Net income attributable to common shareholders — diluted	$	0.04	$	0.14

Fair Value Measurements (Tables)

3 Months Ended

Mar. 31, 2016

Fair Value Disclosures [Abstract]

Fair value of assets and liabilities that are measured at fair value on a recurring basis

The following table presents the fair value at March 31, 2016, of our assets and liabilities that are measured at fair value on a recurring basis (dollars in thousands):



	Quoted Prices in Active Markets for Identical Assets (Level 1)		Significant Other Observable Inputs (Level 2)			Significant Unobservable Inputs (a) (Level 3)			Other				Balance at March 31, 2016
Assets
Risk management activities — derivative instruments:
Commodity contracts	$	—	$	12,613		$	23,847		$	(11,759	)	(b)	$	24,701
Nuclear decommissioning trust:
U.S. commingled equity funds	—		—			—			319,971			(c)	319,971
Fixed income securities:
Cash and cash equivalent funds	11,535		—			—			(1,898		)	(d)	9,637
U.S. Treasury	107,698		—			—			—				107,698
Corporate debt	—		101,687			—			—				101,687
Mortgage-backed securities	—		109,298			—			—				109,298
Municipal bonds	—		80,344			—			—				80,344
Other	—		23,319			—			—				23,319
Subtotal nuclear decommissioning trust	119,233		314,648			—			318,073				751,954
Total	$	119,233	$	327,261		$	23,847		$	306,314			$	776,655
Liabilities
Risk management activities — derivative instruments:
Commodity contracts	$	—	$	(140,554	)	$	(63,354	)	$	25,022		(b)	$	(178,886	)


(a)	Primarily consists of heat rate options and other long-dated electricity contracts.


(b)	Represents counterparty netting, margin and collateral. See Note 6.


(c)	Valued using NAV as a practical expedient, and therefore not classified in the fair value hierarchy.


(d)	Represents nuclear decommissioning trust net pending securities sales and purchases.

The following table presents the fair value at December 31, 2015, of our assets and liabilities that are measured at fair value on a recurring basis (dollars in thousands):



	Quoted Prices in Active Markets for Identical Assets (Level 1)		Significant Other Observable Inputs (Level 2)			Significant Unobservable Inputs (a) (Level 3)			Other				Balance at December 31, 2015
Assets
Risk management activities — derivative instruments:
Commodity contracts	$	—	$	22,992		$	30,364		$	(25,345	)	(b)	$	28,011
Nuclear decommissioning trust:
U.S. commingled equity funds	—		—			—			314,957			(c)	314,957
Fixed income securities:
Cash and cash equivalent funds	12,260		—			—			(335		)	(d)	11,925
U.S. Treasury	117,245		—			—			—				117,245
Corporate debt	—		96,243			—			—				96,243
Mortgage-backed securities	—		99,065			—			—				99,065
Municipal bonds	—		72,206			—			—				72,206
Other	—		23,555			—			—				23,555
Subtotal nuclear decommissioning trust	129,505		291,069			—			314,622				735,196
Total	$	129,505	$	314,061		$	30,364		$	289,277			$	763,207
Liabilities
Risk management activities — derivative instruments:
Commodity contracts	$	—	$	(144,044	)	$	(63,343	)	$	39,698		(b)	$	(167,689	)


(a)	Primarily consists of heat rate options and other long-dated electricity contracts.


(b)	Represents counterparty netting, margin and collateral. See Note 6.


(c)	Valued using NAV as a practical expedient, and therefore not classified in the fair value hierarchy.


(d)	Represents nuclear decommissioning trust net pending securities sales and purchases

Information regarding the entity's internally developed significant unobservable inputs used to value its level 3 instruments

The following tables provide information regarding our significant unobservable inputs used to value our risk management derivative Level 3 instruments at March 31, 2016 and December 31, 2015:



	March 31, 2016 Fair Value (thousands)				Valuation Technique	Significant Unobservable Input		Weighted-Average
Commodity Contracts	Assets		Liabilities		Valuation Technique	Significant Unobservable Input	Range	Weighted-Average
Electricity:
Forward Contracts (a)	$	21,606	$	51,305	Discounted cash flows	Electricity forward price (per MWh)	$13.97 - $39.61	$	26.45
Option Contracts (b)	—		5,880		Option model	Electricity forward price (per MWh)	$19.46 - $37.93	$	29.39
						Electricity price volatilities	47% - 72%	63		%
						Natural gas price volatilities	38% - 45%	41		%
Natural Gas:
Forward Contracts (a)	2,241		6,169		Discounted cash flows	Natural gas forward price (per MMBtu)	$1.65 - $3.11	$	2.67
Total	$	23,847	$	63,354


(a)	Includes swaps and physical and financial contracts.


(b)	Electricity and natural gas price volatilities are estimated based on historical forward price movements due to lack of market quotes for implied volatilities.



	December 31, 2015 Fair Value (thousands)				Valuation Technique	Significant Unobservable Input		Weighted-Average
Commodity Contracts	Assets		Liabilities		Valuation Technique	Significant Unobservable Input	Range	Weighted-Average
Electricity:
Forward Contracts (a)	$	24,543	$	54,679	Discounted cash flows	Electricity forward price (per MWh)	$15.92 - $40.73	$	26.86
Option Contracts (b)	—		5,628		Option model	Electricity forward price (per MWh)	$23.87 - $44.13	$	33.91
						Electricity price volatilities	40% - 59%	52		%
						Natural gas price volatilities	32% - 40%	35		%
Natural Gas:
Forward Contracts (a)	5,821		3,036		Discounted cash flows	Natural gas forward price (per MMBtu)	$2.18 - $3.14	$	2.61
Total	$	30,364	$	63,343


(a)	Includes swaps and physical and financial contracts.


(b)	Electricity and natural gas price volatilities are estimated based on historical forward price movements due to lack of market quotes for implied volatilities

Changes in fair value for assets and liabilities that are measured at fair value on a recurring basis using Level 3 inputs



	Three Months Ended March 31,
Commodity Contracts	2016			2015
Net derivative balance at beginning of period	$	(32,979	)	$	(41,386	)
Total net gains (losses) realized/unrealized:
Included in OCI	—			(262		)
Deferred as a regulatory asset or liability	(9,103		)	(10,747		)
Settlements	1,765			310
Transfers into Level 3 from Level 2	262			(402		)
Transfers from Level 3 into Level 2	548			3,673
Net derivative balance at end of period	$	(39,507	)	$	(48,814	)

Net unrealized gains included in earnings related to instruments still held at end of period	$	—		$	—

Nuclear Decommissioning Trusts (Tables)

3 Months Ended

Mar. 31, 2016

Investments, Debt and Equity Securities [Abstract]

Fair value of APS's nuclear decommissioning trust fund assets

The following table includes the unrealized gains and losses based on the original cost of the investment and summarizes the fair value of APS’s nuclear decommissioning trust fund assets at March 31, 2016 and December 31, 2015 (dollars in thousands):



	Fair Value			Total Unrealized Gains		Total Unrealized Losses
March 31, 2016
Equity securities	$	319,971		$	159,790	$	(65	)
Fixed income securities	433,881			18,250		(676		)
Net payables (a)	(1,898		)	—		—
Total	$	751,954		$	178,040	$	(741	)



	Fair Value			Total Unrealized Gains		Total Unrealized Losses
December 31, 2015
Equity securities	$	314,957		$	157,098	$	(115	)
Fixed income securities	420,574			11,955		(2,645		)
Net payables (a)	(335		)	—		—
Total	$	735,196		$	169,053	$	(2,760	)


(a)	Net payables relate to pending purchases and sales of securities.

Realized gains and losses and proceeds from the sale of securities by the nuclear decommissioning trust funds

The following table sets forth approximate gains and losses and proceeds from the sale of securities by the nuclear decommissioning trust funds (dollars in thousands):



	Three Months Ended March 31,
	2016			2015
Realized gains	$	2,438		$	1,195
Realized losses	(1,786		)	(525		)
Proceeds from the sale of securities (a)	141,809			115,282


(a)	Proceeds are reinvested in the trust.

Fair value of fixed income securities, summarized by contractual maturities

The fair value of fixed income securities, summarized by contractual maturities, at March 31, 2016 is as follows (dollars in thousands):



	Fair Value
Less than one year	$	11,633
1 year – 5 years	126,221
5 years – 10 years	101,773
Greater than 10 years	194,254
Total	$	433,881

Changes in Accumulated Other Comprehensive Loss (Tables)

3 Months Ended

Mar. 31, 2016

Accumulated Other Comprehensive Income (Loss) [Line Items]

Schedule of changes in accumulated other comprehensive loss including reclassification adjustments, net of tax, by component



	Three Months Ended
	March 31,
	2016			2015
Balance at beginning of period	$	(44,748	)	$	(68,141	)
Derivative Instruments
OCI (loss) before reclassifications	(693		)	(800		)
Amounts reclassified from accumulated other comprehensive loss (a)	1,141			1,976
Net current period OCI (loss)	448			1,176
Pension and Other Postretirement Benefits
Amounts reclassified from accumulated other comprehensive loss (b)	530			583
Net current period OCI (loss)	530			583
Balance at end of period	$	(43,770	)	$	(66,382	)


(a)	These amounts represent realized gains and losses and are included in the computation of fuel and purchased power costs and are subject to the PSA. See Note 6.


(b)	These amounts primarily represent amortization of actuarial loss, and are included in the computation of net periodic pension cost. See Note 4.

Arizona Public Service Company

Accumulated Other Comprehensive Income (Loss) [Line Items]

Schedule of changes in accumulated other comprehensive loss including reclassification adjustments, net of tax, by component



	Three Months Ended
	March 31,
	2016			2015
Balance at beginning of period	$	(27,097	)	$	(48,333	)
Derivative Instruments
OCI (loss) before reclassifications	(693		)	(800		)
Amounts reclassified from accumulated other comprehensive loss (a)	1,141			1,976
Net current period OCI (loss)	448			1,176
Pension and Other Postretirement Benefits
Amounts reclassified from accumulated other comprehensive loss (b)	611			681
Net current period OCI (loss)	611			681
Balance at end of period	$	(26,038	)	$	(46,476	)


(a)	These amounts represent realized gains and losses and are included in the computation of fuel and purchased power costs and are subject to the PSA. See Note 6.


(b)	These amounts primarily represent amortization of actuarial loss and are included in the computation of net periodic pension cost. See Note 4.

Consolidation and Nature of Operations (Details) - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2016	Mar. 31, 2015
Cash paid during the period for:
Income taxes, net of refunds	$ 2,502	$ 1,832
Interest, net of amounts capitalized	56,139	53,555
Significant non-cash investing and financing activities:
Accrued capital expenditures	$ 59,707	$ 56,165

Long-Term Debt and Liquidity Matters - Narrative (Details)	Apr. 22, 2016 USD ($)	Mar. 31, 2016 USD ($) Facility	Dec. 31, 2015 USD ($)
Debt Provisions
Total shareholder equity		$ 4,599,999,000	$ 4,583,917,000
Pinnacle West \| Revolving Credit Facility \| Revolving credit facility maturing in May 2019
Long-Term Debt and Liquidity Matters
Current borrowing capacity on credit facility		200,000,000
Maximum borrowing capacity on credit facility upon satisfaction of certain conditions and consent of lenders (up to)		300,000,000
Outstanding borrowings		0
Pinnacle West \| Letter of Credit \| Revolving credit facility maturing in May 2019
Long-Term Debt and Liquidity Matters
Outstanding letters of credit		0
Pinnacle West \| Commercial paper \| Revolving credit facility maturing in May 2019
Long-Term Debt and Liquidity Matters
Commercial paper		0
APS
Debt Provisions
Total shareholder equity		4,687,566,000	4,679,254,000
APS \| ACC
Debt Provisions
Total shareholder equity		4,700,000,000
Total capitalization		8,600,000,000
Dividend restrictions, shareholder equity required		$ 3,400,000,000
APS \| ACC \| Minimum
Debt Provisions
Required common equity ratio ordered by ACC (as a percent) (at least)		40.00%
APS \| Revolving Credit Facility \| Revolving Credit Facilities Maturing in 2020 and 2019
Long-Term Debt and Liquidity Matters
Current borrowing capacity on credit facility		$ 1,000,000,000
Maximum borrowing capacity on credit facility upon satisfaction of certain conditions and consent of lenders (up to)		1,400,000,000
Outstanding borrowings		$ 0
Number of line of credit facilities \| Facility		2
APS \| Revolving Credit Facility \| Revolving credit facility maturing September 2020
Long-Term Debt and Liquidity Matters
Current borrowing capacity on credit facility		$ 500,000,000
Maximum borrowing capacity on credit facility upon satisfaction of certain conditions and consent of lenders (up to)		700,000,000
APS \| Revolving Credit Facility \| Revolving credit facility maturing in May 2019
Long-Term Debt and Liquidity Matters
Current borrowing capacity on credit facility		500,000,000
Maximum borrowing capacity on credit facility upon satisfaction of certain conditions and consent of lenders (up to)		700,000,000
APS \| Letter of Credit
Long-Term Debt and Liquidity Matters
Outstanding letters of credit		79,000,000
APS \| Commercial paper
Long-Term Debt and Liquidity Matters
Maximum commercial paper support available under credit facility		500,000,000	$ 250,000,000
APS \| Commercial paper \| Revolving Credit Facilities Maturing in 2020 and 2019
Long-Term Debt and Liquidity Matters
Commercial paper		$ 261,800,000
Subsequent Event \| APS \| Secured debt \| Term loan facility maturing April 22, 2019
Long-Term Debt and Liquidity Matters
Debt issued	$ 100,000,000

Long-Term Debt and Liquidity Matters - Estimated Fair Value of Long-Term Debt (Details) - USD ($) $ in Thousands	Mar. 31, 2016	Dec. 31, 2015
Estimated fair value of long-term debt, including current maturities
Carrying Amount	$ 3,820,612	$ 3,819,971
Fair Value	4,261,022	4,106,367
Pinnacle West
Estimated fair value of long-term debt, including current maturities
Carrying Amount	125,000	125,000
Fair Value	125,000	125,000
Arizona Public Service Company
Estimated fair value of long-term debt, including current maturities
Carrying Amount	3,695,612	3,694,971
Fair Value	$ 4,136,022	$ 3,981,367

Regulatory Matters (Details) signature in Thousands											2 Months Ended	3 Months Ended			12 Months Ended
Regulatory Matters (Details) signature in Thousands	Apr. 15, 2016 signature	Feb. 01, 2016 $ / kWh	Jan. 15, 2016 USD ($)	Jun. 01, 2015 USD ($)	Mar. 02, 2015 USD ($)	Apr. 15, 2014 Customer MW	Mar. 01, 2014 USD ($)	Jan. 01, 2014 USD ($) $ / kWh	Jan. 06, 2012 USD ($) $ / kWh	Jun. 01, 2011 USD ($)	Apr. 30, 2014 workshop	Mar. 31, 2016 USD ($) $ / kWh	Jan. 31, 2016 $ / kWh	Mar. 31, 2015 USD ($)	Dec. 31, 2015 USD ($) $ / kWh	Apr. 01, 2016 USD ($)	Jan. 12, 2016 USD ($)	Nov. 25, 2015 USD ($)	Mar. 20, 2015 project	Dec. 31, 2014 USD ($)	Dec. 19, 2014 MW	Jul. 01, 2014 USD ($)
Change in regulatory asset
Deferred fuel and purchased power costs — current period												$ (1,007,000)		$ (17,671,000)
Amounts charged to customers												(2,388,000)		(5,614,000)
APS
Change in regulatory asset
Deferred fuel and purchased power costs — current period												(1,007,000)		(17,671,000)
Amounts charged to customers												$ (2,388,000)		(5,614,000)
APS \| Filing with the Arizona Corporation Commission \| ACC \| Retail rate case filing
Public Utilities, General Disclosures [Line Items]
Net retail rate increase										$ 95,500,000
Approximate percentage of increase in the average retail customer bill										6.60%
Settlement Agreement
Net change in base rates									$ 0
Non-fuel base rate increase									116,300,000
Fuel-related base rate decrease									$ 153,100,000
Current base fuel rate (in dollars per kWh) \| $ / kWh									0.03757
Approved base fuel rate (in dollars per kWh) \| $ / kWh									0.03207
Estimated amount of transfer of cost recovery for certain renewable energy projects from the RES surcharge to base rates									$ 36,800,000
Authorized return on common equity (as a percent)									10.00%
Percentage of debt in capital structure									46.10%
Percentage of common equity in capital structure									53.90%
Deferral of property taxes in 2012, if Arizona property tax rates increase (as a percent)									25.00%
Deferral of property taxes in 2013, if Arizona property tax rates increase (as a percent)									50.00%
Deferral of property taxes for 2014 and subsequent years, if Arizona property tax rates increase (as a percent)									75.00%
Deferral of property taxes in all years, if Arizona property tax rates decrease (as a percent)									100.00%
Elimination of the sharing provision of fuel and purchased power costs									9
Period to process the subsequent rate cases									12 months
ACC staff sufficiency findings, general period of time									30 days
APS \| Filing with the Arizona Corporation Commission \| ACC \| Retail rate case filing \| Maximum
Settlement Agreement
Annual cost recovery due to modifications to the Environmental Improvement Surcharge									$ 5,000,000
APS \| RES \| Cost Recovery Mechanisms \| ACC
Settlement Agreement
Plan term												5 years
APS \| 2014 RES \| AZ Sun Program \| Filing with the Arizona Corporation Commission
Settlement Agreement
Request to build additional utility scale solar, capacity \| MW						20
APS \| 2014 RES \| Alternative to AZ Sun Program \| Filing with the Arizona Corporation Commission
Settlement Agreement
Request to build additional utility scale solar, capacity \| MW						10
Additional capacity from APS-owned non AZ Sun projects, impacted customers \| Customer						1,500
APS \| 2014 RES \| Alternative to AZ Sun Program, Phase 1 \| Filing with the Arizona Corporation Commission
Settlement Agreement
Request to build additional utility scale solar, capacity \| MW																					8
APS \| 2014 RES \| Alternative to AZ Sun Program Phase 2 \| Filing with the Arizona Corporation Commission
Settlement Agreement
Request to build additional utility scale solar, capacity \| MW																					2
APS \| 2015 RES \| Cost Recovery Mechanisms \| ACC
Settlement Agreement
Amount of proposed budget																						$ 154,000,000
Amount of approved budget																				$ 152,000,000
APS \| 2016 RES \| Cost Recovery Mechanisms \| ACC
Settlement Agreement
Amount of approved budget																	$ 148,000,000
APS \| 2015 DSMAC \| Cost Recovery Mechanisms \| ACC
Settlement Agreement
Amount of approved budget																		$ 68,900,000
Number of resource savings projects \| project																			3
APS \| 2016 DSMAC \| Cost Recovery Mechanisms \| ACC
Settlement Agreement
Amount of proposed budget				$ 68,900,000
APS \| Electric energy efficiency standard \| ACC
Settlement Agreement
Number of workshops \| workshop											3
APS \| Power Supply Adjustor (PSA) \| Cost Recovery Mechanisms \| ACC
Change in regulatory asset
Beginning balance												$ (9,688,000)		6,925,000	$ 6,925,000
Deferred fuel and purchased power costs — current period												(1,007,000)		(17,671,000)
Amounts charged to customers												(2,388,000)		(5,614,000)
Ending balance												$ (13,083,000)		$ (16,360,000)	$ (9,688,000)
PSA rate (in dollars per kWh) \| $ / kWh		0.001678
PSA rate for prior year (in dollars per kWh) \| $ / kWh															0.000887
Forward component of increase in PSA (in dollars per kWh) \| $ / kWh		0.001975
Historical component of increase in PSA (in dollars per kWh) \| $ / kWh		(0.000297)
Transition component increase in PSA (in dollars per kWh) \| $ / kWh													(0.004936)
APS \| Transmission Rates, Transmission Cost Adjustor and Other Transmission Matters \| Cost Recovery Mechanisms \| FERC
Change in regulatory asset
Increase in annual wholesale transmission rates				$ 17,600,000
APS \| Lost Fixed Cost Recovery Mechanism
Change in regulatory asset
Percentage of retail revenues												1.00%
APS \| Lost Fixed Cost Recovery Mechanism \| Cost Recovery Mechanisms
Change in regulatory asset
Fixed costs recoverable per residential power lost (in dollars per kWh) \| $ / kWh												0.031
Fixed costs recoverable per non-residential power lost (in dollars per kWh) \| $ / kWh												0.023
Amount of adjustment representing prorated sales losses approval					$ 38,500,000		$ 25,300,000
Amount of adjustment representing prorated sales losses pending approval			$ 46,400,000
Increase in amount of adjustment representing prorated sales losses			$ 7,900,000
APS \| Net Metering \| ACC
Change in regulatory asset
Charge on future customers who install rooftop solar panels (in dollars per kWh) \| $ / kWh								0.70				0.70
Estimated monthly collection due to charge on future customers who install rooftop solar panels								$ 4.90
Subsequent Event \| APS \| 2015 DSMAC \| Cost Recovery Mechanisms \| ACC
Settlement Agreement
Amount of proposed budget																$ 68,900,000
Subsequent Event \| APS \| Net Metering \| Arizona Secretary of State
Change in regulatory asset
Rate benefits preservation initiative, number of signatures required \| signature	225

Regulatory Matters - Four Corners and Cholla (Details) - APS - USD ($) $ in Millions			3 Months Ended
	Dec. 23, 2014	Dec. 30, 2013	Mar. 31, 2016	Dec. 31, 2015
SCE \| Four Corners Units 4 and 5
Business Acquisition [Line Items]
Ownership interest acquired		48.00%
Settlement agreement, ACC approved rate adjustment, annualized customer impact	$ 57.1
Net receipt due to negotiation of alternate arrangement		$ 40.0
Four Corners cost deferral (b) \| SCE \| Four Corners Units 4 and 5
Business Acquisition [Line Items]
Regulatory assets, non-current			$ 69.0
Regulatory noncurrent asset amortization period			10 years
Retired power plant costs
Business Acquisition [Line Items]
Net book value			$ 121.0
Four Corners \| SCE
Business Acquisition [Line Items]
Regulatory assets, non-current				$ 12.0

Regulatory Matters - Schedule of Regulatory Assets (Details) - USD ($) $ in Thousands	Mar. 31, 2016	Dec. 31, 2015
Detail of regulatory assets
Regulatory assets, current	$ 168,753	$ 149,555
Regulatory assets, non-current	1,203,474	1,214,146
Pension
Detail of regulatory assets
Regulatory assets, current	0	0
Regulatory assets, non-current	610,569	619,223
Retired power plant costs
Detail of regulatory assets
Regulatory assets, current	9,913	9,913
Regulatory assets, non-current	125,037	127,518
Income taxes — allowance for funds used during construction (AFUDC) equity
Detail of regulatory assets
Regulatory assets, current	5,419	5,495
Regulatory assets, non-current	132,149	133,712
Deferred fuel and purchased power — mark-to-market (Note 6)
Detail of regulatory assets
Regulatory assets, current	86,160	71,852
Regulatory assets, non-current	69,708	69,697
Four Corners cost deferral (b)
Detail of regulatory assets
Regulatory assets, current	6,689	6,689
Regulatory assets, non-current	61,910	63,582
Income taxes — investment tax credit basis adjustment
Detail of regulatory assets
Regulatory assets, current	1,852	1,766
Regulatory assets, non-current	48,347	48,462
Lost fixed cost recovery (b)
Detail of regulatory assets
Regulatory assets, current	48,702	45,507
Regulatory assets, non-current	0	0
Palo Verde VIEs (Note 5)
Detail of regulatory assets
Regulatory assets, current	0	0
Regulatory assets, non-current	18,311	18,143
Deferred compensation
Detail of regulatory assets
Regulatory assets, current	0	0
Regulatory assets, non-current	35,871	34,751
Deferred property taxes
Detail of regulatory assets
Regulatory assets, current	0	0
Regulatory assets, non-current	56,589	50,453
Loss on reacquired debt
Detail of regulatory assets
Regulatory assets, current	1,515	1,515
Regulatory assets, non-current	15,996	16,375
Tax expense of Medicare subsidy
Detail of regulatory assets
Regulatory assets, current	1,512	1,520
Regulatory assets, non-current	12,073	12,163
Transmission vegetation management
Detail of regulatory assets
Regulatory assets, current	2,272	4,543
Regulatory assets, non-current	0	0
Mead-Phoenix transmission line CIAC
Detail of regulatory assets
Regulatory assets, current	332	332
Regulatory assets, non-current	10,957	11,040
Transmission cost adjustor (b)
Detail of regulatory assets
Regulatory assets, current	3,969	0
Regulatory assets, non-current	462	2,942
Coal reclamation
Detail of regulatory assets
Regulatory assets, current	418	418
Regulatory assets, non-current	5,495	6,085
Other
Detail of regulatory assets
Regulatory assets, current	0	5
Regulatory assets, non-current	$ 0	$ 0

Regulatory Matters - Schedule of Regulatory Liabilities (Details) - USD ($) $ in Thousands	Mar. 31, 2016	Dec. 31, 2015
Detail of regulatory liabilities
Regulatory liabilities, current	$ 135,554	$ 145,766
Regulatory liabilities, non-current	1,009,418	994,152
Asset retirement obligations
Detail of regulatory liabilities
Regulatory liabilities, current	0	0
Regulatory liabilities, non-current	289,485	277,554
Removal costs
Detail of regulatory liabilities
Regulatory liabilities, current	32,473	39,746
Regulatory liabilities, non-current	244,724	240,367
Other postretirement benefits
Detail of regulatory liabilities
Regulatory liabilities, current	34,100	34,100
Regulatory liabilities, non-current	171,029	179,521
Income taxes — deferred investment tax credit
Detail of regulatory liabilities
Regulatory liabilities, current	3,774	3,604
Regulatory liabilities, non-current	96,940	97,175
Income taxes — change in rates
Detail of regulatory liabilities
Regulatory liabilities, current	1,771	1,113
Regulatory liabilities, non-current	71,756	72,454
Spent nuclear fuel
Detail of regulatory liabilities
Regulatory liabilities, current	31	3,051
Regulatory liabilities, non-current	71,235	67,437
Renewable energy standard (b)
Detail of regulatory liabilities
Regulatory liabilities, current	41,518	43,773
Regulatory liabilities, non-current	3,274	4,365
Demand side management (b)
Detail of regulatory liabilities
Regulatory liabilities, current	6,628	6,079
Regulatory liabilities, non-current	19,115	19,115
Sundance maintenance
Detail of regulatory liabilities
Regulatory liabilities, current	0	0
Regulatory liabilities, non-current	14,080	13,678
Deferred fuel and purchased power (b) (c)
Detail of regulatory liabilities
Regulatory liabilities, current	13,083	9,688
Regulatory liabilities, non-current	0	0
Deferred gains on utility property
Detail of regulatory liabilities
Regulatory liabilities, current	2,062	2,062
Regulatory liabilities, non-current	5,501	6,001
Four Corners coal reclamation
Detail of regulatory liabilities
Regulatory liabilities, current	0	0
Regulatory liabilities, non-current	14,725	8,920
Other
Detail of regulatory liabilities
Regulatory liabilities, current	114	2,550
Regulatory liabilities, non-current	$ 7,554	$ 7,565

Retirement Plans and Other Postretirement Benefits - Narrative (Details) - USD ($)		1 Months Ended	3 Months Ended
	Sep. 30, 2014	Jul. 31, 2012	Mar. 31, 2016	Mar. 31, 2015
Regulatory Assets
Regulatory asset amortization period		3 years
Amortization of regulatory asset				$ 2,000,000
Pension Benefits
Contributions
Voluntary employer contributions to pension plan			$ 60,000,000
Minimum employer contributions for the next three years			0
Maximum employer contributions for the next two years (up to)			300,000,000
Other Benefits
Other Postretirement Benefit Plan Remeasurement
Other postretirement plan benefit remeasurement, amount seeking approval to move to separate account to Pay Union employee medical costs	$ 140,000,000
Contributions
2016 (up to)			1,000,000
2017 (up to)			1,000,000
2015			$ 1,000,000

Retirement Plans and Other Postretirement Benefits - Schedule of Net Benefit Cost (Details) - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2016	Mar. 31, 2015
Pension Benefits
Retirement Plans and Other Benefits
Service cost — benefits earned during the period	$ 14,266	$ 15,824
Interest cost on benefit obligation	32,945	31,189
Expected return on plan assets	(43,792)	(45,149)
Amortization of:
Prior service cost	132	149
Net actuarial loss	9,731	7,761
Net periodic benefit cost	13,282	9,774
Portion of cost charged to expense	6,519	5,987
Other postretirement benefits
Retirement Plans and Other Benefits
Service cost — benefits earned during the period	3,937	4,346
Interest cost on benefit obligation	7,341	7,184
Expected return on plan assets	(9,122)	(9,147)
Amortization of:
Prior service cost	(9,471)	(9,492)
Net actuarial loss	946	1,561
Net periodic benefit cost	(6,369)	(5,548)
Portion of cost charged to expense	$ (3,126)	$ (1,788)

Palo Verde Sale Leaseback Variable Interest Entities - Narrative (Details) $ in Thousands	3 Months Ended
	Mar. 31, 2016 USD ($) power_plant Lease	Mar. 31, 2015 USD ($)	Dec. 31, 1986 Trust
Palo Verde Sale Leaseback Variable Interest Entities
Increase in net income due to consolidation of Palo Verde Sale Leaseback Trusts	$ 4,873	$ 4,605
Arizona Public Service Company
Palo Verde Sale Leaseback Variable Interest Entities
Number of VIE lessor trusts	3		3
Increase in net income due to consolidation of Palo Verde Sale Leaseback Trusts	$ 4,873	4,605
Arizona Public Service Company \| Consolidation of VIEs
Palo Verde Sale Leaseback Variable Interest Entities
Increase in net income due to consolidation of Palo Verde Sale Leaseback Trusts	5,000	$ 5,000
Initial loss exposure to the VIE's noncontrolling equity participants during lease extension period	288,000
Maximum loss exposure to the VIE's noncontrolling equity participants during lease extension period	$ 456,000
Arizona Public Service Company \| Consolidation of VIEs \| Through 2023
Palo Verde Sale Leaseback Variable Interest Entities
Number of leases under which assets are retained \| Lease	1
Arizona Public Service Company \| Consolidation of VIEs \| Through 2033
Palo Verde Sale Leaseback Variable Interest Entities
Number of leases under which assets are retained \| Lease	2
Arizona Public Service Company \| Consolidation of VIEs \| Period 2016 through 2023
Palo Verde Sale Leaseback Variable Interest Entities
Annual lease payments	$ 23,000
Arizona Public Service Company \| Consolidation of VIEs \| Period 2024 through 2033
Palo Verde Sale Leaseback Variable Interest Entities
Annual lease payments	$ 16,000
Arizona Public Service Company \| Consolidation of VIEs \| Period 2024 through 2033 \| Maximum
Palo Verde Sale Leaseback Variable Interest Entities
Lease period (up to)	2 years

Palo Verde Sale Leaseback Variable Interest Entities - Schedule of VIEs (Details) - USD ($) $ in Thousands	Mar. 31, 2016	Dec. 31, 2015
Amounts relating to the VIEs included in Condensed Consolidated Balance Sheets
Palo Verde sale leaseback property plant and equipment, net of accumulated depreciation	$ 116,418	$ 117,385
Equity — Noncontrolling interests	140,414	135,540
Arizona Public Service Company
Amounts relating to the VIEs included in Condensed Consolidated Balance Sheets
Palo Verde sale leaseback property plant and equipment, net of accumulated depreciation	116,418	117,385
Equity — Noncontrolling interests	140,414	135,540
Arizona Public Service Company \| Consolidation of VIEs
Amounts relating to the VIEs included in Condensed Consolidated Balance Sheets
Palo Verde sale leaseback property plant and equipment, net of accumulated depreciation	116,418	117,385
Equity — Noncontrolling interests	$ 140,414	$ 135,540

Derivative Accounting - Narrative (Details) $ in Thousands	3 Months Ended
Derivative Accounting - Narrative (Details) $ in Thousands	Mar. 31, 2016 USD ($) Counterparty	Dec. 31, 2015 USD ($)
Designated as Hedging Instruments
Derivative Accounting
Gross recognized derivatives	$ 3,000	$ 3,000
Commodity Contracts
Derivative Accounting
Gross recognized derivatives	$ 204,061	207,387
Concentration of credit risk, number of counterparties \| Counterparty	1
Concentration of risk with two counterparties, as a percentage of risk management assets	87.00%
Risk management activities-derivative instruments: Commodity Contracts	$ 24,701	$ 28,011
Additional collateral to counterparties for energy related non-derivative instrument contracts	153,000
Commodity Contracts \| Designated as Hedging Instruments
Derivative Accounting
Estimated net gain (loss) before income taxes to be reclassified from accumulated other comprehensive income	$ (4,000)
Arizona Public Service Company
Derivative Accounting
Percentage of unrealized gains and losses on certain derivatives deferred for future rate treatment	100.00%

Derivative Accounting - Schedule of Gross Notional Amounts Outstanding (Details) - Commodity Contracts MMcf in Thousands	3 Months Ended
	Mar. 31, 2016 GWh MMcf
Outstanding gross notional amount of derivatives
Power \| GWh	2,239
Gas \| MMcf	179

Derivative Accounting - Gains and Losses from Derivative Instruments (Details) - Commodity Contracts - USD ($)	3 Months Ended
	Mar. 31, 2016	Mar. 31, 2015
Designated as Hedging Instruments
Gains and losses from derivative instruments
Amount reclassified from accumulated other comprehensive income to earnings related to discontinued cash flow hedges	$ 0	$ 0
Designated as Hedging Instruments \| Fuel and purchased power
Gains and losses from derivative instruments
Loss reclassified from accumulated OCI into income (effective portion realized)	(941,000)	(2,343,000)
Not Designated as Hedging Instruments
Gains and losses from derivative instruments
Net loss recognized in income	(31,038,000)	(44,851,000)
Not Designated as Hedging Instruments \| Revenue
Gains and losses from derivative instruments
Net loss recognized in income	(102,000)	(48,000)
Not Designated as Hedging Instruments \| Fuel and purchased power
Gains and losses from derivative instruments
Net loss recognized in income	(30,936,000)	(44,803,000)
Other comprehensive income \| Designated as Hedging Instruments
Gains and losses from derivative instruments
Loss recognized in OCI on derivative instruments (effective portion)	$ (147,000)	$ (327,000)

Derivative Accounting - Derivative Instruments in the Balance Sheets (Details) - Commodity Contracts - USD ($) $ in Thousands	Mar. 31, 2016	Dec. 31, 2015
Assets
Gross Recognized Derivatives	$ 36,613	$ 53,356
Amounts Offset	(11,904)	(26,017)
Net Recognized Derivatives	24,709	27,339
Other	(8)	672
Amount Reported on Balance Sheet	24,701	28,011
Liabilities
Gross Recognized Derivatives	(204,061)	(207,387)
Amounts Offset	29,504	44,077
Net Recognized Derivatives	(174,557)	(163,310)
Other	(4,329)	(4,379)
Amount Reported on Balance Sheet	(178,886)	(167,689)
Assets and Liabilities
Gross Recognized Derivatives	(167,448)	(154,031)
Amounts Offset	17,600	18,060
Net Recognized Derivatives	(149,848)	(135,971)
Other	(4,337)	(3,707)
Amount Reported on Balance Sheet	(154,185)	(139,678)
Current Assets
Assets
Gross Recognized Derivatives	25,365	37,396
Amounts Offset	(9,268)	(22,163)
Net Recognized Derivatives	16,097	15,233
Other	(8)	672
Amount Reported on Balance Sheet	16,089	15,905
Investments and Other Assets
Assets
Gross Recognized Derivatives	11,248	15,960
Amounts Offset	(2,636)	(3,854)
Net Recognized Derivatives	8,612	12,106
Other	0	0
Amount Reported on Balance Sheet	8,612	12,106
Current Liabilities
Liabilities
Gross Recognized Derivatives	(115,822)	(113,560)
Amounts Offset	26,868	40,223
Net Recognized Derivatives	(88,954)	(73,337)
Other	(4,329)	(4,379)
Amount Reported on Balance Sheet	(93,283)	(77,716)
Deferred Credits and Other
Liabilities
Gross Recognized Derivatives	(88,239)	(93,827)
Amounts Offset	2,636	3,854
Net Recognized Derivatives	(85,603)	(89,973)
Other	0	0
Amount Reported on Balance Sheet	$ (85,603)	$ (89,973)

Derivative Accounting - Credit Risk and Credit Related Contingent Features (Details) - Commodity Contracts $ in Thousands	Mar. 31, 2016 USD ($)
Credit Risk and Credit-Related Contingent Features
Aggregate fair value of derivative instruments in a net liability position	$ 204,061
Cash collateral posted	17,600
Additional cash collateral in the event credit-risk-related contingent features were fully triggered	$ 133,688

Commitments and Contingencies - Palo Verde Nuclear Generating Station and Contractual Obligations (Details)		3 Months Ended
	Aug. 18, 2014 USD ($)	Mar. 31, 2016 USD ($) time_period power_plant claim	Dec. 31, 1986 Trust
Breach of Contract for Disposal of Spent Nuclear Fuel and/or High Level Radioactive Waste
Commitments and Contingencies
Litigation settlement amount	$ 57,400,000
Proceeds from legal settlements		$ 53,900,000
Arizona Public Service Company
Commitments and Contingencies
Maximum insurance against public liability per occurrence for a nuclear incident (up to)		13,500,000,000
Maximum available nuclear liability insurance (up to)		375,000,000
Remaining nuclear liability insurance through mandatory industry wide retrospective assessment program		13,100,000,000
Maximum retrospective premium assessment per reactor for each nuclear liability incident		127,300,000
Annual limit per incident with respect to maximum retrospective premium assessment		$ 19,000,000
Number of VIE lessor trusts		3	3
Maximum potential retrospective assessment per incident of APS		$ 111,000,000
Annual payment limitation with respect to maximum potential retrospective premium assessment		16,600,000
Amount of "all risk" (including nuclear hazards) insurance for property damage to, and decontamination of, property at Palo Verde		2,800,000,000
Maximum amount that APS could incur under the current NEIL policies for each retrospective assessment		23,100,000
Collateral assurance provided based on rating triggers		$ 61,700,000
Period to provide collateral assurance based on rating triggers		20 days
Arizona Public Service Company \| Breach of Contract for Disposal of Spent Nuclear Fuel and/or High Level Radioactive Waste
Commitments and Contingencies
Litigation settlement amount	$ 16,700,000
Number of claims submitted \| claim		2
Number of settlement agreement time periods \| time_period		2
Proceeds from legal settlements		$ 15,700,000

Commitments and Contingencies - Superfund-Related Matters, Southwest Power Outage and Clean Air Act (Details) - Arizona Public Service Company $ in Millions			3 Months Ended
	Aug. 06, 2013 Defendant	Sep. 08, 2011 kV Customer	Mar. 31, 2016 USD ($)
Loss Contingencies [Line Items]
Capacity of transmission line that tripped out of service (in kV) \| kV		500
Period, after the transmission line went off-line, over which generation and transmission resources for the Yuma area were lost		10 minutes
Number of customers losing service in Yuma area \| Customer		69,700
Contaminated groundwater wells
Loss Contingencies [Line Items]
Costs related to investigation and study under Superfund site \| $			$ 2
Number of defendants against whom Roosevelt Irrigation District (RID) filed lawsuit \| Defendant	24

Commitments and Contingencies - Environmental Matters and Financial Assurances (Details) $ in Millions			3 Months Ended
	Mar. 16, 2016 USD ($)	May. 23, 2013 USD ($)	Mar. 31, 2016 USD ($) Letter_of_credit
Environmental Matters
Clean power plan, optional extension period			2 years
Four Corners \| New Mexico Tax Matter
Environmental Matters
Coal severance surtax, penalty, and interest		$ 30.0
Litigation settlement awarded (against), amount	$ (1.0)
Arizona Public Service Company \| Letters of Credit Expiring in 2017
Financial Assurances
Number of letters of credit expiring \| Letter_of_credit			150,000,000
Arizona Public Service Company \| Letter of Credit
Financial Assurances
Outstanding letters of credit			$ 79.0
Arizona Public Service Company \| Four Corners \| New Mexico Tax Matter
Environmental Matters
Share of the assessment		12.0
Partial payment of assessment		$ 0.8
Litigation settlement awarded (against), amount	$ (0.8)
Regional Haze Rules \| Arizona Public Service Company \| Four Corners Units 4 and 5
Environmental Matters
Percentage of share of cost of control			63.00%
Expected environmental cost			$ 400.0
Regional Haze Rules \| Arizona Public Service Company \| Natural gas tolling contract obligations \| Four Corners Units 4 and 5
Environmental Matters
Additional percentage share of cost of control			7.00%
Regional Haze Rules \| Arizona Public Service Company \| Four Corners \| Four Corners Units 4 and 5
Environmental Matters
Site contingency increase in loss exposure not accrued, best estimate			$ 45.0
Regional Haze Rules \| Arizona Public Service Company \| Navajo Plant
Environmental Matters
Expected environmental cost			200.0
Regional Haze Rules \| Arizona Public Service Company \| Cholla
Environmental Matters
Expected environmental cost			100.0
Mercury and air toxic standards (MATS) \| Arizona Public Service Company \| Navajo Plant
Environmental Matters
Expected environmental cost			1.0
Mercury and air toxic standards (MATS) \| Arizona Public Service Company \| Cholla
Environmental Matters
Expected environmental cost			8.0
Coal combustion waste \| Arizona Public Service Company \| Four Corners
Environmental Matters
Site contingency increase in loss exposure not accrued, best estimate			15.0
Coal combustion waste \| Arizona Public Service Company \| Navajo Plant
Environmental Matters
Site contingency increase in loss exposure not accrued, best estimate			1.0
Coal combustion waste \| Arizona Public Service Company \| Cholla
Environmental Matters
Site contingency increase in loss exposure not accrued, best estimate			$ 40.0

Other Income and Other Expense (Details) - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2016	Mar. 31, 2015
Other income:
Interest income	$ 117	$ 110
Miscellaneous	0	125
Total other income	117	235
Other expense:
Non-operating costs	(2,049)	(2,249)
Investment losses — net	(518)	(495)
Miscellaneous	(1,471)	(1,542)
Total other expense	(4,038)	(4,286)
Arizona Public Service Company
Other income:
Interest income	73	67
Gain on disposition of property	332	207
Miscellaneous	205	365
Total other income	610	639
Other expense:
Non-operating costs	(1,966)	(2,517)
Loss on disposition of property	(426)	(643)
Miscellaneous	(2,358)	(2,194)
Total other expense	$ (4,750)	$ (5,354)

Earnings Per Share (Details) - USD ($) $ / shares in Units, shares in Thousands, $ in Thousands	3 Months Ended
	Mar. 31, 2016	Mar. 31, 2015
Earnings Per Share [Abstract]
Net income attributable to common shareholders	$ 4,453	$ 16,122
Weighted average common shares outstanding - basic (in shares)	111,296	110,916
Net effect of dilutive securities:
Contingently issuable performance shares and restricted stock units (in shares)	551	461
Weighted average common shares outstanding — diluted (in shares)	111,847	111,377
Net income attributable to common shareholders - basic (in dollars per share)	$ 0.04	$ 0.15
Net income attributable to common shareholders - diluted (in dollars per share)	$ 0.04	$ 0.14

Fair Value Measurements - Assets and Liabilities Measured on a Recurring Basis (Details) - USD ($) $ in Thousands	Mar. 31, 2016	Dec. 31, 2015
Assets
Nuclear decommissioning trust	$ 751,954	$ 735,196
Total assets	23,847	30,364
Recurring
Assets
Derivative instruments, other	(11,759)	(25,345)
Derivative assets	24,701	28,011
Nuclear decommissioning trust, other	318,073	314,622
Nuclear decommissioning trust	751,954	735,196
Total, other	306,314	289,277
Total assets	776,655	763,207
Liabilities
Total, other	25,022	39,698
Derivative liability	(178,886)	(167,689)
Recurring \| US commingled equity funds
Assets
Nuclear decommissioning trust, other	319,971	314,957
Nuclear decommissioning trust	319,971	314,957
Recurring \| Cash and cash equivalent funds
Assets
Nuclear decommissioning trust, other	(1,898)	(335)
Nuclear decommissioning trust	9,637	11,925
Recurring \| U.S. Treasury
Assets
Nuclear decommissioning trust	107,698	117,245
Recurring \| Corporate debt
Assets
Nuclear decommissioning trust	101,687	96,243
Recurring \| Mortgage-backed securities
Assets
Nuclear decommissioning trust	109,298	99,065
Recurring \| Municipality bonds
Assets
Nuclear decommissioning trust	80,344	72,206
Recurring \| Other
Assets
Nuclear decommissioning trust	23,319	23,555
Recurring \| Quoted Prices in Active Markets for Identical Assets (Level 1)
Assets
Decommissioning fund investments, gross fair value	119,233	129,505
Gross assets, fair value disclosure	119,233	129,505
Recurring \| Quoted Prices in Active Markets for Identical Assets (Level 1) \| Cash and cash equivalent funds
Assets
Decommissioning fund investments, gross fair value	11,535	12,260
Recurring \| Quoted Prices in Active Markets for Identical Assets (Level 1) \| U.S. Treasury
Assets
Decommissioning fund investments, gross fair value	107,698	117,245
Recurring \| Significant Other Observable Inputs (Level 2)
Assets
Gross derivative assets	12,613	22,992
Decommissioning fund investments, gross fair value	314,648	291,069
Gross assets, fair value disclosure	327,261	314,061
Liabilities
Gross derivative liability	(140,554)	(144,044)
Recurring \| Significant Other Observable Inputs (Level 2) \| Corporate debt
Assets
Decommissioning fund investments, gross fair value	101,687	96,243
Recurring \| Significant Other Observable Inputs (Level 2) \| Mortgage-backed securities
Assets
Decommissioning fund investments, gross fair value	109,298	99,065
Recurring \| Significant Other Observable Inputs (Level 2) \| Municipality bonds
Assets
Decommissioning fund investments, gross fair value	80,344	72,206
Recurring \| Significant Other Observable Inputs (Level 2) \| Other
Assets
Decommissioning fund investments, gross fair value	23,319	23,555
Recurring \| Significant Unobservable Inputs (a) (Level 3)
Assets
Gross derivative assets	23,847	30,364
Gross assets, fair value disclosure	23,847	30,364
Liabilities
Gross derivative liability	$ (63,354)	$ (63,343)

Fair Value Measurements - Significant Unobservable Inputs Used to Value Level 3 Instruments (Details 2) $ in Thousands	3 Months Ended	12 Months Ended
	Mar. 31, 2016 USD ($) $ / MMBTU $ / MWh	Dec. 31, 2015 USD ($) $ / MMBTU $ / MWh
Information regarding the entity's internally developed significant unobservable inputs used to value its level 3 instruments
Assets	$ 23,847	$ 30,364
Liabilities	63,354	63,343
Electricity forward contracts
Information regarding the entity's internally developed significant unobservable inputs used to value its level 3 instruments
Assets	21,606	24,543
Liabilities	$ 51,305	$ 54,679
Electricity forward contracts \| Minimum \| Discounted cash flows
Information regarding the entity's internally developed significant unobservable inputs used to value its level 3 instruments
Electricity forward price (per MWh) \| $ / MWh	13.97	15.92
Electricity forward contracts \| Maximum \| Discounted cash flows
Information regarding the entity's internally developed significant unobservable inputs used to value its level 3 instruments
Electricity forward price (per MWh) \| $ / MWh	39.61	40.73
Electricity forward contracts \| Weighted Average \| Discounted cash flows
Information regarding the entity's internally developed significant unobservable inputs used to value its level 3 instruments
Electricity forward price (per MWh) \| $ / MWh	26.45	26.86
Option Contracts
Information regarding the entity's internally developed significant unobservable inputs used to value its level 3 instruments
Assets	$ 0	$ 0
Liabilities	$ 5,880	$ 5,628
Option Contracts \| Minimum \| Option model
Information regarding the entity's internally developed significant unobservable inputs used to value its level 3 instruments
Electricity forward price (per MWh) \| $ / MWh	19.46	23.87
Electricity price volatilities (as a percent)	47.00%	40.00%
Natural gas price volatilities (as a percent)	38.00%	32.00%
Option Contracts \| Maximum \| Option model
Information regarding the entity's internally developed significant unobservable inputs used to value its level 3 instruments
Electricity forward price (per MWh) \| $ / MWh	37.93	44.13
Electricity price volatilities (as a percent)	72.00%	59.00%
Natural gas price volatilities (as a percent)	45.00%	40.00%
Option Contracts \| Weighted Average \| Option model
Information regarding the entity's internally developed significant unobservable inputs used to value its level 3 instruments
Electricity forward price (per MWh) \| $ / MWh	29.39	33.91
Electricity price volatilities (as a percent)	63.00%	52.00%
Natural gas price volatilities (as a percent)	41.00%	35.00%
Natural gas forward contracts
Information regarding the entity's internally developed significant unobservable inputs used to value its level 3 instruments
Assets	$ 2,241	$ 5,821
Liabilities	$ 6,169	$ 3,036
Natural gas forward contracts \| Minimum \| Discounted cash flows
Information regarding the entity's internally developed significant unobservable inputs used to value its level 3 instruments
Natural gas forward price (per MMbtu) \| $ / MMBTU	1.65	2.18
Natural gas forward contracts \| Maximum \| Discounted cash flows
Information regarding the entity's internally developed significant unobservable inputs used to value its level 3 instruments
Natural gas forward price (per MMbtu) \| $ / MMBTU	3.11	3.14
Natural gas forward contracts \| Weighted Average \| Discounted cash flows
Information regarding the entity's internally developed significant unobservable inputs used to value its level 3 instruments
Natural gas forward price (per MMbtu) \| $ / MMBTU	2.67	2.61

Fair Value Measurements - Level 3 Rollforward Derivatives (Details) - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2016	Mar. 31, 2015
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Roll Forward]
Net derivative balance at beginning of period	$ (32,979)	$ (41,386)
Included in OCI	0	(262)
Deferred as a regulatory asset or liability	(9,103)	(10,747)
Settlements	1,765	310
Transfers into Level 3 from Level 2	262	(402)
Transfers from Level 3 into Level 2	548	3,673
Net derivative balance at end of period	(39,507)	(48,814)
Net unrealized gains included in earnings related to instruments still held at end of period	$ 0	$ 0

Nuclear Decommissioning Trusts (Details) - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2016	Mar. 31, 2015	Dec. 31, 2015
Nuclear decommissioning trust fund assets
Fair Value	$ 751,954		$ 735,196
Realized gains and losses and proceeds from the sale of securities by the nuclear decommissioning trust funds
Proceeds from the sale of securities	141,809	$ 115,282
Fair value of fixed income securities, summarized by contractual maturities
Total	751,954		735,196
Arizona Public Service Company
Nuclear decommissioning trust fund assets
Fair Value	751,954		735,196
Unrealized Gains	178,040		169,053
Unrealized Losses	(741)		(2,760)
Net payables for securities purchases	(1,898)		(335)
Realized gains and losses and proceeds from the sale of securities by the nuclear decommissioning trust funds
Realized gains	2,438	1,195
Realized losses	(1,786)	(525)
Proceeds from the sale of securities	141,809	$ 115,282
Fair value of fixed income securities, summarized by contractual maturities
Total	751,954		735,196
Arizona Public Service Company \| Equity Securities
Nuclear decommissioning trust fund assets
Fair Value	319,971		314,957
Unrealized Gains	159,790		157,098
Unrealized Losses	(65)		(115)
Fair value of fixed income securities, summarized by contractual maturities
Total	319,971		314,957
Arizona Public Service Company \| Fixed income securities.
Nuclear decommissioning trust fund assets
Fair Value	433,881		420,574
Unrealized Gains	18,250		11,955
Unrealized Losses	(676)		(2,645)
Fair value of fixed income securities, summarized by contractual maturities
Less than one year	11,633
1 year - 5 years	126,221
5 years - 10 years	101,773
Greater than 10 years	194,254
Total	$ 433,881		$ 420,574

Changes in Accumulated Other Comprehensive Loss (Details) - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2016	Mar. 31, 2015
AOCI Including Portion Attributable to Noncontrolling Interest, Net of Tax [Roll Forward]
Balance at beginning of period	$ 4,740,413	$ 4,553,007
Total other comprehensive income	978	1,759
Balance at end of period	4,719,457	4,519,102
AOCI Including Portion Attributable to Noncontrolling Interest
AOCI Including Portion Attributable to Noncontrolling Interest, Net of Tax [Roll Forward]
Balance at beginning of period	(43,770)	(66,382)
Balance at end of period	(44,748)	(68,141)
Accumulated Net Investment Gain (Loss) Including Portion Attributable to Noncontrolling Interest
AOCI Including Portion Attributable to Noncontrolling Interest, Net of Tax [Roll Forward]
OCI (loss) before reclassifications	(693)	(800)
Amounts reclassified from accumulated other comprehensive loss	1,141	1,976
Total other comprehensive income	448	1,176
Accumulated Defined Benefit Plans Adjustment Including Portion Attributable to Noncontrolling Interest
AOCI Including Portion Attributable to Noncontrolling Interest, Net of Tax [Roll Forward]
Amounts reclassified from accumulated other comprehensive loss	530	583
Total other comprehensive income	530	583
Arizona Public Service Company
AOCI Including Portion Attributable to Noncontrolling Interest, Net of Tax [Roll Forward]
Balance at beginning of period	4,827,980	4,656,183
Total other comprehensive income	1,059	1,857
Balance at end of period	4,814,794	4,629,852
Arizona Public Service Company \| AOCI Including Portion Attributable to Noncontrolling Interest
AOCI Including Portion Attributable to Noncontrolling Interest, Net of Tax [Roll Forward]
Balance at beginning of period	(26,038)	(46,476)
Balance at end of period	(27,097)	(48,333)
Arizona Public Service Company \| Accumulated Net Investment Gain (Loss) Including Portion Attributable to Noncontrolling Interest
AOCI Including Portion Attributable to Noncontrolling Interest, Net of Tax [Roll Forward]
OCI (loss) before reclassifications	(693)	(800)
Amounts reclassified from accumulated other comprehensive loss	1,141	1,976
Total other comprehensive income	448	1,176
Arizona Public Service Company \| Accumulated Defined Benefit Plans Adjustment Including Portion Attributable to Noncontrolling Interest
AOCI Including Portion Attributable to Noncontrolling Interest, Net of Tax [Roll Forward]
Amounts reclassified from accumulated other comprehensive loss	611	681
Total other comprehensive income	$ 611	$ 681

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