Pinnacle West Capital (PNW) 10-K21 Feb 142013 FY Annual reportFinancial data

Company Profile

Document_and_Entity_Informatio

Document and Entity Information (USD $)	12 Months Ended
Document and Entity Information (USD $)	Dec. 31, 2013	Feb. 14, 2014	Jun. 30, 2013
Document and Entity Information	'	'	'
Entity Registrant Name	'PINNACLE WEST CAPITAL CORP	'	'
Entity Central Index Key	'0000764622	'	'
Document Type	'10-K	'	'
Document Period End Date	31-Dec-13	'	'
Amendment Flag	'false	'	'
Current Fiscal Year End Date	'--12-31	'	'
Entity Well-known Seasoned Issuer	'Yes	'	'
Entity Voluntary Filers	'No	'	'
Entity Current Reporting Status	'Yes	'	'
Entity Filer Category	'Large Accelerated Filer	'	'
Entity Public Float	'	'	$6,078,967,225
Entity Common Stock, Shares Outstanding	'	110,194,366	'
Document Fiscal Year Focus	'2013	'	'
Document Fiscal Period Focus	'FY	'	'

CONSOLIDATED_STATEMENTS_OF_INC

CONSOLIDATED STATEMENTS OF INCOME (USD $)	12 Months Ended
In Thousands, except Per Share data, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
CONSOLIDATED STATEMENTS OF INCOME	'	'	'
OPERATING REVENUES	$3,454,628	$3,301,804	$3,241,379
OPERATING EXPENSES	'	'	'
Fuel and purchased power	1,095,709	994,790	1,009,464
Operations and maintenance	924,727	884,769	904,286
Depreciation and amortization	415,708	404,336	427,054
Taxes other than income taxes	164,167	159,323	147,408
Other expenses	7,994	6,831	6,659
Total	2,608,305	2,450,049	2,494,871
OPERATING INCOME	846,323	851,755	746,508
OTHER INCOME (DEDUCTIONS)	'	'	'
Allowance for equity funds used during construction (Note 1)	25,581	22,436	23,707
Other income (Note 18)	1,704	1,606	3,111
Other expense (Note 18)	-16,024	-19,842	-10,451
Total	11,261	4,200	16,367
INTEREST EXPENSE	'	'	'
Interest charges	201,888	214,616	241,995
Allowance for borrowed funds used during construction (Note 1)	-14,861	-14,971	-18,358
Total	187,027	199,645	223,637
INCOME FROM CONTINUING OPERATIONS BEFORE INCOME TAXES	670,557	656,310	539,238
INCOME TAXES (Note 4)	230,591	237,317	183,604
INCOME FROM CONTINUING OPERATIONS	439,966	418,993	355,634
INCOME (LOSS) FROM DISCONTINUED OPERATIONS	'	'	'
Net of income tax expense (benefit) of $--, $(3,813) and $7,418 (Note 1)	'	-5,829	11,306
NET INCOME	439,966	413,164	366,940
Less: Net income attributable to noncontrolling interests (Note 19)	33,892	31,622	27,467
NET INCOME ATTRIBUTABLE TO COMMON SHAREHOLDERS	406,074	381,542	339,473
WEIGHTED-AVERAGE COMMON SHARES OUTSTANDING - BASIC (in shares)	109,984	109,510	109,053
WEIGHTED-AVERAGE COMMON SHARES OUTSTANDING - DILUTED (in shares)	110,806	110,527	109,864
EARNINGS PER WEIGHTED - AVERAGE COMMON SHARE OUTSTANDING	'	'	'
Income from continuing operations attributable to common shareholders - basic (in dollars per share)	$3.69	$3.54	$3.01
Net income attributable to common shareholders - basic (in dollars per share)	$3.69	$3.48	$3.11
Income from continuing operations attributable to common shareholders - diluted (in dollars per share)	$3.66	$3.50	$2.99
Net income attributable to common shareholders - diluted (in dollars per share)	$3.66	$3.45	$3.09
AMOUNTS ATTRIBUTABLE TO COMMON SHAREHOLDERS:	'	'	'
Income from continuing operations, net of tax	406,074	387,380	328,110
Discontinued operations, net of tax	'	-5,838	11,363
Net income attributable to common shareholders	$406,074	$381,542	$339,473

CONSOLIDATED_STATEMENTS_OF_INC1

CONSOLIDATED STATEMENTS OF INCOME (Parenthetical) (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2012	Dec. 31, 2011
CONSOLIDATED STATEMENTS OF INCOME	'	'
Income tax expense (benefit) on discontinued operations	($3,813)	$7,418

CONSOLIDATED_STATEMENTS_OF_COM

CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME	'	'	'
NET INCOME	$439,966	$413,164	$366,940
Derivative instruments:	'	'	'
Net unrealized loss, net of tax benefit of $140, $14,900, and $37,389 (Note 17)	-213	-22,763	-57,271
Reclassification of net realized loss, net of tax benefit of $17,472, $39,120, and $46,288 (Note 17)	26,747	59,887	70,902
Pension and other postretirement benefits activity, net of tax (expense) benefit of $(6,156), $(651), and $3,935 (Note 8)	9,421	1,031	-6,026
Total other comprehensive income	35,955	38,155	7,605
COMPREHENSIVE INCOME	475,921	451,319	374,545
Less: Comprehensive income attributable to noncontrolling interests	33,892	31,622	27,467
COMPREHENSIVE INCOME ATTRIBUTABLE TO COMMON SHAREHOLDERS	$442,029	$419,697	$347,078

CONSOLIDATED_STATEMENTS_OF_COM1

CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (Parenthetical) (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME	'	'	'
Net unrealized loss, tax benefit	$140	$14,900	$37,389
Reclassification of net realized loss, tax benefit	17,472	39,120	46,288
Pension and other postretirement benefits activity, tax (expense) benefit	($6,156)	($651)	$3,935

CONSOLIDATED_BALANCE_SHEETS

CONSOLIDATED BALANCE SHEETS (USD $)	Dec. 31, 2013	Dec. 31, 2012
In Thousands, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012
CURRENT ASSETS	'	'
Cash and cash equivalents	$9,526	$26,202
Customer and other receivables	299,904	277,225
Accrued unbilled revenues	96,796	94,845
Allowance for doubtful accounts	-3,203	-3,340
Materials and supplies (at average cost)	221,682	218,096
Fossil fuel (at average cost)	38,028	31,334
Deferred income taxes (Note 4)	91,152	152,191
Income tax receivable (Note 4)	135,517	2,423
Assets from risk management activities (Note 17)	17,169	25,699
Deferred fuel and purchased power regulatory asset (Note 3)	20,755	72,692
Other regulatory assets (Note 3)	76,388	71,257
Other current assets	39,895	37,102
Total current assets	1,043,609	1,005,726
INVESTMENTS AND OTHER ASSETS	'	'
Assets from risk management activities (Note 17)	23,815	35,891
Nuclear decommissioning trust (Notes 14 and 20)	642,007	570,625
Other assets	60,875	62,694
Total investments and other assets	726,697	669,210
PROPERTY, PLANT AND EQUIPMENT (Notes 1, 6 and 10)	'	'
Plant in service and held for future use	15,200,464	14,346,367
Accumulated depreciation and amortization	-5,300,219	-4,929,613
Net	9,900,245	9,416,754
Construction work in progress	581,369	565,716
Palo Verde sale leaseback, net of accumulated depreciation of $225,925 and $222,055 (Note 19)	125,125	128,995
Intangible assets, net of accumulated amortization of $439,703 and $411,543	157,689	162,150
Nuclear fuel, net of accumulated amortization of $146,057 and $133,950	124,557	122,778
Total property, plant and equipment	10,888,985	10,396,393
DEFERRED DEBITS	'	'
Regulatory assets (Notes 1, 3 and 4)	711,712	1,099,900
Income tax receivable (Note 4)	'	70,389
Other	137,683	137,997
Total deferred debits	849,395	1,308,286
TOTAL ASSETS	13,508,686	13,379,615
CURRENT LIABILITIES	'	'
Accounts payable	284,516	221,312
Accrued taxes (Note 4)	130,998	124,939
Accrued interest	48,351	49,380
Common dividends payable	62,528	59,789
Short-term borrowings (Note 5)	153,125	92,175
Current maturities of long-term debt (Note 6)	540,424	122,828
Customer deposits	76,101	79,689
Liabilities from risk management activities (Note 17)	31,892	73,741
Liability for asset retirements (Note 12)	32,896	'
Regulatory liabilities (Note 3)	99,273	88,116
Other current liabilities	158,540	171,573
Total current liabilities	1,618,644	1,083,542
LONG-TERM DEBT LESS CURRENT MATURITIES (Note 6)	2,796,465	3,199,088
DEFERRED CREDITS AND OTHER	'	'
Deferred income taxes (Note 4)	2,351,882	2,151,371
Regulatory liabilities (Notes 1, 3 and 4)	801,297	759,201
Liability for asset retirements (Note 12)	313,833	357,097
Liabilities for pension and other postretirement benefits (Note 8)	513,628	1,058,755
Liabilities from risk management activities (Note 17)	70,315	85,264
Customer advances	114,480	109,359
Coal mine reclamation	207,453	118,860
Deferred investment tax credit	152,361	99,819
Unrecognized tax benefits (Note 4)	42,209	71,135
Other	185,659	183,835
Total deferred credits and other	4,753,117	4,994,696
COMMITMENTS AND CONTINGENCIES (SEE NOTES)	'	'
EQUITY (Note 7)	'	'
Common stock, no par value; authorized 150,000,000 shares, issued 110,280,703 at end of 2013 and 109,837,957 at end of 2012	2,491,558	2,466,923
Treasury stock at cost; 98,944 shares at end of 2013 and 95,192 shares at end of 2012	-4,308	-4,211
Total common stock	2,487,250	2,462,712
Retained earnings	1,785,273	1,624,102
Accumulated other comprehensive loss:	'	'
Pension and other postretirement benefits (Note 8)	-54,995	-64,416
Derivative instruments (Note 17)	-23,058	-49,592
Total accumulated other comprehensive loss	-78,053	-114,008
Total shareholders' equity	4,194,470	3,972,806
Noncontrolling interests (Note 19)	145,990	129,483
Total equity	4,340,460	4,102,289
TOTAL LIABILITIES AND EQUITY	$13,508,686	$13,379,615

CONSOLIDATED_BALANCE_SHEETS_Pa

CONSOLIDATED BALANCE SHEETS (Parenthetical) (USD $)	Dec. 31, 2013	Dec. 31, 2012
In Thousands, except Share data, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012
PROPERTY, PLANT AND EQUIPMENT (Notes 1, 6 and 10)	'	'
Accumulated depreciation of Palo Verde sale leaseback	$225,925	$222,055
Accumulated amortization on intangible assets	439,703	411,543
Accumulated amortization on nuclear fuel	$146,057	$133,950
EQUITY (Note 7)	'	'
Common stock, par value	'	'
Common stock, authorized shares	150,000,000	150,000,000
Common stock, issued shares	110,280,703	109,837,957
Treasury stock at cost, shares	98,944	95,192

CONSOLIDATED_STATEMENTS_OF_CAS

CONSOLIDATED STATEMENTS OF CASH FLOWS (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
CASH FLOWS FROM OPERATING ACTIVITIES	'	'	'
Net Income	$439,966	$413,164	$366,940
Adjustments to reconcile net income to net cash provided by operating activities:	'	'	'
Gain on sale of energy-related products and services business	'	'	-10,404
Depreciation and amortization including nuclear fuel	492,322	481,262	493,784
Deferred fuel and purchased power	21,678	71,573	69,166
Deferred fuel and purchased power amortization	31,190	-116,716	-155,157
Allowance for equity funds used during construction	-25,581	-22,436	-23,707
Deferred income taxes	249,296	187,023	117,952
Deferred investment tax credit	52,542	41,579	58,240
Change in derivative instruments fair value	534	-749	4,064
Changes in current assets and liabilities:	'	'	'
Customer and other receivables	-44,991	14,587	40,626
Accrued unbilled revenues	-1,951	30,394	-21,947
Materials, supplies and fossil fuel	-11,878	-23,043	-23,398
Income tax receivable	-133,094	-4,043	3,983
Other current assets	-17,913	-27,352	-3,079
Accounts payable	45,414	-96,600	58,346
Accrued taxes	6,059	12,736	8,085
Other current liabilities	-7,513	23,869	20,358
Change in margin and collateral accounts - assets	993	2,216	33,349
Change in margin and collateral accounts - liabilities	12,355	137,785	29,731
Change in long term income tax receivable	137,270	-1,756	-3,530
Change in unrecognized tax benefits	-91,425	-2,583	8,410
Change in other regulatory liabilities	64,473	13,539	37,009
Change in other long-term assets	-41,757	6,872	-41,722
Change in other long-term liabilities	-24,682	29,801	58,484
Net cash flow provided by operating activities	1,153,307	1,171,122	1,125,583
CASH FLOWS FROM INVESTING ACTIVITIES	'	'	'
Capital expenditures	-1,016,322	-889,551	-884,350
Contributions in aid of construction	41,090	49,876	38,096
Allowance for borrowed funds used during construction	-14,861	-14,971	-18,358
Proceeds from sale of energy-related products and services business	0	'	45,111
Proceeds from nuclear decommissioning trust sales	446,025	417,603	497,780
Investment in nuclear decommissioning trust	-463,274	-434,852	-513,799
Proceeds from sale of life insurance policies	'	'	55,444
Other	-2,059	-1,099	-1,931
Net cash flow used for investing activities	-1,009,401	-872,994	-782,007
CASH FLOWS FROM FINANCING ACTIVITIES	'	'	'
Issuance of long-term debt	136,307	476,081	470,353
Repayment of long-term debt	-122,828	-654,286	-655,169
Short-term borrowings and payments - net	60,950	92,175	-16,600
Dividends paid on common stock	-235,244	-225,075	-221,728
Common stock equity issuance	17,319	15,955	15,841
Distributions to noncontrolling interests	-17,385	-10,529	-10,210
Other	299	170	-2,668
Net cash flow used for financing activities	-160,582	-305,509	-420,181
NET DECREASE IN CASH AND CASH EQUIVALENTS	-16,676	-7,381	-76,605
CASH AND CASH EQUIVALENTS AT BEGINNING OF YEAR	26,202	33,583	110,188
CASH AND CASH EQUIVALENTS AT END OF YEAR	$9,526	$26,202	$33,583

CONSOLIDATED_STATEMENTS_OF_CHA

CONSOLIDATED STATEMENTS OF CHANGES IN EQUITY (USD $)	Total	COMMON STOCK (Note 7)	TREASURY STOCK (Note 7)	RETAINED EARNINGS	ACCUMULATED OTHER COMPREHENSIVE INCOME (LOSS)	NONCONTROLLING INTERESTS	COMPREHENSIVE INCOME ATTRIBUTABLE TO COMMON SHAREHOLDERS
In Thousands, unless otherwise specified	Total	COMMON STOCK (Note 7)	TREASURY STOCK (Note 7)	RETAINED EARNINGS	ACCUMULATED OTHER COMPREHENSIVE INCOME (LOSS)	NONCONTROLLING INTERESTS	COMPREHENSIVE INCOME ATTRIBUTABLE TO COMMON SHAREHOLDERS
Balance at Dec. 31, 2010	'	$2,421,372	($2,239)	$1,423,961	($159,767)	$91,899	'
Increase (Decrease) in Shareholders' Equity	'	'	'	'	'	'	'
Issuance of common stock	'	22,875	'	'	'	'	'
Purchase of treasury stock	'	'	-3,720	'	'	'	'
Reissuance of treasury stock used for stock compensation	'	'	1,242	'	'	'	'
Net income attributable to common shareholders	339,473	'	'	339,473	'	'	339,473
Common stock dividends declared ($2.23, $2.67, and $ 2.10 per share)	'	'	'	-228,951	'	'	'
Net income attributable to noncontrolling interests	-27,467	'	'	'	'	27,467	'
Net capital activities by noncontrolling interests	'	'	'	'	'	-10,630	'
COMPREHENSIVE INCOME ATTRIBUTABLE TO COMMON SHAREHOLDER	'	'	'	'	'	'	'
Other comprehensive income attributable to common shareholders	7,605	'	'	'	7,604	'	7,605
COMPREHENSIVE INCOME ATTRIBUTABLE TO COMMON SHAREHOLDERS	347,078	'	'	'	'	'	347,078
Balance at Dec. 31, 2011	3,930,586	2,444,247	-4,717	1,534,483	-152,163	108,736	'
Increase (Decrease) in Shareholders' Equity	'	'	'	'	'	'	'
Issuance of common stock	'	22,676	'	'	'	'	'
Purchase of treasury stock	'	'	-4,607	'	'	'	'
Reissuance of treasury stock used for stock compensation	'	'	5,113	'	'	'	'
Net income attributable to common shareholders	381,542	'	'	381,542	'	'	381,542
Common stock dividends declared ($2.23, $2.67, and $ 2.10 per share)	'	'	'	-291,923	'	'	'
Net income attributable to noncontrolling interests	-31,622	'	'	'	'	31,622	'
Net capital activities by noncontrolling interests	'	'	'	'	'	-10,875	'
COMPREHENSIVE INCOME ATTRIBUTABLE TO COMMON SHAREHOLDER	'	'	'	'	'	'	'
Other comprehensive income attributable to common shareholders	38,155	'	'	'	38,155	'	38,155
COMPREHENSIVE INCOME ATTRIBUTABLE TO COMMON SHAREHOLDERS	419,697	'	'	'	'	'	419,697
Balance at Dec. 31, 2012	4,102,289	2,466,923	-4,211	1,624,102	-114,008	129,483	'
Increase (Decrease) in Shareholders' Equity	'	'	'	'	'	'	'
Issuance of common stock	'	24,635	'	'	'	'	'
Purchase of treasury stock	'	'	-9,727	'	'	'	'
Reissuance of treasury stock used for stock compensation	'	'	9,630	'	'	'	'
Net income attributable to common shareholders	406,074	'	'	406,074	'	'	406,074
Common stock dividends declared ($2.23, $2.67, and $ 2.10 per share)	'	'	'	-244,903	'	'	'
Net income attributable to noncontrolling interests	-33,892	'	'	'	'	33,892	'
Net capital activities by noncontrolling interests	'	'	'	'	'	-17,385	'
COMPREHENSIVE INCOME ATTRIBUTABLE TO COMMON SHAREHOLDER	'	'	'	'	'	'	'
Other comprehensive income attributable to common shareholders	35,955	'	'	'	35,955	'	35,955
COMPREHENSIVE INCOME ATTRIBUTABLE TO COMMON SHAREHOLDERS	442,029	'	'	'	'	'	442,029
Balance at Dec. 31, 2013	$4,340,460	$2,491,558	($4,308)	$1,785,273	($78,053)	$145,990	'

CONSOLIDATED_STATEMENTS_OF_CHA1

CONSOLIDATED STATEMENTS OF CHANGES IN EQUITY (Parenthetical) (USD $)	12 Months Ended
	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
CONSOLIDATED STATEMENTS OF CHANGES IN EQUITY	'	'	'
Common stock dividends declared (in dollars per share)	$2.23	$2.67	$2.10

Summary_of_Significant_Account

Summary of Significant Accounting Policies	12 Months Ended
	Dec. 31, 2013
Summary of Significant Accounting Policies	'
Summary of Significant Accounting Policies	'
	1. Summary of Significant Accounting Policies

	Description of Business and Basis of Presentation

	Pinnacle West is a holding company that conducts business through its subsidiaries, APS and El Dorado, and formerly SunCor and APSES. APS, our wholly-owned subsidiary, is a vertically-integrated electric utility that provides either retail or wholesale electric service to substantially all 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 accounts for essentially all of our revenues and earnings, and is expected to continue to do so. SunCor was a developer of residential, commercial and industrial real estate projects and essentially all of these assets were sold in 2009 and 2010. In February 2012, SunCor filed for protection under the United States Bankruptcy Code to complete an orderly liquidation of its business. All activities for SunCor are reported as discontinued operations. APSES provided energy-related projects to commercial and industrial retail customers in competitive markets in the western United States. APSES was sold in 2011 and is reported as discontinued operations. El Dorado is an investment firm.

	Pinnacle West’s Consolidated Financial Statements include the accounts of Pinnacle West and our subsidiaries: APS and El Dorado, and formerly SunCor and APSES. APS’s consolidated financial statements include the accounts of APS and certain VIEs relating to the Palo Verde sale leaseback. Intercompany accounts and transactions between the consolidated companies have been eliminated.

	We consolidate VIEs for which we are the primary beneficiary. We determine whether we are the primary beneficiary of a VIE through a qualitative analysis that identifies which variable interest holder has the controlling financial interest in the VIE. In performing our primary beneficiary analysis, we consider all relevant facts and circumstances, including the design and activities of the VIE, the terms of the contracts the VIE has entered into, and which parties participated significantly in the design or redesign of the entity. We continually evaluate our primary beneficiary conclusions to determine if changes have occurred which would impact our primary beneficiary assessments. We have determined that APS is the primary beneficiary of certain VIE lessor trusts relating to the Palo Verde sale leaseback, and therefore APS consolidates these entities (see Note 19).

	Our 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 line items are presented in more detail on the Consolidated Balance Sheets and Consolidated Statements of Cash Flows than was presented in the prior years. Other line items are more condensed than the previous presentation. The prior year amounts were reclassified to conform to the current year presentation. These reclassifications had no impact on total assets or net cash flow provided by operating activities. The following tables show the impacts of the reclassifications of prior years (previously reported) amounts (dollars in thousands):

	Balance Sheets - December 31, 2012		As			Reclassifications to			Amount reported
			previously			conform to current year			after reclassification
			reported			presentation			to conform to current
									year presentation
	Long-Term Debt less Current Maturities —
	Long-term debt less current maturities		$	3,160,219		$	38,869		$	3,199,088
	Long-Term Debt less Current Maturities —
	Palo Verde sale leaseback lessor notes less
	current maturities		38,869			(38,869		)	—


	Statement of Cash Flows for the		As previously			Reclassifications to			Amount reported after
	Year Ended December 31, 2012		reported			conform to current year			reclassification to
						presentation			conform to current
									year presentation
	Cash Flows from Operating Activities
	Deferred income taxes		$	228,602		$	(41,579	)	$	187,023
	Deferred investment tax credit		—			41,579			41,579
	Accrued taxes and income tax receivable		8,693			(8,693		)	—
	Income tax receivable		—			(4,043		)	(4,043		)
	Accrued taxes		—			12,736			12,736


	Statement of Cash Flows for the		As previously			Reclassifications to			Amount reported after
	Year Ended December 31, 2011		reported			conform to current year			reclassification to
						presentation			conform to current year
									presentation
	Cash Flows from Operating Activities
	Deferred income taxes		$	176,192		$	(58,240	)	$	117,952
	Deferred investment tax credit		—			58,240			58,240
	Accrued taxes and income tax receivable		12,068			(12,068		)	—
	Income tax receivable		—			3,983			3,983
	Accrued taxes		—			8,085			8,085


	Accounting Records and Use of Estimates

	Our accounting records are maintained in accordance with 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.

	Regulatory Accounting

	APS is regulated by the ACC and FERC. The accompanying financial statements reflect the rate-making policies of these commissions. As a result, we capitalize certain costs that would be included as expense in the current period by unregulated companies. Regulatory assets represent incurred costs that have been deferred because they are probable of future recovery in customer rates. Regulatory liabilities generally represent expected future costs that have already been collected from customers.

	Management continually assesses whether our regulatory assets are probable of future recovery by considering factors such as changes in the applicable regulatory environment and recent rate orders applicable to APS or other regulated entities in the same jurisdiction. This determination reflects the current political and regulatory climate in Arizona and is subject to change in the future. If future recovery of costs ceases to be probable, the assets would be written off as a charge in current period earnings.

	See Note 3 for additional information.

	Electric Revenues

We derive electric revenues primarily from sales of electricity to our regulated Native Load customers. Revenues related to the sale of electricity are generally recorded when service is rendered or electricity is delivered to customers. The billing of electricity sales to individual Native Load customers is based on the reading of their meters, which occurs on a systematic basis throughout the month. Unbilled revenues are estimated by applying an average revenue/kWh by customer class to the number of estimated kWhs delivered but not billed. Differences historically between the actual and estimated unbilled revenues are immaterial. We exclude sales taxes and franchise fees on electric revenues from both revenue and taxes other than income taxes.

Revenues from our Native Load customers and non-derivative instruments are reported on a gross basis on Pinnacle West’s Consolidated Statements of Income. In the electricity business, some contracts to purchase energy are netted against other contracts to sell energy. This is called a “book-out” and usually occurs for contracts that have the same terms (quantities and delivery points) and for which power does not flow. We net these book-outs, which reduces both revenues and fuel and purchased power costs.

For the period January 1, 2010 through June 30, 2012, electric revenues also include proceeds for line extension payments for new or upgraded service in accordance with the 2009 Settlement Agreement (see Note 3). Effective July 1, 2012, as a result of the 2012 Settlement Agreement, these amounts are now recorded as contributions in aid of construction and are not included in electric revenues.

Some of our cost recovery mechanisms are alternative revenue programs. For alternative revenue programs that meet specified accounting criteria, we recognize revenues when the specific events permitting billing of the additional revenues have been completed.

Allowance for Doubtful Accounts

The allowance for doubtful accounts represents our best estimate of existing accounts receivable that will ultimately be uncollectible. The allowance is calculated by applying estimated write-off factors to various classes of outstanding receivables, including accrued utility revenues. The write-off factors used to estimate uncollectible accounts are based upon consideration of both historical collections experience and management’s best estimate of future collections success given the existing collections environment.

Property, Plant and Equipment

Utility plant is the term we use to describe the business property and equipment that supports electric service, consisting primarily of generation, transmission and distribution facilities. We report utility plant at its original cost, which includes:

· material and labor;
· contractor costs;
· capitalized leases;
· construction overhead costs (where applicable); and
· allowance for funds used during construction.

We expense the costs of plant outages, major maintenance and routine maintenance as incurred. We charge retired utility plant to accumulated depreciation. Liabilities associated with the retirement of tangible long-lived assets are recognized at fair value as incurred and capitalized as part of the related tangible long-lived assets. Accretion of the liability due to the passage of time is an operating expense, and the capitalized cost is depreciated over the useful life of the long-lived asset. See Note 12.

APS records a regulatory liability on its regulated assets for the difference between the amount that has been recovered in regulated rates and the amount calculated in accordance with guidance on accounting for asset retirement obligations. APS believes it can recover in regulated rates the costs calculated in accordance with this accounting guidance.

We record depreciation on utility plant on a straight-line basis over the remaining useful life of the related assets. The approximate remaining average useful lives of our utility property at December 31, 2013 were as follows:

· Fossil plant — 18 years;
· Nuclear plant — 26 years;
· Other generation — 26 years;
· Transmission — 37 years;
· Distribution — 34 years; and
· Other — 7 years.

APS applied for twenty-year extensions of its operating licenses for each of the three Palo Verde units in December 2008. On April 21, 2011, the NRC approved the extensions of the Palo Verde licenses. The nuclear plant remaining life takes into consideration an ACC decision which authorizes the use of the new Palo Verde nuclear plant lives, effective January 1, 2012.

Pursuant to an ACC order, we defer operating costs related to APS’s acquisition of additional interests in Units 4 and 5 and the related closure of Units 1-3 of Four Corners. See Note 3 for further discussion. These costs are deferred on the depreciation line of the Consolidated Statements of Income.

For the years 2011 through 2013, the depreciation rates ranged from a low of 0.45% to a high of 12.08%. The weighted-average rate was 3.00% for 2013, 2.71% for 2012, and 2.98% for 2011.

Allowance for Funds Used During Construction

AFUDC represents the approximate net composite interest cost of borrowed funds and an allowed return on the equity funds used for construction of regulated utility plant. Both the debt and equity components of AFUDC are non-cash amounts within the Consolidated Statement of Income. Plant construction costs, including AFUDC, are recovered in authorized rates through depreciation when completed projects are placed into commercial operation.

AFUDC was calculated by using a composite rate of 8.56% for 2013, 8.60% for 2012, and 10.25% for 2011. APS compounds AFUDC semi-annually and ceases to accrue AFUDC when construction work is completed and the property is placed in service.

Materials and Supplies

APS values materials, supplies and fossil fuel inventory using a weighted-average cost method. APS materials, supplies and fossil fuel inventories are carried at the lower of weighted-average cost or market, unless evidence indicates that the weighted-average cost (even if in excess of market) will be recovered.

Fair Value Measurements

We account for derivative instruments, investments held in our nuclear decommissioning trust, certain cash equivalents and plan assets held in our retirement and other benefit plans at fair value on a recurring basis. Due to the short-term nature of net accounts receivable, accounts payable, and short-term borrowings, the carrying values of these instruments approximate fair value. Fair value measurements may also be applied on a nonrecurring basis to other assets and liabilities in certain circumstances such as impairments. We also disclose fair value information for our long-term debt, which is carried at amortized cost (see Note 6).

Fair value is the price that would be received for an asset or paid to transfer a liability (exit price) in the principal or most advantageous market which we can access for the asset or liability in an orderly transaction between willing market participants on the measurement date. Inputs to fair value may include observable and unobservable data. We maximize the use of observable inputs and minimize the use of unobservable inputs when measuring fair value.

We determine fair market value using observable inputs such as actively-quoted prices for identical instruments when available. When actively quoted prices are not available for the identical instruments, we use other observable inputs, such as prices for similar instruments, other corroborative market information, or prices provided by other external sources. For options, long-term contracts and other contracts for which observable price data are not available, we use models and other valuation methods, which may incorporate unobservable inputs to determine fair market value.

The use of models and other valuation methods to determine fair market value often requires subjective and complex judgment. Actual results could differ from the results estimated through application of these methods.

See Note 14 for additional information about fair value measurements.

Derivative Accounting

We are exposed to the impact of market fluctuations in the commodity price and transportation costs of electricity, natural gas, coal, emission allowances and in interest rates. We manage risks associated with market volatility by utilizing various physical and financial 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. The changes in market value of such contracts have a high correlation to price changes in the hedged transactions. We also enter into derivative instruments for economic hedging purposes. 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 expenses in our Consolidated Statements of Income, but does not impact our financial condition, net income or cash flows.

We account for our derivative contracts in accordance with derivatives and hedging guidance, which requires all derivatives not qualifying for a scope exception to be measured at fair value on the balance sheet as either assets or liabilities. Transactions with counterparties that have master netting arrangements are reported net on the balance sheet. See Note 17 for additional information about our derivative instruments.

Loss Contingencies and Environmental Liabilities

Pinnacle West and APS are involved in certain legal and environmental matters that arise in the normal course of business. Contingent losses and environmental liabilities are recorded when it is determined that it is probable that a loss has occurred and the amount of the loss can be reasonably estimated. When a range of the probable loss exists and no amount within the range is a better estimate than any other amount, Pinnacle West and APS record a loss contingency at the minimum amount in the range. Unless otherwise required by GAAP, legal fees are expensed as incurred.

Retirement Plans and Other Benefits

Pinnacle West sponsors a qualified defined benefit and account balance pension plan for the employees of Pinnacle West and its subsidiaries. We also sponsor an other postretirement benefit plan for the employees of Pinnacle West and our subsidiaries that provides medical and life insurance benefits to retired employees. Pension and other postretirement benefit expense are determined by actuarial valuations, based on assumptions that are evaluated annually. See Note 8 for additional information on pension and other postretirement benefits.

Nuclear Fuel

APS amortizes nuclear fuel by using the unit-of-production method. The unit-of-production method is based on actual physical usage. APS divides the cost of the fuel by the estimated number of thermal units it expects to produce with that fuel. APS then multiplies that rate by the number of thermal units produced within the current period. This calculation determines the current period nuclear fuel expense.

APS also charges nuclear fuel expense for the interim storage and permanent disposal of spent nuclear fuel. The DOE is responsible for the permanent disposal of spent nuclear fuel and charges APS $0.001 per kWh of nuclear generation. See Note 11 for information on spent nuclear fuel disposal costs.

Income Taxes

Income taxes are provided using the asset and liability approach prescribed by guidance relating to accounting for income taxes. We file our federal income tax return on a consolidated basis, and we file our state income tax returns on a consolidated or unitary basis. In accordance with our intercompany tax sharing agreement, federal and state income taxes are allocated to each first-tier subsidiary as though each first-tier subsidiary filed a separate income tax return. Any difference between that method and the consolidated (and unitary) income tax liability is attributed to the parent company. The income tax accounts reflect the tax and interest associated with management’s estimate of the largest amount of tax benefit that is greater than 50% likely of being realized upon settlement for all known and measurable tax exposures (see Note 4).

Cash and Cash Equivalents

We consider all highly liquid investments with a remaining maturity of three months or less at acquisition to be cash equivalents.

The following table summarizes supplemental Pinnacle West cash flow information for each of the last three years (dollars in thousands):

		Years ended December 31,
		2013			2012			2011

Cash paid during the period for:
Income taxes, net of refunds		$	18,537		$	2,543		$	10,324
Interest, net of amounts capitalized		184,010			200,923			217,789
Significant non-cash investing and financing activities:
Accrued capital expenditures		$	33,184		$	26,208		$	27,245
Dividends declared but not paid		62,528			59,789			—
Liabilities assumed relating to acquisition of SCE Four Corners’ interest (see Note 3)		145,609			—			—

Intangible Assets

We have no goodwill recorded and have separately disclosed other intangible assets, primarily APS’s software, on Pinnacle West’s Consolidated Balance Sheets. The intangible assets are amortized over their finite useful lives. Amortization expense was $53 million in 2013, $50 million in 2012, and $47 million in 2011. Estimated amortization expense on existing intangible assets over the next five years is $47 million in 2014, $38 million in 2015, $29 million in 2016, $19 million in 2017, and $7 million in 2018. At December 31, 2013, the weighted-average remaining amortization period for intangible assets was 6 years.

Investments

El Dorado accounts for its investments using either the equity method (if significant influence) or the cost method (if less than 20% ownership).

Our investments in the nuclear decommissioning trust fund are accounted for in accordance with guidance on accounting for certain investments in debt and equity securities. See Note 14 and Note 20 for more information on these investments.

Business Segments

Pinnacle West’s reportable business segment is our regulated electricity segment, which consists of traditional regulated retail and wholesale electricity businesses (primarily electricity service to Native Load customers) and related activities and includes electricity generation, transmission and distribution. All other segment activities are insignificant.

New_Accounting_Standards

New Accounting Standards	12 Months Ended
New Accounting Standards	Dec. 31, 2013
New Accounting Standards	'
New Accounting Standards	'
	2. New Accounting Standards

	During 2013, we adopted, on a retrospective basis, new guidance relating to balance sheet offsetting disclosures. The new guidance requires enhanced disclosures regarding an entity’s ability to offset certain instruments on the balance sheet and how offsetting impacts the balance sheet. The adoption of this guidance resulted in expanded disclosures relating to our derivative instruments (see Note 17), but did not impact our financial statement results.

	During 2013, we also adopted, on a prospective basis, new guidance relating to reporting amounts reclassified from accumulated other comprehensive income. This guidance requires new disclosures relating to accumulated other comprehensive income and how reclassifications from accumulated other comprehensive income impact net income. As a result of adopting this new guidance, we have included a new footnote disclosure to provide the information required by the new standard (see Notes 21 and S-4). The adoption of this guidance did not impact our financial statement results.

	In July 2013, new guidance was issued which will generally require entities to present unrecognized tax benefits as a reduction to any available deferred tax asset for a net operating loss, a similar tax loss, or a tax credit carryforward. The intent of this guidance is to eliminate diversity in practice in the presentation of certain unrecognized tax benefits. The new guidance is effective for us during the first quarter of 2014, and is permitted to be adopted using either a prospective or retrospective application. Currently, we do not present unrecognized tax benefits as a reduction to deferred tax asset carryforwards on the balance sheet. As a result, the adoption of this new guidance will impact our balance sheet presentation; however, we do not expect these presentation changes to be material to our balance sheet. The adoption of this new guidance will not impact our results of operations or cash flows.

Regulatory_Matters

Regulatory Matters	12 Months Ended
	Dec. 31, 2013
Regulatory Matters	'
Regulatory Matters	'
	3. Regulatory Matters

	Retail Rate Case Filing with the Arizona Corporation Commission

	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 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 from $0.03757 to $0.03207 per kWh; and (3) the transfer of cost recovery for certain renewable energy projects from the RES surcharge to base rates in an estimated amount of $36.8 million.

	APS also agreed not to file its next general rate case before May 31, 2015, and not to request that its next general retail rate increase be effective prior to July 1, 2016. The 2012 Settlement Agreement allows APS to request a change to its base rates during the stay-out period in the event of an extraordinary event that, in the ACC’s judgment, requires base rate relief in order to protect the public interest. Nor is APS precluded from seeking rate relief, or any other party to the 2012 Settlement Agreement precluded from petitioning the ACC to examine the reasonableness of APS’s rates, in the event of significant regulatory developments that materially impact the financial results expected under the terms of the 2012 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 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 Four Corners (APS made its filing under this provision on December 30, 2013, which would result in an average bill impact to residential customers of approximately 2% if approved as requested);

	· Implementation of a “Lost Fixed Cost Recovery” rate mechanism to support energy efficiency and distributed renewable generation;

	· Modifications to the Environmental Improvement Surcharge 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 PSA, including the elimination of the 90/10 sharing provision;

	· A limitation on the use of the RES surcharge and the DSMAC to recoup capital expenditures not required under the terms of the 2009 Settlement Agreement discussed below;

	· Allowing a negative credit that existed in the PSA rate to continue until February 2013, rather than being reset on the anticipated July 1, 2012 rate effective date;

	· Modification of the 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.

	2008 General Retail Rate Case On-Going Impacts

	On December 30, 2009, the ACC issued an order approving the 2009 Settlement Agreement entered into by APS and twenty-one other parties. The 2009 Settlement Agreement contains certain on-going requirements, commitments and authorizations that will survive the 2012 Settlement Agreement, including the following:

	· A commitment from APS to reduce average annual operational expenses by at least $30 million from 2010 through 2014;

	· Authorization and requirements of equity infusions into APS of $700 million during the period beginning June 1, 2009 through December 31, 2014 and compliance with various financial conditions, including the maintenance of a prescribed capital structure (APS was able to meet these conditions without the need for additional equity infusions beyond the $253 million infused into APS in the second quarter of 2010); and

	· Renewable energy programs that require APS to expand its use of renewable energy through 2015, as well as allow for concurrent recovery of renewable energy expenses.

	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.

	On July 12, 2013, APS filed its annual RES implementation plan, covering the 2014-2018 timeframe and requesting a 2014 RES budget of approximately $143 million. In a final order dated January 7, 2014, the ACC approved the requested budget. Also in 2013, the ACC conducted a hearing to consider APS’s proposal to establish compliance with distributed energy requirements by tracking and recording distributed energy, rather than acquiring and retiring renewable energy credits. On February 6, 2014, the ACC established a proceeding to modify the renewable energy rules so that utilities can establish compliance without using renewable energy credits.

	On July 12, 2013, APS filed an application with the ACC proposing a solution to fix the cost shift brought by the current net metering rules. In its application, APS requested that the ACC cause all new residential customers installing new rooftop solar systems to either: (i) take electric service under APS’s demand-based ECT-2 rate and remain eligible for net metering; or (ii) take service under the customer’s existing rate as if no distributed energy system was installed and receive a bill credit for 100% of the distributed energy system’s output at a market-based price. APS also proposed that the ACC: (i) grandfather current rates and use of net metering for existing and immediately pending distributed energy customers; and (ii) continue using direct cash incentives for new distributed energy installations.

On December 3, 2013, the ACC issued its order on APS’s net metering proposal. The ACC instituted a charge on future customers who install rooftop solar panels and directed APS to provide quarterly reports on the pace of rooftop solar adoption to assist the ACC in considering further increases. 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 electricity grid. The new policy will be in effect until the next APS rate case.

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 electrical grid. ACC professional staff and the state’s Residential Utility Consumer Office, among other organizations, also agreed that a cost shift exists. The fixed charge does not increase APS’s revenue, but instead will modestly reduce the impact of the cost shift on non-solar customers. The ACC acknowledged that the new charge addresses only a portion of the cost shift.

Demand Side Management Adjustor Charge. The ACC Electric Energy Efficiency Standards require APS to submit a Demand Side Management Implementation Plan for review by and approval of the ACC.

On June 1, 2011, APS filed its 2012 Demand Side Management Implementation Plan consistent with the ACC’s Electric Energy Efficiency Rules, which became effective January 1, 2011. The 2012 requirement under such standards is for cumulative energy efficiency savings of 3% of APS retail sales for the prior year. This energy savings requirement is slightly higher than the goal established by the 2009 Settlement Agreement (2.75% of total energy resources for the same two-year period). The ACC issued an order on April 4, 2012, approving recovery of approximately $72 million of APS’s energy efficiency and demand side management program costs. This amount was recovered by the then existing DSMAC over a twelve-month period beginning March 1, 2012. This amount does not include $10 million already being recovered in general retail base rates, but does include amortization of 2009 costs (approximately $5 million of the $72 million).

On June 1, 2012, APS filed its 2013 Demand Side Management Implementation Plan. In 2013, the standards require APS to achieve cumulative energy savings equal to 5% of its 2012 retail energy sales. Later in 2012, APS filed a supplement to its plan that included a proposed budget for 2013 of $87.6 million.

The ACC Staff recommendation and proposed order, issued on October 30, 2013, largely recommended continuing the status quo, although at lower funding levels. ACC Staff recommended approval of all existing cost-effective energy efficiency and demand response programs and a budget of $68.9 million going forward. APS expects to receive a decision from the ACC in early 2014.

On June 27, 2013, the ACC voted to open a new docket investigating whether the Electric Energy Efficiency Rules should be modified or abolished. This spring the ACC will hold a series of three workshops 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.

PSA Mechanism and Balance. The PSA provides for the adjustment of retail rates to reflect variations in retail fuel and purchased power costs. The PSA is subject to specified parameters and procedures, including the following:

· APS records deferrals for recovery or refund to the extent actual retail fuel and purchased power costs vary from the Base Fuel Rate;

· an adjustment to the PSA rate is made annually each February 1st (unless otherwise approved by the ACC) and goes into effect automatically unless suspended by the ACC;

· the PSA uses a forward-looking estimate of fuel and purchased power costs to set the annual PSA rate, which is reconciled to actual costs experienced for each PSA Year (February 1 through January 31) (see the following bullet point);

· the PSA rate includes (a) a “Forward Component,” under which APS recovers or refunds differences between expected fuel and purchased power costs for the upcoming calendar year and those embedded in the Base Fuel Rate; (b) a “Historical Component,” under which differences between actual fuel and purchased power costs and those recovered through the combination of the Base Fuel Rate and the Forward Component are recovered during the next PSA Year; and (c) a “Transition Component,” under which APS may seek mid-year PSA changes due to large variances between actual fuel and purchased power costs and the combination of the Base Fuel Rate and the Forward Component; and

· the PSA rate may not be increased or decreased more than $0.004 per kWh in a year without permission of the ACC.

The following table shows the changes in the deferred fuel and purchased power regulatory asset for 2013 and 2012 (dollars in millions):

		Twelve Months Ended
		December 31,
		2013			2012
Beginning balance		$	73		$	28
Deferred fuel and purchased power costs - current period		(21		)	(72		)
Amounts (charged) credited to customers		(31		)	117
Ending balance		$	21		$	73

The PSA rate for the PSA year beginning February 1, 2014 is $0.001557 per kWh, as compared to $0.001329 per kWh for the prior year. This represents a $0.000228 per kWh increase over the 2013 PSA charge. This new rate is comprised of a forward component of $0.001277 per kWh and a historical component of $0.000280 per kWh. Any uncollected (overcollected) deferrals during the 2014 PSA year will be included in the calculation of the PSA rate for the PSA year beginning February 1, 2015.

Transmission Rates, Transmission Cost Adjustor and Other Transmission Matters. In July 2008, 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 (discussed above), 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 effect on the Retail Transmission Charge because any adjustment, though applied prospectively, may be calculated to account for previously over- or under-collected amounts.

Effective June 1, 2012, APS’s annual wholesale transmission rates for all users of its transmission system increased by approximately $16 million for the twelve-month period beginning June 1, 2012 in accordance with the FERC-approved formula.

Effective June 1, 2013, APS’s annual wholesale transmission rates for all users of its transmission system increased by approximately $26 million for the twelve-month period beginning June 1, 2013 in accordance with the FERC-approved formula. Pursuant to the 2012 Settlement Agreement (discussed above), an adjustment to APS’s retail rates to recover FERC-approved transmission charges went into effect automatically on June 1, 2013.

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 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 or if metering is unavailable, through accepted estimating techniques.

APS filed its first LFCR adjustment on January 15, 2013 and will file for a LFCR adjustment every January thereafter. On February 12, 2013, the ACC approved a LFCR adjustment of $5.1 million, representing a pro-rated amount for 2012 since the 2012 Settlement Agreement went into effect on July 1, 2012. APS filed its 2014 annual LFCR adjustment on January 15, 2014, requesting a LFCR adjustment of $25.3 million, effective March 1, 2014. APS anticipates that the ACC will consider whether to approve APS’s LFCR adjustment prior to the end of March 2014.

Deregulation

On May 9, 2013, the ACC voted to re-examine the facilitation of a deregulated retail electric market in Arizona. The ACC subsequently opened a docket for this matter and received comments from a number of interested parties on the considerations involved in establishing retail electric deregulation in the state. One of these considerations is whether various aspects of a deregulated market, including setting utility rates on a “market” basis, would be consistent with the requirements of the Arizona Constitution. On September 11, 2013, after receiving legal advice from the ACC staff, the ACC voted 4-1 to close the current docket and await full Constitutional authority before any further examination of this matter. The motion approved by the ACC also included opening one or more new dockets in the future to explore options to offer more rate choices to customers and innovative changes within the existing cost-of-service regulatory model that could include elements of competition. The ACC opened a new docket on November 4, 2013 to explore technological advances and innovative changes within the electric utility industry. Workshops in this docket are expected to be held in 2014.

Four Corners

On December 30, 2013, APS purchased SCE’s 48% ownership interest in each of Units 4 and 5 of Four Corners. As a result of this purchase, APS now owns 63% of Units 4 and 5. APS has a total entitlement from Four Corners of 970 MW. The final purchase price for the interest was approximately $182 million. APS acquired assets and assumed certain of SCE’s decommissioning and mine reclamation obligations. We have recognized plant-in-service, net of accumulated depreciation, of $316 million, which includes an acquisition adjustment of $255 million. In addition, we have recognized a liability of $34 million for the decommissioning obligations, $93 million for the mine reclamation obligations, $18 million of other various liabilities, and $11 million of construction work in progress relating to this purchase. These amounts are subject to revision during the measurement period, not to exceed one year, to the extent additional information is obtained about the facts and circumstances that existed as of the acquisition date. While we expect the ACC to approve the recovery of the acquisition adjustment, should recovery be disallowed, it will be reclassified from plant-in-service to goodwill, subject to impairment testing. The decommissioning and mine reclamation obligations were recognized at their fair value. Because APS’s rates are regulated, APS expects to recover the costs of the acquired plant assets, including a return on its investment based on its cost of capital. APS believes this return is consistent with what a market participant would consider to be fair value in APS’s regulatory environment. Accordingly, APS believes the cost of the plant assets approximate their fair value.

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 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. This includes deferral for future recovery of all non-fuel operating cost for the acquired SCE interest in Four Corners, net of the non-fuel operating costs savings resulting from the closure of Four Corners Units 1-3. The 2012 Settlement Agreement also provides for deferral for future recovery of all unrecovered costs incurred in connection with the closure of Four Corners Units 1-3. The deferral balance related to the acquisition of SCE’s interest in Units 4 and 5 and the closure of Four Corners Units 1-3 was $37 million as of December 31, 2013.

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. APS and SCE negotiated an alternate arrangement under which SCE will assign its 1,555 MW capacity rights over the Arizona Transmission System to third-parties, including 300 MW to APS’s marketing and trading group for transmission of the additional power received from Four Corners. This arrangement becomes effective upon FERC approval and will remain in effect until the net payments received by SCE in connection with the assignments reach $40 million, at which time the arrangement and the Transmission Agreement will terminate. APS believes that FERC will approve the alternate arrangement as filed but, if not approved, SCE and APS will again be subject to the terms of the Transmission Termination Agreement. As we previously disclosed, APS believes that the original denial by FERC of rate recovery under the Transmission Termination Agreement constitutes the failure of a condition that relieves APS of its obligations under that agreement. If APS and SCE were unable to determine a resolution through negotiation, the Transmission Termination Agreement requires that disputes be resolved through arbitration. APS is unable to predict the outcome of this matter if it proceeds to arbitration.

Regulatory Assets and Liabilities

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

		Remaining		December 31, 2013					December 31, 2012
		Amortization
		Period		Current			Non-Current		Current		Non-Current
Pension and other postretirement benefits		(a	)	$	—		$	314	$	—	$	780
Income taxes — AFUDC equity		2043		4			105		4		92
Deferred fuel and purchased power — mark-to-market (Note 17)		2016		5			29		19		21
Transmission vegetation management		2016		9			14		9		23
Coal reclamation		2038		8			18		8		24
Palo Verde VIEs (Note 19)		2046		—			41		—		38
Deferred compensation		2036		—			34		—		34
Deferred fuel and purchased power (b) (c)		2014		21			—		73		—
Tax expense of Medicare subsidy		2023		2			15		2		17
Loss on reacquired debt		2034		1			17		2		18
Income taxes — investment tax credit basis adjustment		2043		1			39		1		26
Pension and other postretirement benefits deferral		2015		8			4		8		13
Four Corners cost deferral		2024		—			37		—		—
Lost fixed cost recovery		2014		25			—		7		—
Transmission cost adjustor		2015		8			2		10		—
Retired power plant costs		2020		3			18		—		—
Other		Various		2			25		1		14
Total regulatory assets (d)				$	97		$	712	$	144	$	1,100

(a) This asset represents the future recovery of under-funded pension and other postretirement benefit obligations through retail rates. If these costs are disallowed by the ACC, this regulatory asset would be charged to OCI and result in lower future revenues. See Note 8 for further discussion.
(b) See “Cost Recovery Mechanisms” discussion above.
(c) Subject to a carrying charge.
(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 and Transmission Cost Adjustor.”

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

		Remaining		December 31, 2013					December 31, 2012
		Amortization
		Period		Current			Non-Current		Current		Non-Current
Removal costs		(a	)	$	28		$	303	$	27	$	321
Asset retirement obligations		(a	)	—			266		—		256
Renewable energy standard (b)		2015		33			15		43		—
Income taxes — change in rates		2043		—			74		—		66
Spent nuclear fuel		2047		6			36		10		36
Deferred gains on utility property		2019		2			10		2		12
Income taxes — deferred investment tax credit		2043		3			79		2		52
Demand side management (b)		2014		27			—		4		—
Other		Various		—			18		—		16
Total regulatory liabilities				$	99		$	801	$	88	$	759

(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 (see Note 12).
(b) See “Cost Recovery Mechanisms” discussion above.

Income_Taxes

Income Taxes	12 Months Ended
Income Taxes	Dec. 31, 2013
Income Taxes	'
Income Taxes	'
	4. Income Taxes

	Certain assets and liabilities are reported differently for income tax purposes than they are for financial statement purposes. The tax effect of these differences is recorded as deferred taxes. We calculate deferred taxes using currently enacted income tax rates.

	APS has recorded regulatory assets and regulatory liabilities related to income taxes on its Balance Sheets in accordance with accounting guidance for regulated operations. The regulatory assets are for certain temporary differences, primarily the allowance for equity funds used during construction and pension and other postretirement benefits. The regulatory liabilities primarily relate to deferred taxes resulting from investment tax credits (“ITC”) and the change in income tax rates.

	In accordance with regulatory requirements, APS ITCs are deferred and are amortized over the life of the related property with such amortization applied as a credit to reduce current income tax expense in the statement of income.

	The $70 million long-term income tax receivable on the Consolidated Balance Sheets as of December 31, 2012 represented the anticipated refund related to an APS tax accounting method change approved by the IRS in the third quarter of 2009. On July 9, 2013, IRS guidance was released which provided clarification regarding the timing and amount of this cash receipt. As a result of this guidance, uncertain tax positions decreased $67 million during the third quarter. This decrease in uncertain tax positions resulted in a corresponding increase to the total anticipated refund due from the IRS and an offsetting increase in long-term deferred tax liabilities. Additionally, as a result of this IRS guidance, the resulting $137 million anticipated refund was reclassified to current income tax receivable.

	During the year ended December 31, 2013, the IRS finalized the examination of tax returns for the years ended December 31, 2008 and 2009, and the $137 million anticipated refund was reduced by approximately $4 million to reflect the outcome of this examination. On December 17, 2013, the Joint Committee on Taxation approved the anticipated refund. Cash related to this refund was received in the first quarter of 2014.

	On September 13, 2013, the U.S. Treasury Department released final income tax regulations on the deduction and capitalization of expenditures related to tangible property. These final regulations apply to tax years beginning on or after January 1, 2014. Several of the provisions within the regulations will require a tax accounting method change to be filed with the IRS, resulting in a cumulative effect adjustment. To account for the adoption of these regulations, plant-related long-term deferred tax liabilities decreased by $84 million, with the offsetting decrease to current deferred income tax assets. Prior to the issuance of these regulations, this $84 million would have been repaid over 20 years through lower tax depreciation deductions.

	Net income associated with the Palo Verde sale leaseback VIEs is not subject to tax (see Note 19). As a result, there is no income tax expense associated with the VIEs recorded on the Consolidated Statements of Income.

	The following is a tabular reconciliation of the total amounts of unrecognized tax benefits, excluding interest and penalties, at the beginning and end of the year that are included in accrued taxes and unrecognized tax benefits (dollars in thousands):

			2013			2012			2011
	Total unrecognized tax benefits, January 1		$	133,422		$	136,005		$	127,595
	Additions for tax positions of the current year		3,516			5,167			10,915
	Additions for tax positions of prior years		13,158			—			—
	Reductions for tax positions of prior years for:
	Changes in judgment		(108,099		)	(7,729		)	(1,555		)
	Settlements with taxing authorities		—			—			(124		)
	Lapses of applicable statute of limitations		—			(21		)	(826		)
	Total unrecognized tax benefits, December 31		$	41,997		$	133,422		$	136,005

	Included in the balances of unrecognized tax benefits at December 31, 2013, 2012 and 2011 were approximately $10 million, $10 million and $8 million, respectively, of tax positions that, if recognized, would decrease our effective tax rate.

	As of the balance sheet date, the tax year ended December 31, 2010 and all subsequent tax years remain subject to examination by the IRS. With a few exceptions, we are no longer subject to state income tax examinations by tax authorities for years before 2010.

	We reflect interest and penalties, if any, on unrecognized tax benefits in the Consolidated Statements of Income as income tax expense. The amount of interest recognized in the Consolidated Statements of Income related to unrecognized tax benefits was a pre-tax benefit of $4 million for 2013, a pre-tax expense of $4 million for 2012, and a pre-tax expense of $3 million for 2011.

	The total amount of accrued liabilities for interest recognized in the Consolidated Balance Sheets related to unrecognized tax benefits was less than $1 million as of December 31, 2013, $13 million as of December 31, 2012 and $9 million as of December 31, 2011. To the extent that matters are settled favorably, this amount could reverse and decrease our effective tax rate. Additionally, as of December 31, 2013, we have recognized $5 million of interest income to be received on the overpayment of income taxes for certain adjustments that we have filed, or will file, with the IRS.

	The components of income tax expense are as follows (dollars in thousands):

			Year Ended December 31,
			2013			2012			2011
	Current:
	Federal		$	(81,784	)	$	(3,493	)	$	(310	)
	State		10,537			8,395			15,140
	Total current		(71,247		)	4,902			14,830
	Deferred:
	Federal		279,973			200,322			159,566
	State		21,865			28,280			16,626
	Total deferred		301,838			228,602			176,192
	Total income tax expense		230,591			233,504			191,022
	Less: income tax expense (benefit) on discontinued operations		—			(3,813		)	7,418
	Income tax expense — continuing operations		$	230,591		$	237,317		$	183,604

	The following chart compares pretax income from continuing operations at the 35% federal income tax rate to income tax expense — continuing operations (dollars in thousands):

			Year Ended December 31,
			2013			2012			2011

	Federal income tax expense at 35% statutory rate		$	234,695		$	229,709		$	188,733
	Increases (reductions) in tax expense resulting from:
	State income tax net of federal income tax benefit		21,387			23,819			19,594
	Credits and favorable adjustments related to prior years resolved in current year		(3,356		)	—			—
	Medicare Subsidy Part-D		823			483			823
	Allowance for equity funds used during construction (see Note 1)		(6,997		)	(6,158		)	(6,881		)
Palo Verde VIE noncontrolling interest (see Note 19)		(11,862		)	(11,065		)	(9,636		)
Other		(4,099		)	529			(9,029		)
Income tax expense — continuing operations		$	230,591		$	237,317		$	183,604

The following table shows the net deferred income tax liability recognized on the Consolidated Balance Sheets (dollars in thousands):

		December 31,
		2013			2012
Current asset		$	91,152		$	152,191
Long-term liability		(2,351,882		)	(2,151,371		)
Deferred income taxes — net		$	(2,260,730	)	$	(1,999,180	)

On February 17, 2011, Arizona enacted legislation (H.B. 2001) that included a four-year phase-in of corporate income tax rate reductions beginning in 2014. As a result of these tax rate reductions, Pinnacle West has revised the tax rate applicable to reversing temporary items in Arizona. In accordance with accounting for regulated companies, the benefit of this rate reduction is substantially offset by a regulatory liability. As of December 31, 2013 APS has recorded a regulatory liability of $75 million, with a corresponding decrease in accumulated deferred income tax liabilities, to reflect the impact of this change in tax law.

On April 4, 2013, New Mexico enacted legislation (H.B. 641) that included a five-year phase-in of corporate income tax rate reductions beginning in 2014. As a result of these tax rate reductions, Pinnacle West has revised the tax rate applicable to reversing temporary items in New Mexico. In accordance with accounting for regulated companies, the benefit of this rate reduction is substantially offset by a regulatory liability. As of December 31, 2013, APS has recorded a regulatory liability of $2 million, with a corresponding decrease in accumulated deferred income tax liabilities, to reflect the impact of this change in tax law.

The components of the net deferred income tax liability were as follows (dollars in thousands):

		December 31,
		2013			2012
DEFERRED TAX ASSETS
Risk management activities		$	44,920		$	72,243
Regulatory liabilities:
Asset retirement obligation and removal costs		235,959			238,669
Unamortized investment tax credits		82,116			53,837
Other		42,609			33,764
Pension and other postretirement liabilities		198,642			408,764
Renewable energy incentives		65,434			66,941
Credit and loss carryforwards		133,070			139,022
Other		148,492			68,844
Total deferred tax assets		951,242			1,082,084
DEFERRED TAX LIABILITIES
Plant-related		(2,903,730		)	(2,584,166		)
Risk management activities		(16,191		)	(23,940		)
Regulatory assets:
Allowance for equity funds used during construction		(43,058		)	(37,899		)
Deferred fuel and purchased power		(8,282		)	(28,858		)
Deferred fuel and purchased power — mark-to-market		(13,343		)	(15,796		)
Pension and other postretirement benefits		(129,250		)	(316,757		)
Other		(93,202		)	(68,170		)
Other		(4,916		)	(5,678		)
Total deferred tax liabilities		(3,211,972		)	(3,081,264		)
Deferred income taxes — net		$	(2,260,730	)	$	(1,999,180	)

As of December 31, 2013, the deferred tax assets for credit and loss carryforwards relate to federal general business credits of $131 million which first begin to expire in 2031, and other federal and state loss carryforwards of $2 million which first begin to expire in 2018.

Lines_of_Credit_and_ShortTerm_

Lines of Credit and Short-Term Borrowings

12 Months Ended

Dec. 31, 2013

Lines of Credit and Short-Term Borrowings

5. Lines of Credit and Short-Term Borrowings

The table below presents the consolidated credit facilities and the amounts available and outstanding as of December 31, 2013 (dollars in millions):

Credit Facility

Expiration

Amount

Unused

Commitment

Committed

Amount (a)

Fees

Pinnacle West Revolving Credit Facility

November 2016

200

0.175

APS Revolving Credit Facility

November 2016

500

347

0.125

APS Revolving Credit Facility

April 2018

500

0.125

Total

1,200

1,047

(a) At December 31, 2013, APS had $153 million of outstanding commercial paper. Accordingly, at such date, the total combined amount available under its two $500 million credit facilities was $847 million.

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

Pinnacle West

At December 31, 2013, the Pinnacle West credit facility, which terminates in November 2016, was available to refinance indebtedness of the Company and for other general corporate purposes, including credit support for its $200 million commercial paper program. 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 December 31, 2013, Pinnacle West had no outstanding borrowings under its credit facility, no letters of credit and no commercial paper borrowings.

APS

On April 9, 2013, APS refinanced its $500 million revolving credit facility that would have matured in February 2015, with a new $500 million facility. The new revolving credit facility matures in April 2018.

At December 31, 2013, APS had two credit facilities totaling $1 billion, including a $500 million credit facility that was refinanced in April 2013 (see above) and a $500 million credit facility that matures in November 2016. APS may increase the amount of each facility up to a maximum of $700 million upon the satisfaction of certain conditions and with the consent of the lenders. APS can use these facilities to refinance indebtedness and for other general corporate purposes. Interest rates are based on APS’s senior unsecured debt credit ratings.

APS may increase the amount of each facility up to a maximum of $700 million upon the satisfaction of certain conditions and with the consent of the lenders. APS will use these facilities to refinance indebtedness and for other general corporate purposes. Interest rates are based on APS’s senior unsecured debt credit ratings.

The facilities described above are available to support APS’s $250 million commercial paper program, for bank borrowings or for issuances of letters of credit. At December 31, 2013, APS had no outstanding borrowings or letters of credit under its revolving credit facilities. In addition, APS had commercial paper borrowings of $153 million at December 31, 2013.

See “Financial Assurances” in Note 11 for a discussion of APS’s separate outstanding letters of credit.

The table below presents the consolidated credit facilities and the amounts available and outstanding as of December 31, 2012 (dollars in millions):

Credit Facility

Expiration

Amount

Unused

Commitment

Committed

Amount (a)

Fees

Pinnacle West Revolving Credit Facility

November 2016

200

0.225

APS Revolving Credit Facility

November 2016

500

408

0.175

APS Revolving Credit Facility

February 2015

500

0.2

Total

1,200

1,108

(a) At December 31, 2012, APS had $92 million of outstanding commercial paper. Accordingly, at such date the total combined amount available under its two $500 million credit facilities was $908 million.

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

Pinnacle West

At December 31, 2012, the Pinnacle West credit facility, which matures in November 2016, was available to refinance indebtedness of the Company and for other general corporate purposes, including credit support for its $200 million commercial paper program. 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 December 31, 2012, Pinnacle West had no outstanding borrowings under its credit facility, no letters of credit and no commercial paper borrowings.

APS

The facilities described above are available to support APS’s $250 million commercial paper program, for bank borrowings or for issuances of letters of credit. At December 31, 2012, APS had no outstanding borrowings or letters of credit under its revolving credit facilities. In addition, APS had commercial paper borrowings of $92 million at December 31, 2012.

See “Financial Assurances” in Note 11 for a discussion of APS’s separate outstanding letters of credit.

Debt Provisions

Although provisions in APS’s articles of incorporation and ACC financing orders establish maximum amounts of preferred stock and debt that APS may issue, APS does not expect any of these provisions to limit its ability to meet its capital requirements. On February 6, 2013, the ACC issued a financing order in which, subject to specified parameters and procedures, it (a) approved APS’s short-term debt authorization equal to a sum of (i) 7% of APS’s capitalization, and (ii) $500 million (which is required to be used for costs relating to purchases of natural gas and power), (b) approved an increase in APS’s long-term debt authorization from $4.2 billion to $5.1 billion in light of the projected growth of APS and its customer base and the resulting projected financing needs, and (c) authorized APS to enter into derivative financial instruments for the purpose of managing interest rate risk associated with its long- and short-term debt. This financing order is set to expire on December 31, 2017.

LongTerm_Debt_and_Liquidity_Ma

Long-Term Debt and Liquidity Matters	12 Months Ended
Long-Term Debt and Liquidity Matters	Dec. 31, 2013
Long-Term Debt and Liquidity Matters	'
Long-Term Debt and Liquidity Matters	'
	6. Long-Term Debt and Liquidity Matters

	All of Pinnacle West’s and APS’s debt is unsecured. The following table presents the components of long-term debt on the Consolidated Balance Sheets outstanding at December 31, 2013 and 2012 (dollars in thousands):

		Maturity		Interest		December 31,
		Dates (a)		Rates		2013			2012
	APS
	Pollution Control Bonds:
	Variable	2029-2038		(b)		$	75,580		$	75,580
	Fixed	2024-2034		1.25%-6.00%		426,125			490,275
	Total Pollution Control Bonds					501,705			565,855

	Senior unsecured notes	2014-2042		4.50%-8.75%		2,675,000			2,575,000
	Palo Verde sale leaseback lessor notes	2015		8.00%		38,869			65,547
	Unamortized discount					(8,732		)	(9,486		)
	Unamortized premium					5,047			—
	Total APS long-term debt					3,211,889			3,196,916
	Less current maturities	(d)				540,424			122,828
	Total APS long-term debt less current maturities					2,671,465			3,074,088
	Pinnacle West
	Term loan	2015		(c)		125,000			125,000
	TOTAL LONG-TERM DEBT LESS CURRENT MATURITIES					$	2,796,465		$	3,199,088

	(a) This schedule does not reflect the timing of redemptions that may occur prior to maturities.
	(b) The weighted-average rate for the variable rate pollution control bonds was 0.03%-0.06% at December 31, 2013 and 0.13%-0.15% at December 31, 2012.
	(c) The weighted-average interest rate was 1.269% at December 31, 2013 and 1.312% at December 31, 2012.
	(d) Current maturities include $215 million of pollution control bonds expected to be remarketed in 2014 and $300 million in senior unsecured notes that mature in 2014.

	The following table shows principal payments due on Pinnacle West’s and APS’s total long-term debt (dollars in millions):

	Year	Consolidated			Consolidated
	Year	Pinnacle West			APS
	2014	$	540		$	540
	2015	470			345
	2016	358			358
	2017	—			—
	2018	32			32
	Thereafter	1,940			1,940
	Total	$	3,340		$	3,215

	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 represents the estimated fair value of our long-term debt, including current maturities (dollars in millions):

		As of						As of
		December 31, 2013						December 31, 2012
		Carrying			Fair Value			Carrying			Fair Value
		Amount			Fair Value			Amount			Fair Value

	Pinnacle West	$	125		$	125		$	125		$	125
	APS	3,212			3,454			3,197			3,750
	Total	$	3,337		$	3,579		$	3,322		$	3,875

	Credit Facilities and Debt Issuances

	APS

	On March 22, 2013, APS issued an additional $100 million par amount of its outstanding 4.50% unsecured senior notes that mature on April 1, 2042. The net proceeds from the sale were used to repay short-term commercial paper borrowings and replenish cash used to redeem certain tax-exempt indebtedness in November 2012.

	On May 1, 2013, APS purchased all $32 million of the Maricopa County, Arizona Pollution Control Corporation Pollution Control Revenue Refunding Bonds, 2009 Series C, due 2029. On May 28, 2013, we remarketed the bonds. The interest rate for these bonds was set to a new term rate. The new term rate for these bonds ends, subject to a mandatory tender, on May 30, 2018. During this time, the bonds will bear interest at a rate of 1.75% per annum. These bonds are classified as long-term debt on our Consolidated Balance Sheets at December 31, 2013 and were classified as current maturities of long-term debt on our Consolidated Balance Sheets at December 31, 2012.

	On July 12, 2013, APS purchased all $33 million of the Coconino County, Arizona Pollution Control Corporation Pollution Control Revenue Refunding Bonds, 1994 Series A, due 2029. On January 15, 2014, these bonds were canceled. These bonds were classified as current maturities of long-term debt on our Consolidated Balance Sheets at December 31, 2012.

On October 11, 2013, APS purchased all $32 million of the City of Farmington, New Mexico Pollution Control Revenue Bonds, 1994 Series C, due 2024. On January 15, 2014, these bonds were canceled. These bonds were classified as current maturities of long-term debt on our Consolidated Balance Sheets at December 31, 2012.

On January 10, 2014, APS issued $250 million of 4.70% unsecured senior notes that mature on January 15, 2044. The proceeds from the sale were used to repay commercial paper which was used to fund the purchase price and costs associated with the acquisition of SCE’s 48% ownership interest in each of Units 4 and 5 of Four Corners and to replenish cash used to re-acquire two series of tax-exempt indebtedness.

See “Lines of Credit and Short-Term Borrowings” in Note 5 and “Financial Assurances” in Note 11 for discussion of APS’s other letters of credit.

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 December 31, 2013, the ratio was approximately 47% for Pinnacle West and 45% 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 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.

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 December 31, 2013, APS was in compliance with this common equity ratio requirement. Its total shareholder equity was approximately $4.3 billion, and total capitalization was approximately $7.5 billion. APS would be prohibited from paying dividends if the payment would reduce its total shareholder equity below approximately $3.0 billion, assuming APS’s total capitalization remains the same. Since APS was in compliance with this common equity ratio requirement, this restriction does not materially affect Pinnacle West’s ability to meet its ongoing capital requirements.

Common_Stock_and_Treasury_Stoc

Common Stock and Treasury Stock	12 Months Ended
Common Stock and Treasury Stock	Dec. 31, 2013
Common Stock and Treasury Stock	'
Common Stock and Treasury Stock	'
	7. Common Stock and Treasury Stock

	Our common stock and treasury stock activity during each of the three years 2013, 2012 and 2011 is as follows (dollars in thousands):

		Common Stock			Treasury Stock
		Shares	Amount		Shares		Amount
	Balance at December 31, 2010	108,820,067	$	2,421,372	(50,410	)	$	(2,239	)

	Common stock issuance	536,907	22,875		—		—
	Purchase of treasury stock (a)	—	—		(88,440	)	(3,720		)
	Reissuance of treasury stock for stock compensation	—	—		27,689		1,242
	Balance at December 31, 2011	109,356,974	2,444,247		(111,161	)	(4,717		)

	Common stock issuance	480,983	22,676		—		—
	Purchase of treasury stock (a)	—	—		(89,629	)	(4,607		)
	Reissuance of treasury stock for stock compensation	—	—		105,598		5,113
	Balance at December 31, 2012	109,837,957	2,466,923		(95,192	)	(4,211		)

	Common stock issuance	442,746	24,635		—		—
	Purchase of treasury stock (a)	—	—		(174,290	)	(9,727		)
	Reissuance of treasury stock for stock compensation	—	—		170,538		9,630
	Balance at December 31, 2013	110,280,703	$	2,491,558	(98,944	)	$	(4,308	)

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

	At December 31, 2013, Pinnacle West had 10 million shares of serial preferred stock authorized with no par value, none of which was outstanding, and APS had 15,535,000 shares of various types of preferred stock authorized with $25, $50 and $100 par values, none of which was outstanding.

Retirement_Plans_and_Other_Ben

Retirement Plans and Other Benefits	12 Months Ended
Retirement Plans and Other Benefits	Dec. 31, 2013
Retirement Plans and Other Benefits	'
Retirement Plans and Other Benefits	'
	8. Retirement Plans and Other Benefits

	Pinnacle West sponsors a qualified defined benefit and account balance pension plan (The Pinnacle West Capital Corporation Retirement Plan) and a non-qualified supplemental excess benefit retirement plan for the employees of Pinnacle West and its subsidiaries. All new employees participate in the account balance plan. Defined benefit plans specify the amount of benefits a plan participant is to receive using information about the participant. The pension plan covers nearly all employees. The supplemental excess benefit retirement plan covers officers of the Company and highly compensated employees designated for participation by the Board of Directors. Our employees do not contribute to the plans. Generally, we calculate the benefits based on age, years of service and pay.

	Pinnacle West also sponsors an other postretirement benefit plan (Pinnacle West Capital Corporation Group Life and Medical Plan) for the employees of Pinnacle West and its subsidiaries. This plan provides medical and life insurance benefits to retired employees. Employees must retire to become eligible for these retirement benefits, which are based on years of service and age. For the medical insurance plan, retirees make contributions to cover a portion of the plan costs. For the life insurance plan, retirees do not make contributions. We retain the right to change or eliminate these benefits.

	Pinnacle West uses a December 31 measurement date each year for its pension and other postretirement benefit plans. The market-related value of our plan assets is their fair value at the measurement date. See Note 14 for further discussion of how fair values are determined. Due to subjective and complex judgments, which may be required in determining fair values, actual results could differ from the results estimated through the application of these methods.

	A significant portion of the changes in the actuarial gains and losses of our pension and postretirement plans is attributable to APS and therefore is recoverable in rates. Accordingly, these changes are recorded as a regulatory asset. In its 2009 retail rate case settlement, APS received approval to defer a portion of pension and other postretirement benefit cost increases incurred in 2011 and 2012. We deferred pension and other postretirement benefit costs of approximately $14 million in 2012 and $11 million in 2011. Pursuant to an ACC regulatory order, we began amortizing the regulatory asset over 3 years beginning in July 2012. We amortized approximately $8 million during 2013 and $4 million during 2012.

	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 to the regulatory asset) (dollars in thousands):

			Pension									Other Benefits
			2013			2012			2011			2013			2012			2011
	Service cost-benefits earned during the period		$	64,195		$	63,502		$	57,605		$	23,597		$	27,163		$	21,856
	Interest cost on benefit obligation		112,392			119,586			124,727			41,536			46,467			46,807
	Expected return on plan assets		(146,333		)	(140,979		)	(133,678		)	(45,717		)	(45,793		)	(41,536		)
	Amortization of:
	Transition obligation		—			—			—			—			452			452
	Prior service cost (credit)		1,097			1,143			1,400			(179		)	(179		)	(179		)
	Net actuarial loss		39,852			44,250			25,956			11,310			20,233			15,015
	Net periodic benefit cost		$	71,203		$	87,502		$	76,010		$	30,547		$	48,343		$	42,415
	Portion of cost charged to expense		$	38,968		$	36,333		$	29,312		$	18,469		$	19,321		$	15,208

	The following table shows the plans’ changes in the benefit obligations and funded status for the years 2013 and 2012 (dollars in thousands):

			Pension						Other Benefits
			2013			2012			2013			2012
	Change in Benefit Obligation
	Benefit obligation at January 1		$	2,850,846		$	2,699,126		$	990,418		$	1,047,094
	Service cost		64,195			63,502			23,597			27,163
	Interest cost		112,392			119,586			41,536			46,467
	Benefit payments		(125,269		)	(113,632		)	(26,675		)	(26,279		)
	Actuarial (gain) loss		(255,634		)	82,264			(138,458		)	(104,027		)
	Benefit obligation at December 31		2,646,530			2,850,846			890,418			990,418

	Change in Plan Assets
	Fair value of plan assets at January 1		2,079,181			1,850,550			684,221			608,663
	Actual return on plan assets		150,546			259,363			76,995			83,567
	Employer contributions		140,500			65,000			14,438			22,707
	Benefit payments		(106,106		)	(95,732		)	(27,315		)	(30,716		)
	Fair value of plan assets at December 31		2,264,121			2,079,181			748,339			684,221
	Funded Status at December 31		$	(382,409	)	$	(771,665	)	$	(142,079	)	$	(306,197	)

	The following table shows the projected benefit obligation and the accumulated benefit obligation for pension plans with an accumulated obligation in excess of plan assets as of December 31, 2013 and 2012 (dollars in thousands):

			2013			2012
	Projected benefit obligation		$	2,646,530		$	2,850,846
	Accumulated benefit obligation		2,469,889			2,646,306
	Fair value of plan assets		2,264,121			2,079,181


	The following table shows the amounts recognized on the Consolidated Balance Sheets as of December 31, 2013 and 2012 (dollars in thousands):

			Pension						Other Benefits
			2013			2012			2013			2012
	Current liability		$	(10,860	)	$	(19,107	)	$	—		$	—
	Noncurrent liability		(371,549		)	(752,558		)	(142,079		)	(306,197		)
	Net amount recognized		$	(382,409	)	$	(771,665	)	$	(142,079	)	$	(306,197	)

	The following table shows the details related to accumulated other comprehensive loss as of December 31, 2013 and 2012 (dollars in thousands):

			Pension						Other Benefits
		2013			2012			2013			2012
Net actuarial loss		$	344,540		$	644,239		$	57,816		$	238,862
Prior service cost (credit)		2,072			3,169			(296		)	(475		)
APS’s portion recorded as a regulatory asset		(265,107		)	(550,471		)	(49,298		)	(230,020		)
Income tax benefit		(32,204		)	(38,303		)	(2,528		)	(2,585		)
Accumulated other comprehensive loss		$	49,301		$	58,634		$	5,694		$	5,782

The following table shows the estimated amounts that will be amortized from accumulated other comprehensive loss and regulatory assets into net periodic benefit cost in 2014 (dollars in thousands):

		Pension			Other
		Pension			Benefits
Net actuarial loss		$	8,363		$	—
Prior service cost (credit)		874			(179		)
Total amounts estimated to be amortized from accumulated other comprehensive loss and regulatory assets in 2014		$	9,237		$	(179	)

The following table shows the weighted-average assumptions used for both the pension and other benefits to determine benefit obligations and net periodic benefit costs:

		Benefit Obligations				Benefit Costs
		As of December 31,				For the Years Ended December 31,
		2013		2012		2013		2012		2011
Discount rate – pension		4.88	%	4.01	%	4.01	%	4.42	%	5.31	%
Discount rate – other benefits		5.1	%	4.2	%	4.2	%	4.59	%	5.49	%
Rate of compensation increase		4	%	4	%	4	%	4	%	4	%
Expected long-term return on plan assets		N/A		N/A		7	%	7.75	%	7.75	%
Initial healthcare cost trend rate		7.5	%	7.5	%	7.5	%	7.5	%	8	%
Ultimate healthcare cost trend rate		5	%	5	%	5	%	5	%	5	%
Number of years to ultimate trend rate		4		4		4		4		4

In selecting the pretax expected long-term rate of return on plan assets, we consider past performance and economic forecasts for the types of investments held by the plan. For 2014, we are assuming a 6.9% long-term rate of return for pension assets and 7.1% (before tax) for other benefit assets, which we believe is reasonable given our asset allocation in relation to historical and expected performance.

The assumed healthcare cost trend rates shown above have a significant effect on the amounts reported for the healthcare plans. In selecting our healthcare trend rates, we consider past performance and forecasts of healthcare costs. A one percentage point change in the assumed initial and ultimate healthcare cost trend rates would have the following effects (dollars in millions):

		1% Increase			1% Decrease
Effect on other postretirement benefits expense, after consideration of amounts capitalized or billed to electric plant participants		$	13		$	(10	)
Effect on service and interest cost components of net periodic other postretirement benefit costs		14			(11		)
Effect on the accumulated other postretirement benefit obligation		149			(120		)


Plan Assets

The Board of Directors has delegated oversight of the pension and other postretirement benefit plans’ assets to an Investment Management Committee (“Committee”). The Committee has adopted investment policy statements (“IPS”) for the pension and the other postretirement benefit plans’ assets. The investment strategies for these plans include external management of plan assets, and prohibition of investments in Pinnacle West securities.

The overall strategy of the pension plan’s IPS is to achieve an adequate level of trust assets relative to the benefit obligations. To achieve this objective, the plan’s investment policy provides for mixes of investments including long-term fixed income assets and return-generating assets. The target allocation between return-generating and long-term fixed income assets is defined in the IPS and is a function of the plan’s funded status. The plan’s funded status is reviewed on at least a monthly basis.

Long-term fixed income assets, also known as liability-hedging assets, are designed to offset changes in the benefit obligations due to changes in interest rates. Long-term fixed income assets consist primarily of fixed income debt securities issued by the U.S. Treasury, other government agencies, and corporations. Long-term fixed income assets may also include interest rate swaps, U.S. Treasury futures and other instruments.

Return-generating assets are intended to provide a reasonable long-term rate of investment return with a prudent level of volatility. Return-generating assets are composed of U.S. equities, international equities, and alternative investments. International equities include investments in both developed and emerging markets. Alternative investments include investments in real estate, private equity and various other strategies. The plan may hold investments in return-generating assets by holding securities in common and collective trusts.

Based on the IPS, and given the pension plan’s funded status at year-end 2013, the long-term fixed income assets had a target allocation of 58% with a permissible range of 55% to 61% and the return-generating assets had a target allocation of 42% with a permissible range of 45% to 39%. The return-generating assets have additional target allocations, as a percent of total plan assets, of 22% equities in U.S. and other developed markets, 6% equities in emerging markets, and 14% in alternative investments. The pension plan IPS does not provide for a specific mix of long-term fixed income assets, but does expect the average credit quality of such assets to be investment grade. As of December 31, 2013, long-term fixed income assets represented 55% of total pension plan assets, and return-generating assets represented 45% of total pension plan assets.

The asset allocation for other postretirement benefit plan assets is governed by the IPS for those plans, which provides for an asset allocation target mix of generally 25% of fixed income assets and 75% of non-fixed income assets. This asset allocation target mix does not vary with the plan’s funded status. As of December 31, 2013, investment in fixed income assets represented 38% of the other postretirement benefit plan total assets, and non-fixed income assets represented 62% of the other postretirement benefit plan’s assets. Fixed income assets are primarily invested in corporate bonds of investment-grade U.S. issuers, and U.S. Treasuries. Non-fixed income assets are primarily invested in large cap U.S. equities in diverse industries, and international equities in both emerging and developed markets.

See Note 14 for a discussion on the fair value hierarchy and how fair value methodologies are applied. The plans invest directly in fixed income and equity securities, in addition to investing indirectly in fixed income securities, equity securities and real estate through the use of common and collective trusts. Equity securities held directly by the plans are valued using quoted active market prices from the published exchange on which the equity security trades, and are classified as Level 1. Fixed income securities issued by the U.S. Treasury held directly by the plans are valued using quoted active market prices, and are classified as Level 1. Fixed income securities issued by corporations, municipalities, and other agencies are primarily valued using quoted inactive market prices, or quoted active market prices for similar securities, or by utilizing calculations which incorporate observable inputs such as yield, maturity and credit quality. These instruments are classified as Level 2.

The common and collective trusts, which are similar to mutual funds, are maintained by banks or investment companies and hold certain investments in accordance with a stated set of objectives (such as tracking the performance of the S&P 500 Index). Common and collective trusts are valued using the concept of net asset value (“NAV”), which is a value derived from the quoted active market prices of the underlying securities. The plans’ common and collective real estate trust is valued using NAV, which is derived from the appraised values of the trust’s underlying real estate assets. As of December 31, 2013, the plans were able to transact in the common and collective trusts at NAV and accordingly classify these investments as Level 2. Because the trust’s shares are offered to a limited group of investors, they are not considered to be traded in an active market.

The plans’ trustee provides valuation of our plan assets by using pricing services that utilize methodologies described to determine fair market value. We have internal control procedures 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 reports on the trustee’s internal operating controls and valuation processes.

The fair value of Pinnacle West’s pension plan and other postretirement benefit plan assets at December 31, 2013, by asset category, are as follows (dollars in thousands):

		Quoted Prices			Significant			Significant			Other (c)			Balance at
		in Active			Other			Unobservable						December 31,
		Markets for			Observable			Inputs						2013
		Identical			Inputs			(Level 3)
		Assets			(Level 2)
		(Level 1)
Pension Plan:
Assets:
Cash and cash equivalents		$	504		$	—		$	—		$	—		$	504
Fixed Income Securities:
Corporate		—			898,621			—			—			898,621
U.S. Treasury		231,590			—			—			—			231,590
Other (b)		—			84,011			—			—			84,011
Equities:
U.S. Companies		239,036			—			—			—			239,036
International Companies		19,429			—			—			—			19,429
Common and collective trusts:
U.S. Equities		—			116,150			—			—			116,150
International Equities		—			367,551			—			—			367,551
Fixed Income					137,520									137,520
Real estate		—			119,739			—			—			119,739
Short-term investments and other		—			41,060			8,660		(a)	250			49,970

Total Pension Plan		$	490,559		$	1,764,652		$	8,660		$	250		$	2,264,121
Other Benefits:
Assets:
Fixed Income Securities:
Corporate		$	—		$	153,888		$	—		$	—		$	153,888
U.S. Treasury		98,704			—			—			—			98,704
Other (b)		—			27,936			—			—			27,936
Equities:
U.S. Companies		252,181			—			—			—			252,181
International Companies		20,892			—			—			—			20,892
Common and collective trusts:
U.S. Equities		—			80,751			—			—			80,751
International Equities		—			92,382			—			—			92,382
Real Estate		—			10,761			—			—			10,761
Short-term investments and other		—			8,414			—			2,430			10,844

Total Other Benefits		$	371,777		$	374,132		$	—		$	2,430		$	748,339

(a) Represents investments in a partnership that invests in privately held portfolio companies.
(b) This category consists primarily of debt securities issued by municipalities.
(c) Represents plan receivables and payables.

The fair value of Pinnacle West’s pension plan and other postretirement benefit plan assets at December 31, 2012, by asset category, are as follows (dollars in thousands):

		Quoted Prices			Significant			Significant			Other (c)			Balance at
		in Active			Other			Unobservable						December 31,
		Markets for			Observable			Inputs						2012
		Identical			Inputs			(Level 3)
		Assets			(Level 2)
		(Level 1)
Pension Plan:
Assets:
Cash and cash equivalents		$	579		$	—		$	—		$	—		$	579
Fixed Income Securities:
Corporate		—			607,749			—			—			607,749
U.S. Treasury		232,161			—			—			—			232,161
Other (b)		—			67,992			—			—			67,992
Equities:
U.S. Companies		531,291			—			—			—			531,291
International Companies		43,848			—			—			—			43,848
Common and collective trusts:
U.S. Equities		—			176,694			—			—			176,694
International Equities		—			271,735			—			—			271,735
Real estate		—			117,854			—			—			117,854
Short-term investments and other		—			26,922			2,419		(a)	(63		)	29,278

Total Pension Plan		$	807,879		$	1,268,946		$	2,419		$	(63	)	$	2,079,181
Other Benefits:
Assets:
Cash and cash equivalents		$	60		$	—		$	—		$	—		$	60
Fixed Income Securities:
Corporate		—			163,306			—			—			163,306
U.S. Treasury		112,558			—			—			—			112,558
Other (b)		—			33,998			—			—			33,998
Equities:
U.S. Companies		205,714			—			—			—			205,714
International Companies		14,412			—			—			—			14,412
Common and collective trusts:
U.S. Equities		—			60,038			—			—			60,038
International Equities		—			76,969			—			—			76,969
Real Estate		—			9,378			—			—			9,378
Short-term investments and other		402			6,340			—			1,046			7,788

Total Other Benefits		$	333,146		$	350,029		$	—		$	1,046		$	684,221

(a) Represents investments in a partnership that invests in privately held portfolio companies.
(b) This category consists primarily of debt securities issued by municipalities.
(c) Represents plan receivables and payables.

The following table shows the changes in fair value for assets that are measured at fair value on a recurring basis using significant unobservable inputs (Level 3) for the year ended December 31, 2013 and 2012 (dollars in thousands):

		Pension
Short-Term Investments and Other		2013			2012
Beginning balance at January 1		$	2,419		$	—
Actual return on assets still held at December 31		(498		)	(668		)
Purchases, sales, and settlements		6,739			3,087
Transfers in and/or out of Level 3		—			—
Ending balance at December 31		$	8,660		$	2,419

Contributions

Future year contribution amounts are dependent on plan asset performance and plan actuarial assumptions. We made contributions to our pension plan totaling $141 million in 2013, $65 million in 2012, and zero in 2011. The minimum contributions for the pension plan total $141 million for the next three years under the recently enacted Moving Ahead for Progress in the 21st Century Act (zero in 2014, $19 million in 2015, and $122 million in 2016). Instead, we expect to make voluntary contributions totaling $300 million for the next three years ($175 million in 2014, of which $70 million was already contributed in early 2014, up to $100 million in 2015, and up to $25 million in 2016). With regard to contributions to our other postretirement benefit plans, we made a contribution of approximately $14 million in 2013, $23 million in 2012, and $19 million in 2011. The contributions to our other postretirement benefit plans for 2014, 2015 and 2016 are expected to be approximately $10 million each year. APS funds its share of the contributions. APS’s share of the pension plan contribution was $140 million in 2013, $64 million in 2012, and zero in 2011. APS’s share of the contributions to the other postretirement benefit plan was $14 million in 2013, $22 million in 2012, and $19 million in 2011.

Estimated Future Benefit Payments

Benefit payments, which reflect estimated future employee service, for the next five years and the succeeding five years thereafter, are estimated to be as follows (dollars in thousands):

Year		Pension			Other Benefits
2014		$	129,159		$	28,664
2015		143,452			31,804
2016		149,105			34,933
2017		162,678			37,966
2018		169,064			40,972
Years 2019-2023		972,826			245,366


Electric plant participants contribute to the above amounts in accordance with their respective participation agreements.

Employee Savings Plan Benefits

Pinnacle West sponsors a defined contribution savings plan for eligible employees of Pinnacle West and its subsidiaries. In 2013, costs related to APS’s employees represented 99% of the total cost of this plan. In a defined contribution savings plan, the benefits a participant receives result from regular contributions participants make to their own individual account, the Company’s matching contributions and earnings or losses on their investments. Under this plan, the Company matches a percentage of the participants’ contributions in cash which is then invested in the same investment mix as participants elect to invest their own future contributions. Pinnacle West recorded expenses for this plan of approximately $9 million for 2013, $8 million for 2012, and $8 million for 2011.

Leases

Leases	12 Months Ended
	Dec. 31, 2013
Leases	'
Leases	'
	9. Leases

	We lease certain vehicles, land, buildings, equipment and miscellaneous other items through operating rental agreements with varying terms, provisions and expiration dates.

	Total lease expense recognized in the Consolidated Statements of Income was $18 million in 2013, $19 million in 2012, and $21 million in 2011. APS’s lease expense was $15 million in 2013, $16 million in 2012, and $18 million in 2011.

	Estimated future minimum lease payments for Pinnacle West’s and APS’s operating leases, excluding purchased power agreements, are approximately as follows (dollars in millions):

	Year	Pinnacle West		APS
		Consolidated
	2014	$	20	$	17
	2015	17		14
	2016	6		5
	2017	5		5
	2018	4		4
	Thereafter	59		59
	Total future lease commitments	$	111	$	104

	In 1986, APS entered into agreements with three separate lessor trust entities in order to sell and lease back interests in Palo Verde Unit 2 and related common facilities. These lessor trust entities have been deemed VIEs for which APS is the primary beneficiary. As the primary beneficiary, APS consolidated these lessor trust entities. The above lease disclosures exclude the impacts of these sale leaseback transactions, as lease accounting for these agreements is eliminated upon consolidation. See Note 19 for a discussion of VIEs.

JointlyOwned_Facilities

Jointly-Owned Facilities	12 Months Ended
	Dec. 31, 2013
Jointly-Owned Facilities	'
Jointly-Owned Facilities	'
	10. Jointly-Owned Facilities

	APS shares ownership of some of its generating and transmission facilities with other companies. We are responsible for our share of operating costs, as well as for providing our own financing. Our share of operating expenses and utility plant costs related to these facilities is accounted for using proportional consolidation. The following table shows APS’s interests in those jointly-owned facilities recorded on the Consolidated Balance Sheets at December 31, 2013 (dollars in thousands):

		Percent		Plant in		Accumulated		Construction
		Owned		Service		Depreciation		Work in
								Progress
	Generating facilities:
	Palo Verde Units 1 and 3	29.1	%	$	1,701,844	$	1,027,523	$	22,400
	Palo Verde Unit 2 (a)	16.8	%	543,972		338,918		10,095
	Palo Verde Common	28	% (b)	538,818		219,801		81,599
	Palo Verde Sale Leaseback		(a)	351,050		225,925		—
	Four Corners Units 4, 5 and Common (d)	63	%	809,946		608,194		14,434
	Navajo Generating Station Units 1, 2 and 3	14	%	270,448		150,501		2,864
	Cholla common facilities (c)	63.3	% (b)	148,299		47,851		7,159
	Transmission facilities:
	ANPP 500kV System	34.2	% (b)	98,145		32,350		1,095
	Navajo Southern System	22.2	% (b)	58,702		16,937		518
	Palo Verde — Yuma 500kV System	18	% (b)	12,115		4,656		11,786
	Four Corners Switchyards	48.1	% (b)	33,460		9,052		185
	Phoenix — Mead System	17.1	% (b)	39,758		12,140		—
	Palo Verde — Estrella 500kV System	50	% (b)	89,571		14,883		21
	Morgan — Pinnacle Peak System	64.5	% (b)	130,132		6,651		1,042
	Round Valley System	50	% (b)	488		268		—
	Palo Verde — Morgan System	90	% (b)	—		—		36,601


	(a) See Note 19.
	(b) Weighted-average of interests.
	(c) PacifiCorp owns Cholla Unit 4 and APS operates the unit for PacifiCorp. The common facilities at Cholla are jointly-owned.
	(d) See Note 3.

Commitments_and_Contingencies

Commitments and Contingencies

12 Months Ended

Dec. 31, 2013

Commitments and Contingencies.

Commitments and Contingencies

11. 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 breach of contract lawsuit against the DOE in the United States Court of Federal Claims. The lawsuit seeks to recover damages incurred due to DOE’s breach of the Standard Contract for failing to accept Palo Verde 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 NWPA. This lawsuit is currently pending in the Court of Federal Claims.

APS currently estimates it will incur $122 million over the current life of Palo Verde for its share of the costs related to the on-site interim storage of spent nuclear fuel. At December 31, 2013, APS had a regulatory liability of $42 million that represents amounts recovered in retail rates in excess of amounts spent for on-site interim spent fuel storage.

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 $13.6 billion per occurrence. Palo Verde maintains the maximum available nuclear liability insurance in the amount of $375 million, which is provided by commercial insurance carriers. The remaining balance of $13.2 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 assessment per reactor under the program for each nuclear 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 interest in the three Palo Verde units, APS’s maximum potential retrospective assessment per incident for all three units is approximately $111 million, with an annual payment limitation of approximately $16.4 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 $2.75 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 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”). Effective April 1, 2013, a sublimit of $1.5 billion for non-nuclear property damage losses site-wide has been imposed on the NEIL property policies. Effective April 1, 2013, a sublimit of $327.6 million per unit has been imposed on the non-nuclear losses covered by the NEIL accidental outage policy, potentially subject to further limitations. APS is subject to retrospective 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 $18 million for each retrospective 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 $48 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.

Fuel and Purchased Power Commitments and Purchase Obligations

APS is party to purchase obligations and various fuel and purchased power contracts with terms expiring between 2014 and 2043 that include required purchase provisions. APS estimates the contract requirements to be approximately $729 million in 2014; $628 million in 2015; $638 million in 2016; $613 million in 2017; $580 million in 2018; and $8.7 billion thereafter. These fuel and purchased power commitments include the amounts incurred from acquiring SCE’s interest in Four Corners. However, these amounts may vary significantly pursuant to certain provisions in such contracts that permit us to decrease required purchases under certain circumstances.

Of the various fuel and purchased power contracts mentioned above, some of those contracts for coal supply include take-or-pay provisions. The current coal contracts with take-or-pay provisions have terms that expire in 2031.

The following table summarizes our estimated coal take-or-pay commitments (dollars in millions):

Years Ended December 31,

2014

2015

2016

2017

2018

Thereafter

Coal take-or-pay commitments (a)

152

157

166

180

175

2,539

(a) Total take-or-pay commitments are approximately $3.4 billion. The total net present value of these commitments is approximately $2.2 billion.

APS spends more to meet its actual fuel requirements than the minimum purchase obligations in our coal take-or-pay contracts. The following table summarizes the actual amounts purchased under the coal contracts which include take-or-pay provisions for each of the last three years (dollars in millions):

Year Ended December 31,

2013

2012

2011

Total purchases

188

196

191

Renewable Energy Credits

APS has entered into contracts to purchase renewable energy credits to comply with the RES. APS estimates the contract requirements to be approximately $48 million in 2014; $42 million in 2015; $42 million in 2016; $42 million in 2017; $42 million in 2018; and $453 million thereafter. These amounts do not include purchases of renewable energy credits that are bundled with energy. Also, these amounts do not include purchases of renewable energy credits that are associated with purchased power contracts.

Coal Mine Reclamation Obligations

APS must reimburse certain coal providers for amounts incurred for final and contemporaneous coal mine reclamation. We account for contemporaneous reclamation costs as part of the cost of the delivered coal. We utilize site-specific studies of costs expected to be incurred in the future to estimate our final reclamation obligation. These studies utilize various assumptions to estimate the future costs. Based on the most recent reclamation studies, APS recorded a final coal mine reclamation obligation of approximately $207 million at December 31, 2013 and $119 million at December 31, 2012. Under our current coal supply agreements, we expect to make payments to certain coal providers for the final mine reclamation as follows: $1 million in 2014; $1 million in 2015; $8 million in 2016; $14 million in 2017; $14 million in 2018; and $170 million thereafter. Any amendments to current coal supply agreements may change the timing of the reimbursement.

Superfund

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 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 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, 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. We are unable to determine a range of potential losses that are reasonably possible of occurring.

Southwest Power Outage

Regulatory. On September 8, 2011 at approximately 3:30 PM, a 500kV 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.

Within the same time period that APS’s Yuma customers lost service, a series of transmission and generation disruptions occurred across the systems of several utilities that resulted in outages affecting portions of southern Arizona, southern California and northern Mexico. A total of approximately 7,900 MW of firm load and 2.7 million customers were reported to have been affected. Service to all affected APS customers was restored by 9:15 PM on September 8. Service to customers affected by the wider regional outages was restored by approximately 3:25 AM on September 9.

FERC and the North American Electric Reliability Corporation (“NERC”) conducted a joint inquiry into the outages and, on May 1, 2012, they issued a report (the “Joint Report”) with their analysis and conclusions as to the causes of the events. The report includes recommendations to help industry operators prevent similar outages in the future, including increased data sharing and coordination among the western utilities and entities responsible for bulk electric system reliability coordination. The Joint Report does not address potential reliability violations or an assessment of responsibility of the parties involved. APS continues to analyze business practices and procedures related to the September 8 events.

On January 22, 2014, following non-public preliminary investigations, FERC Staff issued a Notice of Alleged Violations naming six entities involved in the event, including APS. FERC Staff alleges that each of the named entities violated varying numbers of NERC Reliability Standards. APS is alleged to have violated seven Reliability Standard Requirements. The allegations of violations are preliminary determinations by FERC Staff and do not constitute findings by FERC itself that any violations have occurred.

APS intends to work with FERC Staff to resolve the matter. If violations of the Reliability Standards are ultimately determined to have occurred, FERC has the legal authority to assert a possible fine of up to $1 million per violation per day that a violation is found to have been in existence. APS cannot predict the timing or financial or operational impacts that may result from the Staff’s Notice of Alleged Violations, including any payments that may result from a settlement if one is reached, or any claims that may be made as a result of the outages.

Litigation. 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.

Clean Air Act Citizen Lawsuit

On October 4, 2011, Earthjustice, on behalf of several environmental organizations, filed a lawsuit in the United States District Court for the District of New Mexico against APS and the other Four Corners participants alleging violations of the NSR provisions of the Clean Air Act. Subsequent to filing its original Complaint, on January 6, 2012, Earthjustice filed a First Amended Complaint adding claims for violations of the Clean Air Act’s NSPS program. Among other things, the environmental plaintiffs seek to have the court enjoin operations at Four Corners until APS applies for and obtains any required NSR permits and complies with the NSPS. The plaintiffs further request the court to order the payment of civil penalties, including a beneficial mitigation project. On April 2, 2012, APS and the other Four Corners participants filed motions to dismiss. The case is being held in abeyance while the parties seek to negotiate a settlement. On March 30, 2013, upon joint motion of the parties, the court issued an order deeming the motions to dismiss withdrawn without prejudice during pendency of the stay. At such time as the stay is lifted, APS and the other Four Corners participants may reinstate their motions to dismiss without risk of default. We are unable to determine a range of potential losses that are reasonably possible of occurring.

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 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 and Cholla and is currently awaiting a final rulemaking from EPA that could impose new requirements on the Navajo Plant. EPA and ADEQ will require these plants to install pollution control equipment that constitutes the BART to lessen the impacts of emissions on visibility surrounding the plants. Based on EPA’s final standards, APS’s 63% share of the cost of these controls for Four Corners Units 4 and 5 would be approximately $350 million. APS’s share of costs for upgrades at Navajo, based on EPA’s FIP proposal, could be up to approximately $200 million. APS has filed a Petition for Review of EPA’s rule as it applies to Cholla, which, if not successful, will require installation of controls with a cost to APS of approximately $200 million.

Mercury and Other Hazardous Air Pollutants. 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 $120 million for Cholla Units 2 and 3. No additional equipment is needed for Four Corners Units 4 and 5 to comply with these rules. SRP, the operating agent for the Navajo Plant, is still evaluating compliance options under the rules.

Other future environmental rules that could involve material compliance costs include those related to cooling water intake structures, coal combustion waste, effluent limitations, ozone national ambient air quality, GHG emissions, and other rules or matters involving the Clean Air Act, Clean Water Act, ESA, the Navajo Nation, and water supplies for our power plants. The financial impact of complying with these and other 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.

Regional Haze Rules — Cholla

APS believes that EPA’s final rule as it applies to Cholla is unsupported and that EPA had no basis for disapproving Arizona’s 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. We expect briefing in the case to be completed on February 21, 2014.

New Mexico Tax Matter

On May 23, 2013, the New Mexico Taxation and Revenue Department 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 and immediately filed a refund claim with respect to that partial payment in August 2013. The New Mexico Taxation and Revenue Department 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. APS believes the Assessment and the refund claim denial are without merit, but cannot predict the timing or outcome of this litigation.

Financial Assurances

APS has entered into various agreements that require letters of credit for financial assurance purposes. At December 31, 2013, approximately $76 million of letters of credit were outstanding to support existing pollution control bonds of a similar amount. The letters of credit are available to fund the payment of principal and interest of such debt obligations. One of these letters of credit expires in 2015 and two expire in 2016. APS has also entered into letters of credit to support certain equity participants in the Palo Verde sale leaseback transactions (see Note 19 for further details on the Palo Verde sale leaseback transactions). These letters of credit will expire on December 31, 2015, and totaled approximately $32 million at December 31, 2013. Additionally, APS has issued letters of credit to support collateral obligations under certain risk management arrangements, including certain natural gas tolling contracts entered into with third parties. At December 31, 2013, $55 million of such letters of credit were outstanding that will expire in 2014 and 2015.

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 surety bonds for APS which were not material at December 31, 2013.

Asset_Retirement_Obligations

Asset Retirement Obligations	12 Months Ended
	Dec. 31, 2013
Asset Retirement Obligations	'
Asset Retirement Obligations	'
	12. Asset Retirement Obligations

	APS has asset retirement obligations for its Palo Verde nuclear facilities and certain other generation, transmission and distribution assets. The Palo Verde asset retirement obligation primarily relates to final plant decommissioning. This obligation is based on the NRC’s requirements for disposal of radiated property or plant and agreements APS reached with the ACC for final decommissioning of the plant. During the fourth quarter of 2013, a new decommissioning study with updated cash flow estimates was completed for Palo Verde.

	The non-nuclear generation asset retirement obligations primarily relate to requirements for removing portions of those plants at the end of the plant life or lease term. The Four Corners coal-fired power plant asset retirement obligation relates to final plant decommissioning, including ash pond closures. In the fourth quarter of 2012, a new study related to ash pond closure was completed which updated the total costs estimates and related cash flows. In the fourth quarter of 2013, APS finalized the transaction to acquire SCE’s interest in Four Corners. As part of that transaction, APS assumed SCE’s asset retirement obligation. Also, APS retired Four Corners Units 1-3 on December 30, 2013. Decommissioning activities began for Units 1-3 in January 2014. An update was made to the timing of the Units 1-3 decommissioning cash out flows to coincide with the expected decommissioning activities.

	Some of APS’s transmission and distribution assets have asset retirement obligations because they are subject to right of way and easement agreements that require final removal. These agreements have a history of uninterrupted renewal that APS expects to continue. As a result, APS cannot reasonably estimate the fair value of the asset retirement obligation related to such distribution and transmission assets.

	Additionally, APS has aquifer protection permits for some of its generation sites that require the closure of certain facilities at those sites.

	The following schedule shows the change in our asset retirement obligations for 2013 and 2012 (dollars in millions):

		2013			2012
	Asset retirement obligations at the beginning of year	$	357		$	280
	Changes attributable to:
	Accretion expense	24			19
	Settlements	(12		)	—
	Assumed SCE’s obligation	34			—
	Estimated cash flow revisions	(56		)	58
	Asset retirement obligations at the end of year	$	347		$	357

	Decommissioning activities for Four Corners Units 1-3 will begin in January 2014; thus, $33 million of the total asset retirement obligation of $347 million at December 31, 2013, is classified as a current liability on the balance sheet.

	In accordance with regulatory accounting, APS accrues removal costs for its regulated utility assets, even if there is no legal obligation for removal. See detail of regulatory liabilities in Note 3.

Selected_Quarterly_Financial_D

Selected Quarterly Financial Data (Unaudited)	12 Months Ended
	Dec. 31, 2013
Selected Quarterly Financial Data (Unaudited)	'
Selected Quarterly Financial Data (Unaudited)	'
	13. Selected Quarterly Financial Data (Unaudited)

	Consolidated quarterly financial information for 2013 and 2012 is provided in the tables below (dollars in thousands, except per share amounts). Weather conditions cause significant seasonal fluctuations in our revenues; therefore, results for interim periods do not necessarily represent results expected for the year.

		2013 Quarter Ended									2013
		March 31,			June 30,		Sept. 30,		Dec. 31,		Total

	Operating revenues	$	686,652		$	915,822	$	1,152,392	$	699,762	$	3,454,628
	Operations and maintenance	223,250			229,300		233,323		238,854		924,727
	Operating income	86,923			259,812		415,688		83,900		846,323
	Income taxes	12,469			77,043		131,912		9,167		230,591
	Income from continuing operations	32,836			139,598		234,718		32,814		439,966
	Net income attributable to common shareholders	24,444			131,207		226,163		24,260		406,074

	Earnings Per Share:
	Income from continuing operations attributable to common shareholders — Basic	$	0.22		$	1.19	$	2.06	$	0.22	$	3.69
	Net income attributable to common shareholders — Basic	0.22			1.19		2.06		0.22		3.69
	Income from continuing operations attributable to common shareholders — Diluted	0.22			1.18		2.04		0.22		3.66
	Net income attributable to common shareholders — Diluted	0.22			1.18		2.04		0.22		3.66

		2012 Quarter Ended									2012
		March 31,			June 30,		Sept. 30,		Dec. 31,		Total

	Operating revenues	$	620,631		$	878,576	$	1,109,475	$	693,122	$	3,301,804
	Operations and maintenance	210,663			216,236		220,729		237,141		884,769
	Operating income	48,007			254,489		447,970		101,289		851,755
	Income taxes	(4,645		)	76,689		147,116		18,157		237,317
	Income from continuing operations	284			130,930		252,874		34,905		418,993
	Net income (loss) attributable to common shareholders	(8,257		)	122,345		244,823		22,631		381,542

	Earnings Per Share:
	Income (loss) from continuing operations attributable to common shareholders — Basic	$	(0.07	)	$	1.12	$	2.23	$	0.24	$	3.54
	Net income (loss) attributable to common shareholders — Basic	(0.08		)	1.12		2.23		0.21		3.48
	Income (loss) from continuing operations attributable to common shareholders — Diluted	(0.07		)	1.12		2.21		0.24		3.5
	Net income (loss) attributable to common shareholders — Diluted	(0.08		)	1.11		2.21		0.2		3.45

Fair_Value_Measurements

Fair Value Measurements	12 Months Ended
	Dec. 31, 2013
Fair Value Measurements	'
Fair Value Measurements	'
	14. 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, 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. This category also includes investments in common and collective trusts and commingled funds that are redeemable and valued based on NAV.

	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.

	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

	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 8 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 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 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 based on the concept of NAV, which is a value primarily derived from the quoted active market prices of the underlying equity securities. We may transact in these commingled funds on a semi-monthly basis at the NAV, and accordingly classify these investments as Level 2. The commingled funds, which are similar to mutual 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 fund shares are offered to a limited group of investors, they are not considered to be traded in an active market.

	Cash equivalents reported within Level 2 represent investments held in a short-term investment commingled fund, valued using NAV, which invests in U.S. government fixed income securities. We may transact in this commingled fund on a daily basis at the NAV.

	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 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.

	Our trustee provides valuation of our nuclear decommissioning trust assets by using 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 reports on the trustee’s internal operating controls and valuation processes. See Note 20 for additional discussion about our nuclear decommissioning trust.

	Fair Value Tables

	The following table presents the fair value at December 31, 2013 of our assets and liabilities that are measured at fair value on a recurring basis (dollars in millions):

			Quoted Prices			Significant			Significant			Other			Balance at
			in Active			Other			Unobservable						December 31,
			Markets for			Observable			Inputs (a)						2013
			Identical			Inputs			(Level 3)
			Assets			(Level 2)
			(Level 1)
	Assets
	Risk management activities — derivative instruments:
	Commodity Contracts		$	—		$	9		$	41		$	(9	) (b)	$	41
	Nuclear decommissioning trust:
	U.S. commingled equity funds		—			272			—			—			272
	Fixed income securities:
	U.S. Treasury		107			—			—			—			107
	Cash and cash equivalent funds		—			11			—			(3		) (c)	8
	Corporate debt		—			88			—			—			88
	Mortgage-backed securities		—			85			—			—			85
	Municipality bonds		—			71			—			—			71
Other		—			11			—			—			11
Subtotal nuclear decommissioning trust		107			538			—			(3		)	642
Total		$	107		$	547		$	41		$	(12	)	$	683

Liabilities
Risk management activities — derivative instruments:
Commodity contracts		$	—		$	(33	)	$	(90	)	$	21	(b)	$	(102	)

(a) Primarily consists of heat rate options and other long-dated electricity contracts.
(b) Represents counterparty netting, margin and collateral. See Note 17.
(c) Represents nuclear decommissioning trust net pending securities sales and purchases.

The following table presents the fair value at December 31, 2012 of our assets and liabilities that are measured at fair value on a recurring basis (dollars in millions):

		Quoted Prices			Significant			Significant			Other			Balance at
		in Active			Other			Unobservable						December 31,
		Markets for			Observable			Inputs (a)						2012
		Identical			Inputs			(Level 3)
		Assets			(Level 2)
		(Level 1)
Assets
Cash equivalents		$	16		$	—		$	—		$	—		$	16
Risk management activities — derivative instruments:
Commodity Contracts		—			22			62			(22		) (b)	62
Nuclear decommissioning trust:
U.S. commingled equity funds		—			204			—			—			204
Fixed income securities:
U.S. Treasury		104			—			—			—			104
Cash and cash equivalent funds		6			13			—			(4		) (c)	15
Corporate debt		—			80			—			—			80
Mortgage-backed securities		—			83			—			—			83
Municipality bonds		—			74			—			—			74
Other		—			11			—			—			11
Subtotal nuclear decommissioning trust		110			465			—			(4		)	571
Total		$	126		$	487		$	62		$	(26	)	$	649

Liabilities
Risk management activities — derivative instruments:
Commodity contracts		$	—		$	(96	)	$	(110	)	$	47	(b)	$	(159	)

(a) Primarily consists of heat rate options and other long-dated electricity contracts.
(b) Represents counterparty netting, margin and collateral. See Note 17.
(c) 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.

Our option contracts classified as Level 3 primarily relate to purchase heat rate options. The significant unobservable inputs 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 December 31, 2013 and December 31, 2012:

		December 31, 2013						Valuation		Significant				Weighted-
		Fair Value (millions)
Commodity Contracts		Assets			Liabilities			Technique		Unobservable Input		Range		Average
Electricity:
Forward Contracts (a)		$	40		$	66		Discounted cash flows		Electricity forward price (per MWh)		$24.89 - $65.04		$	41.09

Option Contracts (b)		—			19			Option model		Electricity forward price (per MWh)		$39.91 - $85.41		$	58.7
										Natural gas forward price (per MMbtu)		$3.57 - $3.80		$	3.71
										Electricity price volatilities		35% - 94%		59		%
										Natural gas price volatilities		22% - 36%		27		%
Natural Gas:
Forward Contracts (a)		1			5			Discounted cash flows		Natural gas forward price (per MMbtu)		$3.47 - $4.31		$	3.87
Total		$	41		$	90

(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, 2012						Valuation		Significant				Weighted-
		Fair Value (millions)
Commodity Contracts		Assets			Liabilities			Technique		Unobservable Input		Range		Average
Electricity:
Forward Contracts (a)		$	57		$	82		Discounted cash flows		Electricity forward price (per MWh)		$23.06 - $64.20		$	43.16

Option Contracts		—			27			Option model		Electricity forward price (per MWh)		$36.66 - $92.19		$	60.97
										Natural gas forward price (per MMbtu)		$4.10 - $4.25		$	4.2
										Implied electricity price volatilities		15% - 66%		39		%
										Implied natural gas price volatilities		17% - 36%		23		%
Natural Gas:
Forward Contracts (a)		5			1			Discounted cash flows		Natural gas forward price (per MMbtu)		$3.25 - $4.44		$	3.93
Total		$	62		$	110

(a) Includes swaps and physical and financial contracts.

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 years ended December 31, 2013 and 2012 (dollars in millions):

		Year Ended
		December 31,
Commodity Contracts		2013			2012
Net derivative balance at beginning of period		$	(48	)	$	(51	)
Total net gains (losses) realized/unrealized:
Included in earnings		—			2
Included in OCI		—			(3		)
Deferred as a regulatory asset or liability		(10		)	7
Settlements		10			(5		)
Transfers into Level 3 from Level 2		—			(2		)
Transfers from Level 3 into Level 2		(1		)	4
Net derivative balance at end of period		$	(49	)	$	(48	)

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 heat rate options and 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 6 for our long-term debt fair values.

Earnings_Per_Share

Earnings Per Share	12 Months Ended
	Dec. 31, 2013
Earnings Per Share	'
Earnings Per Share	'
	15. Earnings Per Share

	The following table presents earnings attributable to common shareholders per weighted-average common share outstanding for the years ended December 31, 2013, 2012 and 2011:

		2013		2012			2011
	Basic earnings per share:
	Income from continuing operations attributable to common shareholders	$	3.69	$	3.54		$	3.01
	Income (loss) from discontinued operations	—		(0.06		)	0.1
	Earnings per share – basic	$	3.69	$	3.48		$	3.11
	Diluted earnings per share:
	Income from continuing operations attributable to common shareholders	$	3.66	$	3.5		$	2.99
	Income (loss) from discontinued operations	—		(0.05		)	0.1
	Earnings per share – diluted	$	3.66	$	3.45		$	3.09

	Dilutive stock options and performance shares (which are contingently issuable) increased average common shares outstanding by approximately 822,000 shares in 2013, 1,017,000 shares in 2012 and 811,000 shares in 2011. Total average common shares outstanding for the purposes of calculating diluted earnings per share were 110,805,943 shares in 2013, 110,527,311 shares in 2012 and 109,864,243 shares in 2011.

	For the years ended 2013, 2012 and 2011, there were no common stock options that were excluded from the computation of diluted earnings per share as a result of the options’ exercise prices being greater than the average market price of the common shares.

StockBased_Compensation

Stock-Based Compensation	12 Months Ended
Stock-Based Compensation	Dec. 31, 2013
Stock-Based Compensation	'
Stock-Based Compensation	'
	16. Stock-Based Compensation

	Pinnacle West grants long-term incentive awards under the 2012 Long-Term Incentive Plan (“2012 Plan”) in the form of Stock Grants, Restricted Stock Units and Performance Shares and may grant restricted stock, stock units, dividend equivalents, performance share units, performance cash, incentive and non-qualified stock options, and stock appreciation rights. The 2012 Plan, effective May 16, 2012, provides 4,595,500 common shares to be available for grant to eligible employees and members of the Board of Directors. Awards made since 2012 were issued under the 2012 Plan, and prior awards from 2007 to 2011 were issued under the 2007 Long-Term Incentive Plan (“2007 Plan”).

	Restricted Stock Unit Awards and Stock Grants

	Stock grants issued to non-officer members of the Board of Directors in 2013, 2012 and 2011, provided the members of the Board of Directors the option to elect to receive a stock grant, or to defer receipt until a later date and receive restricted stock units in lieu of the stock grant. The members of the Board of Directors who elect to defer may elect to receive payment in either stock, or 50% in cash and 50% in stock. The members of the Board of Directors may elect to receive payments either as of the last business day of the month following the month in which they separate from service on the Board of Directors, or as of a specified date, which must be after December 31 of the year in which the grant was received. The deferred restricted stock units accrue dividend rights, equal to the amount of dividends the Directors would have received had they directly owned stock equal to the number of vested restricted stock units from the date of grant to the date of payment plus interest compounded quarterly. The dividends and interest are paid, based on the Director’s election, in either stock, or 50% in cash and 50% in stock.

	Restricted stock units have been granted to officers and key employees in each year since 2007. From 2007 through 2009, officers and key employees elected to receive payment in either cash or in fully transferable shares of stock, in exchange for each restricted stock unit on pre-established valuation dates. From 2010 through 2013, officers and key employees elected to receive payment in either stock, or 50% in cash and 50% in stock.

	Restricted stock unit awards vest and settle over a four-year period. In addition, officers and key employees accrue dividend rights on vested restricted stock units, equal to the amount of dividends that they would have received had they directly owned stock, equal to the number of vested restricted stock units from the date of grant to the date of payment plus interest compounded quarterly. The dividends and interest for the 2007 through 2009 awards are paid in cash. The dividends and interest for the 2010 through 2013 awards are paid in the same form as the restricted stock unit payment election. Restricted stock unit awards are accounted for as a liability award, with compensation cost initially calculated on the date of grant using the Company’s closing stock price, and remeasured at each balance sheet date. Compensation expense for retirement eligible participants is recognized immediately.

	In December 2012, the Company granted a retention award of 50,617 restricted stock units to the Chairman of the Board, President, and Chief Executive Officer of Pinnacle West. The award will vest and will be paid in shares of common stock on December 31, 2016, provided that he remains employed with the Company until the vesting date. The award will accrue notional dividends equal to the amount of dividends that would have been received if the Chairman of the Board, President and Chief Executive Officer had directly owned one share of Pinnacle West common stock for each restricted stock unit held from the grant date to each dividend payment date. The award can be increased up to an additional 33,745 restricted stock units payable in stock if certain performance requirements are met.

	A grant of restricted stock unit awards was made to officers of the company on February 15, 2011, payable solely in shares of common stock upon the officer’s retirement or other separation of employment. This award vested 50% on February 15, 2013. The remaining grant will vest 25% on February 15, 2014 and 25% on February 15, 2015, provided that the officer remains employed on such date. The officers will also accrue notional dividends equal to the amount of dividends that they would have received if they had directly owned one share of Pinnacle West common stock for each restricted stock unit held from the grant date to each dividend payment date. Each additional restricted stock unit will proportionally vest on the same remaining vesting schedule that applies to the original restricted stock unit.

	The following table is a summary of granted restricted stock units and stock grants and the weighted-average fair value for the three years ended 2013, 2012 and 2011:

			2013			2012		2011
	Units granted		129,620			202,278		292,242
	Grant date fair value (a)		$	55.21		$	49.31	$	41.98


	(a) Weighted-average grant date fair value.

	The following table is a summary of the status of restricted stock units and stock grants, as of December 31, 2013 and changes during the year. This table represents only the stock portion of restricted stock units, per the election on payment discussed in the paragraph above:

	Nonvested shares		Shares		Weighted-Average
	Nonvested shares		Shares		Grant Date Fair Value
	Nonvested at January 1, 2013		480,753		$	43.58
	Granted		129,620		55.21
	Vested		191,988		40.33
	Forfeited		20,409		45.7
	Nonvested at December 31, 2013		397,976		47.74


	The amount of cash required to settle the payments on restricted stock units is (dollars in millions):

	Year		2013			2012		2011
	2007 Grant		$	—		$	—	$	1
	2008 Grant		—			1.9		1.6
	2009 Grant		3			1.7		1.5
	2010 Grant		2.3			0.6		0.6
	2011 Grant		2.5			0.7		—
	2012 Grant		2.2			—		—


	Performance Share Awards

	Performance share awards have been granted to officers and key employees under the 2012 Plan since 2012 and under the 2007 Plan from 2008 to 2011. Performance share awards contain two performance element criteria that affect the number of shares received after the end of a three-year performance period if performance criteria conditions are met.

	The 2013, 2012 and 2011 performance share grant criteria is based 50% upon the percentile ranking of Pinnacle West’s total shareholder return at the end of the three-year performance period, as compared with the total shareholder return of all relevant companies in a specified utility index and the other 50% is based upon six non-financial separate performance metrics. The exact number of shares issued will vary from 0% to 200% of the target award. Shares received include dividend rights paid in stock equal to the amount of dividends that they would have received had they directly owned stock, equal to the number of vested performance shares from the date of grant to the date of payment plus interest compounded quarterly.

	Performance share awards are accounted for as liability awards, with compensation cost initially calculated on the date of grant using the Company’s closing stock price, and remeasured at each balance sheet date. Compensation expense for retirement eligible participants is recognized immediately. Management also evaluates the probability of meeting the performance criteria at each balance sheet date. If performance criteria are not achieved, no compensation cost is recognized and any previously recognized compensation cost is reversed.

	The following table is a summary of the performance shares granted and the weighted-average fair value for the three years ended 2013, 2012 and 2011:

			2013			2012		2011
	Units granted (a)		176,332			185,878		175,072
	Grant date fair value (b)		$	55.45		$	47.4	$	41.71


	(a) Reflects the target payout level.
(b) Weighted-average grant date fair value.

The following table is a summary of the status of performance shares, as of December 31, 2013 and changes during the year:

Nonvested shares (a)		Shares		Weighted-Average
Nonvested shares (a)		Shares		Grant Date Fair Value
Nonvested at January 1, 2013		347,690		$	44.67
Granted		176,332		55.45
Increase in performance factor		40,183		41.71
Vested		200,915		41.71
Forfeited		18,894		48.11
Nonvested at December 31, 2013		344,396		51.13


(a) Nonvested shares are reflected at target payout level. The increase or decrease in the number of shares from the target level to the estimated actual payout level is included in the increase for performance factor amounts in the year the award vests.

Stock Options

The Company has not granted stock options since 2004 and has no stock options outstanding.

The following table summarizes the option activity under prior equity incentive plans for the year ended December 31, 2013:

Options		Shares		Weighted-
				Average
				Exercise
				Price
Outstanding at January 1, 2013		7,925		$	32.29
Exercised		3,625		32.29
Forfeited or expired		4,300		32.29
Outstanding at December 31, 2013		—		—


Cash received from options exercised under our share-based payment arrangements was $0.1 million for 2013, $0.5 million for 2012, and $1.8 million for 2011. The tax benefit realized for the tax deductions from option exercises of the share-based payment arrangements were immaterial for all years.

The intrinsic value of options exercised was immaterial for all years.

As of December 31, 2013, there was $17 million of total unrecognized compensation cost related to nonvested share-based compensation arrangements granted under the plans. That cost is expected to be recognized over a weighted-average period of 2.0 years. The total fair value of shares vested during 2013, 2012 and 2011 was $20 million, $19 million and $14 million, respectively.

The compensation cost that has been charged against Pinnacle West’s income for share-based compensation plans was $25 million in 2013, $32 million in 2012, and $23 million in 2011. The compensation cost that Pinnacle West has capitalized is immaterial for all years. Pinnacle West’s total income tax benefit recognized in the Consolidated Statements of Income for share-based compensation arrangements was $10 million in 2013, $13 million in 2012, and $9 million in 2011. APS’s share of compensation cost that has been charged against income was $25 million in 2013, $32 million in 2012, and $22 million in 2011.

Pinnacle West’s current policy is to issue new shares to satisfy share requirements for stock compensation plans, and it does not expect to repurchase any shares except to satisfy tax withholding obligations upon the vesting of restricted stock units and performance shares.

Derivative_Accounting

Derivative Accounting	12 Months Ended
	Dec. 31, 2013
Derivative Accounting	'
Derivative Accounting	'
	17. 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 Consolidated Statements of Income, but does not impact our financial condition, net income or cash flows.

	On June 1, 2012, we elected to discontinue cash flow hedge accounting treatment for the significant majority of our contracts that had previously been designated as cash flow hedges. This discontinuation is due to changes in PSA recovery (see Note 3), which now allows for 100% deferral of the unrealized gains and losses relating to these contracts. For those contracts that were de-designated, all changes in fair value after May 31, 2012 are no longer recorded through OCI, but are deferred through the PSA. The amounts previously recorded in accumulated OCI relating to these instruments will remain in accumulated OCI, and will transfer to earnings in the same period or periods during which the hedged transaction affects earnings or sooner if we determine it is probable that the forecasted transaction will not occur. When amounts have been reclassified from accumulated OCI to earnings, they will be subject to deferral in accordance with the PSA. Cash flow hedge accounting treatment will continue for a limited number of contracts that are not subject to PSA recovery.

	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 14 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 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.

	Prior to the 2012 Settlement Agreement, for its regulated operations, APS deferred for future rate treatment approximately 90% of unrealized gains and losses on certain derivatives pursuant to the PSA mechanism that would otherwise be recognized in income. Due to the 2012 Settlement Agreement, for its regulated operations, APS now defers for future rate treatment 100% of the unrealized gains and losses for delivery periods after June 30, 2012 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 December 31, 2013, we had the following outstanding gross notional volume of derivatives, which represent both purchases and sales (does not reflect net position):

	Commodity		Quantity
	Power		5,765		GWh
	Gas		108		Bcfs (a)

	(a) “Bcf” is 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 years ended December 31, 2013, 2012 and 2011 (dollars in thousands):

					Year Ended
			Financial Statement		December 31,
	Commodity Contracts		Location		2013			2012			2011

	Loss Recognized in OCI on Derivative Instruments (Effective Portion)		OCI — derivative instruments		$	(353	)	$	(37,663	)	$	(94,660	)
	Loss Reclassified from Accumulated OCI into Income (Effective Portion Realized) (a)		Fuel and purchased power (b)		(44,219		)	(99,007		)	(117,189		)
	Gain (Loss) Recognized in Income (Ineffective Portion and Amount Excluded from Effectiveness Testing)		Fuel and purchased power (b)		—			117			(211		)


	(a) During the years ended December 31, 2013, 2012, and 2011, we had zero, $1.8 million, and zero 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 $21 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, substantially all 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 years ended December 31, 2013, 2012 and 2011 (dollars in thousands):

					Year Ended
			Financial Statement		December 31,
	Commodity Contracts		Location		2013			2012			2011

	Net Gain (Loss) Recognized in Income		Operating revenues (a)		$	289		$	103		$	(27	)

	Net Loss Recognized in Income		Fuel and purchased power (a)		(10,449		)	(2,747		)	(52,113		)
	Total				$	(10,160	)	$	(2,644	)	$	(52,140	)

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

	Derivative Instruments in the 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 Consolidated Balance Sheets. Transactions that do not allow for offsetting of positive and negative positions are reported gross on the 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 Consolidated Balance Sheets as of December 31, 2013 and December 31, 2012, include gross liabilities of $5 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 December 31, 2013 and 2012. These amounts relate to commodity contracts and are located in the assets and liabilities from risk management activities lines of our Consolidated Balance Sheets.

	As of December 31, 2013:		Gross			Amounts			Net			Other			Amount
	(dollars in thousands)		Recognized			Offset			Recognized			(c)			Reported on
	Derivatives		(b)			Derivatives						Balance Sheet
	(a)
Current Assets			$	24,587		$	(7,425	)	$	17,162		$	7		$	17,169
Investments and Other Assets			25,364			(1,549		)	23,815			—			23,815
Total Assets		49,951			(8,974		)	40,977			7			40,984

Current Liabilities		(50,540		)	26,166			(24,374		)	(7,518		)	(31,892		)
Deferred Credits and Other		(72,123		)	1,808			(70,315		)	—			(70,315		)
Total Liabilities		(122,663		)	27,974			(94,689		)	(7,518		)	(102,207		)
Total		$	(72,712	)	$	19,000		$	(53,712	)	$	(7,511	)	$	(61,223	)

(a) All of our gross recognized derivative instruments were subject to master netting arrangements.
(b) Includes cash collateral provided to counterparties of $19,000.
(c) Represents cash collateral and 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 $7,518, and cash margin provided to counterparties of $7.

As of December 31, 2012:		Gross			Amounts			Net			Other			Amount
(dollars in thousands)		Recognized			Offset			Recognized			(c)			Reported on
		Derivatives			(b)			Derivatives						Balance Sheet
		(a)
Current Assets		$	42,495		$	(17,797	)	$	24,698		$	1,001		$	25,699
Investments and Other Assets		41,563			(5,672		)	35,891			—			35,891
Total Assets		84,058			(23,469		)	60,589			1,001			61,590

Current Liabilities		(105,324		)	57,046			(48,278		)	(25,463		)	(73,741		)
Deferred Credits and Other		(100,986		)	15,722			(85,264		)	—			(85,264		)
Total Liabilities		(206,310		)	72,768			(133,542		)	(25,463		)	(159,005		)
Total		$	(122,252	)	$	49,299		$	(72,953	)	$	(24,462	)	$	(97,415	)


(a) All of our gross recognized derivative instruments were subject to master netting arrangements.
(b) Includes cash collateral provided to counterparties of $49,299.
(c) Represents cash collateral relating to non-derivative instruments or derivatives qualifying for scope exceptions. Includes cash collateral provided to counterparties of $1,001, and cash collateral received from counterparties of $25,463. This amount is not subject to offsetting.

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 two counterparties for which our exposure represents approximately 92% of Pinnacle West’s $41 million of risk management assets as of December 31, 2013. This exposure relates to long-term traditional wholesale contracts with counterparties that have 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.

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 December 31, 2013 (dollars in millions):

		December 31,
		2013
Aggregate Fair Value of Derivative Instruments in a Net Liability Position		$	123
Cash Collateral Posted		19
Additional Cash Collateral in the Event Credit-Risk Related Contingent Features were Fully Triggered (a)		66



(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 $180 million if our debt credit ratings were to fall below investment grade.

Other_Income_and_Other_Expense

Other Income and Other Expense	12 Months Ended
Other Income and Other Expense	Dec. 31, 2013
Other Income and Other Expense	'
Other Income and Other Expense	'
	18. Other Income and Other Expense

	The following table provides detail of other income and other expense for 2013, 2012 and 2011 (dollars in thousands):

		2013			2012			2011
	Other income:
	Interest income	$	1,629		$	1,239		$	1,850
	Investment gains — net	—			—			1,165
	Miscellaneous	75			367			96
	Total other income	$	1,704		$	1,606		$	3,111

	Other expense:
	Non-operating costs	$	(8,207	)	$	(7,777	)	$	(7,037	)
	Investment loss — net	(3,711		)	(2,453		)	—
	Miscellaneous	(4,106		)	(9,612		)	(3,414		)
	Total other expense	$	(16,024	)	$	(19,842	)	$	(10,451	)

Palo_Verde_Sale_Leaseback_Vari

Palo Verde Sale Leaseback Variable Interest Entities	12 Months Ended
	Dec. 31, 2013
Palo Verde Sale Leaseback Variable Interest Entities	'
Palo Verde Sale Leaseback Variable Interest Entities	'
	19. Palo Verde Sale Leaseback Variable Interest Entities

	In 1986, APS entered into agreements with three separate VIE lessor trusts in order to sell and lease back interests in Palo Verde Unit 2 and related common facilities. APS will pay approximately $49 million per year during 2014 and 2015 related to these leases. The lease agreements include fixed rate renewal periods which give APS the ability to utilize the asset for a significant portion of the asset’s economic life, and therefore provide APS with the power to direct activities of the VIEs that most significantly impact the VIEs’ economic performance. Predominately due to the fixed rate renewal periods, APS has been deemed the primary beneficiary of these VIEs and therefore consolidates the VIEs.

	On December 31, 2012, APS notified the lessor trust entities that APS will retain the assets beyond 2015 by either exercising the fixed rate lease renewals or by purchasing the assets. If APS elects to purchase the assets, the purchase price will be based on the fair market value of the assets at the end of 2015. If APS elects to extend the leases, we will be required to make payments beginning in 2016 of approximately $23 million annually. The length of the lease extensions is unknown at this time, as it must be determined through an appraisal process. APS must give notice to the lessor trusts by June 30, 2014 notifying them which of these two options (lease renewal or purchasing the assets) it will exercise. The December 31, 2012 notification does not impact APS’s consolidation of the VIEs, as APS continues to be deemed the primary beneficiary of the VIEs.

	As a result of consolidation, we eliminate rent expense and recognize depreciation and interest expense, resulting in an increase in net income for 2013, 2012 and 2011 of $34 million, $32 million and $28 million, respectively, entirely attributable to the noncontrolling interests. Income attributable to Pinnacle West shareholders remains the same. Consolidation of these VIEs also results in changes to our Consolidated Statements of Cash Flows, but does not impact net cash flows.

	Our Consolidated Balance Sheets at December 31, 2013 and December 31, 2012 include the following amounts relating to the VIEs (in millions):

		December 31,		December 31,
		2013		2012
	Palo Verde sale leaseback property plant and equipment, net of accumulated depreciation	$	125	$	129
	Current maturities of long-term debt	26		27
	Long-term debt excluding current maturities	13		39
	Equity-Noncontrolling interests	146		129


	Assets of the VIEs are restricted and may only be used to settle the VIEs’ debt obligations and 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 reasonably likely to occur. Under certain circumstances (for example, the 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, assume the VIEs’ debt, and take title to the leased Palo Verde Unit 2 interests which, if appropriate, may be required to be written down in value. If such an event had occurred as of December 31, 2013, APS would have been required to pay the noncontrolling equity participants approximately $133 million and assume $39 million of debt. Since APS consolidates these VIEs, the debt APS would be required to assume is already reflected in our Consolidated Balance Sheets.

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

Nuclear_Decommissioning_Trusts

Nuclear Decommissioning Trusts	12 Months Ended
	Dec. 31, 2013
Nuclear Decommissioning Trusts	'
Nuclear Decommissioning Trusts	'
	20. 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 Consolidated Balance Sheets. See Note 14 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 December 31, 2013 and December 31, 2012 (dollars in millions):

		Fair Value			Total			Total
					Unrealized			Unrealized
					Gains			Losses
	December 31, 2013
	Equity securities	$	272		$	129		$	—
	Fixed income securities	373			11			(6		)
	Net payables (a)	(3		)	—			—
	Total	$	642		$	140		$	(6	)

		Fair Value			Total			Total
					Unrealized			Unrealized
					Gains			Losses
	December 31, 2012
	Equity securities	$	204		$	67		$	—
	Fixed income securities	371			24			—
	Net payables (a)	(4		)	—			—
	Total	$	571		$	91		$	—

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

	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 millions):

		Year Ended December 31,
		2013			2012			2011

	Realized gains	$	6		$	7		$	8
	Realized losses	(7		)	(4		)	(5		)
	Proceeds from the sale of securities (a)	446			418			498


	(a) Proceeds are reinvested in the trust.

	The fair value of fixed income securities, summarized by contractual maturities, at December 31, 2013 is as follows (dollars in millions):

		Fair Value
	Less than one year	$	9
	1 year – 5 years	109
	5 years – 10 years	108
	Greater than 10 years	147
	Total	$	373

Changes_in_Accumulated_Other_C

Changes in Accumulated Other Comprehensive Loss	12 Months Ended
	Dec. 31, 2013
Changes in Accumulated Other Comprehensive Loss	'
Changes in Accumulated Other Comprehensive Loss	'
	21. Changes in Accumulated Other Comprehensive Loss

	The following table shows the changes in accumulated other comprehensive loss, including reclassification adjustments, net of tax, by component for the year ended December 31, 2013 (dollars in thousands):

		Year Ended December 31, 2013
		Derivative			Pension and			Total
		Instruments			Other
					Postretirement
					Benefits

	Beginning balance	$	(49,592	)	$	(64,416	)	$	(114,008	)
	OCI (loss) before reclassifications	(213		)	5,594			5,381
	Amounts reclassified from accumulated other comprehensive loss	26,747		(a)	3,827		(b)	30,574

	Net current period OCI	26,534			9,421			35,955
	Ending balance	$	(23,058	)	$	(54,995	)	$	(78,053	)

	(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 17.
	(b) These amounts primarily represent amortization of actuarial loss, and are included in the computation of net periodic pension cost. See Note 8.

SCHEDULE_I_CONDENSED_FINANCIAL

SCHEDULE I - CONDENSED FINANCIAL INFORMATION OF REGISTRANT	12 Months Ended
	Dec. 31, 2013
SCHEDULE I - CONDENSED FINANCIAL INFORMATION OF REGISTRANT	'
SCHEDULE I - CONDENSED FINANCIAL INFORMATION OF REGISTRANT	'
	PINNACLE WEST CAPITAL CORPORATION HOLDING COMPANY
	SCHEDULE I — CONDENSED FINANCIAL INFORMATION OF REGISTRANT
	CONDENSED STATEMENTS OF COMPREHENSIVE INCOME
	(in thousands)

			Year Ended December 31,
			2013			2012			2011

	Operating revenues		$	799		$	6,133		$	1,034
	Operating expenses		24,930			12,125			8,811

	Operating loss		(24,131		)	(5,992		)	(7,777		)

	Other
	Equity in earnings of subsidiaries		420,926			391,528			335,859
	Other expense		(1,999		)	(2,001		)	(1,481		)
	Total		418,927			389,527			334,378

	Interest expense		3,226			4,868			8,053

	Income from continuing operations		391,570			378,667			318,548
	Income tax benefit		(14,504		)	(7,079		)	(8,938		)

	Income from continuing operations — net of income taxes		406,074			385,746			327,486
	Income (loss) from discontinued operations — net of income taxes		—			(4,204		)	11,987

	Net income attributable to common shareholders		406,074			381,542			339,473

	Other comprehensive income — attributable to common shareholders		35,955			38,155			7,605
	Total comprehensive income — attributable to common shareholders		$	442,029		$	419,697		$	347,078

	See Notes to Pinnacle West’s Consolidated Financial Statements.


	PINNACLE WEST CAPITAL CORPORATION HOLDING COMPANY
	SCHEDULE I — CONDENSED FINANCIAL INFORMATION OF REGISTRANT
	CONDENSED BALANCE SHEETS
	(in thousands)

			December 31,
			2013			2012
	ASSETS

	Current assets
	Cash and cash equivalents		$	5,798		$	22,679
	Accounts receivable		80,108			92,906
	Current deferred income taxes		93,185			77,771
	Income tax receivable		1,853			3,350
	Other current assets		242			25
	Total current assets		181,186			196,731

	Investments and other assets
	Investments in subsidiaries		4,455,049			4,223,301
	Other assets		13,789			13,833
	Total investments and other assets		4,468,838			4,237,134

	Total Assets		$	4,650,024		$	4,433,865

	LIABILITIES AND EQUITY

	Current liabilities
	Accounts payable		$	3,279		$	5,735
	Accrued taxes		8,538			8,239
Common dividends payable		62,528			59,789
Other current liabilities		31,295			41,000
Total current liabilities		105,640			114,763

Long-term debt less current maturities		125,000			125,000

Deferred credits and other
Deferred income taxes		4,158			17,395
Pension and other postretirement liabilities		37,611			41,199
Other		37,155			33,219
Total deferred credits and other		78,924			91,813

Common stock equity
Common stock		2,487,250			2,462,712
Accumulated other comprehensive loss		(78,053		)	(114,008		)
Retained earnings		1,785,273			1,624,102
Total Pinnacle West Shareholders’ equity		4,194,470			3,972,806
Noncontrolling interests		145,990			129,483
Total Equity		4,340,460			4,102,289
Total Liabilities and Equity		$	4,650,024		$	4,433,865

See Notes to Pinnacle West’s Consolidated Financial Statements.


PINNACLE WEST CAPITAL CORPORATION HOLDING COMPANY
SCHEDULE I — CONDENSED FINANCIAL INFORMATION OF REGISTRANT
CONDENSED STATEMENTS OF CASH FLOWS
(in thousands)

		Year Ended December 31,
		2013			2012			2011

Cash flows from operating activities
Net income		$	406,074		$	381,542		$	339,473
Adjustments to reconcile net income to net cash provided by operating activities:
Equity in earnings of subsidiaries — net		(420,926		)	(391,528		)	(335,859		)
Depreciation and amortization		95			94			97
Gain on sale of energy-related business		—			—			(10,404		)
Deferred income taxes		(28,806		)	(15,135		)	7,387
Accounts receivable		21,671			28,763			(24,201		)
Accounts payable		(2,449		)	879			(2,677		)
Accrued taxes and income tax receivables — net		1,402			(3,103		)	7,512
Dividends received from subsidiaries		242,100			222,200			228,900
Other		(15,065		)	(4,589		)	19,270
Net cash flow provided by operating activities		204,096			219,123			229,498

Cash flows from investing activities
Investments in subsidiaries		(3,400		)	—			—
Repayments of loans from subsidiaries		2,149			996			61,143
Proceeds from sale of energy-related products and services business		—			—			45,111
Advances of loans to subsidiaries		(2,099		)	(1,200		)	(64,970		)
Proceeds from sale of life insurance policies		—			—			9,357
Net cash flow provided by (used for) investing activities		(3,350		)	(204		)	50,641

Cash flows from financing activities
Issuance of long-term debt		—			125,000			175,000
Short-term borrowings and payments — net		—			—			(16,600		)
Dividends paid on common stock		(235,244		)	(225,075		)	(221,728		)
Repayment of long-term debt		—			(125,000		)	(225,000		)
Common stock equity issuance		17,319			15,955			15,841
Other		298			170			(2,667		)
Net cash flow used for financing activities		(217,627		)	(208,950		)	(275,154		)

Net increase (decrease) in cash and cash equivalents		(16,881		)	9,969			4,985

Cash and cash equivalents at beginning of year		22,679			12,710			7,725

Cash and cash equivalents at end of year		$	5,798		$	22,679		$	12,710

See Notes to Pinnacle West’s Consolidated Financial Statements.

SCHEDULE_II_RESERVE_FOR_UNCOLL

SCHEDULE II - RESERVE FOR UNCOLLECTIBLES	12 Months Ended
	Dec. 31, 2013
SCHEDULE II - RESERVE FOR UNCOLLECTIBLES	'
SCHEDULE II - RESERVE FOR UNCOLLECTIBLES	'
	PINNACLE WEST CAPITAL CORPORATION
	SCHEDULE II — RESERVE FOR UNCOLLECTIBLES
	(dollars in thousands)

	Column A	Column B		Column C				Column D		Column E
				Additions
	Description	Balance at		Charged to		Charged		Deductions		Balance
		beginning		cost and		to other				at end of
		of period		expenses		accounts				period

	Reserve for uncollectibles:
	2013	$	3,340	$	4,923	$	—	$	5,060	$	3,203
	2012	3,748		5,290		—		5,698		3,340
	2011	4,709		5,672		—		6,633		3,748

Summary_of_Significant_Account1

Summary of Significant Accounting Policies (Policies)	12 Months Ended
	Dec. 31, 2013
Summary of Significant Accounting Policies	'
Description of Business and Basis of Presentation	'
	Description of Business and Basis of Presentation

	Pinnacle West is a holding company that conducts business through its subsidiaries, APS and El Dorado, and formerly SunCor and APSES. APS, our wholly-owned subsidiary, is a vertically-integrated electric utility that provides either retail or wholesale electric service to substantially all 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 accounts for essentially all of our revenues and earnings, and is expected to continue to do so. SunCor was a developer of residential, commercial and industrial real estate projects and essentially all of these assets were sold in 2009 and 2010. In February 2012, SunCor filed for protection under the United States Bankruptcy Code to complete an orderly liquidation of its business. All activities for SunCor are reported as discontinued operations. APSES provided energy-related projects to commercial and industrial retail customers in competitive markets in the western United States. APSES was sold in 2011 and is reported as discontinued operations. El Dorado is an investment firm.

	Pinnacle West’s Consolidated Financial Statements include the accounts of Pinnacle West and our subsidiaries: APS and El Dorado, and formerly SunCor and APSES. APS’s consolidated financial statements include the accounts of APS and certain VIEs relating to the Palo Verde sale leaseback. Intercompany accounts and transactions between the consolidated companies have been eliminated.

	We consolidate VIEs for which we are the primary beneficiary. We determine whether we are the primary beneficiary of a VIE through a qualitative analysis that identifies which variable interest holder has the controlling financial interest in the VIE. In performing our primary beneficiary analysis, we consider all relevant facts and circumstances, including the design and activities of the VIE, the terms of the contracts the VIE has entered into, and which parties participated significantly in the design or redesign of the entity. We continually evaluate our primary beneficiary conclusions to determine if changes have occurred which would impact our primary beneficiary assessments. We have determined that APS is the primary beneficiary of certain VIE lessor trusts relating to the Palo Verde sale leaseback, and therefore APS consolidates these entities (see Note 19).

	Our 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 line items are presented in more detail on the Consolidated Balance Sheets and Consolidated Statements of Cash Flows than was presented in the prior years. Other line items are more condensed than the previous presentation. The prior year amounts were reclassified to conform to the current year presentation. These reclassifications had no impact on total assets or net cash flow provided by operating activities. The following tables show the impacts of the reclassifications of prior years (previously reported) amounts (dollars in thousands):

	Balance Sheets - December 31, 2012	As		Reclassifications to			Amount reported
		previously		conform to current year			after reclassification
		reported		presentation			to conform to current
							year presentation
	Long-Term Debt less Current Maturities —
	Long-term debt less current maturities	$	3,160,219	$	38,869		$	3,199,088
	Long-Term Debt less Current Maturities —
	Palo Verde sale leaseback lessor notes less
	current maturities	38,869		(38,869		)	—


	Statement of Cash Flows for the	As previously		Reclassifications to			Amount reported after
	Year Ended December 31, 2012	reported		conform to current year			reclassification to
				presentation			conform to current
							year presentation
	Cash Flows from Operating Activities
	Deferred income taxes	$	228,602	$	(41,579	)	$	187,023
	Deferred investment tax credit	—		41,579			41,579
	Accrued taxes and income tax receivable	8,693		(8,693		)	—
	Income tax receivable	—		(4,043		)	(4,043		)
	Accrued taxes	—		12,736			12,736


	Statement of Cash Flows for the	As previously		Reclassifications to			Amount reported after
	Year Ended December 31, 2011	reported		conform to current year			reclassification to
				presentation			conform to current year
							presentation
	Cash Flows from Operating Activities
	Deferred income taxes	$	176,192	$	(58,240	)	$	117,952
	Deferred investment tax credit	—		58,240			58,240
	Accrued taxes and income tax receivable	12,068		(12,068		)	—
	Income tax receivable	—		3,983			3,983
	Accrued taxes	—		8,085			8,085


Accounting Records and Use of Estimates	'
	Accounting Records and Use of Estimates

	Our accounting records are maintained in accordance with 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.

Regulatory Accounting	'
	Regulatory Accounting

	APS is regulated by the ACC and FERC. The accompanying financial statements reflect the rate-making policies of these commissions. As a result, we capitalize certain costs that would be included as expense in the current period by unregulated companies. Regulatory assets represent incurred costs that have been deferred because they are probable of future recovery in customer rates. Regulatory liabilities generally represent expected future costs that have already been collected from customers.

	Management continually assesses whether our regulatory assets are probable of future recovery by considering factors such as changes in the applicable regulatory environment and recent rate orders applicable to APS or other regulated entities in the same jurisdiction. This determination reflects the current political and regulatory climate in Arizona and is subject to change in the future. If future recovery of costs ceases to be probable, the assets would be written off as a charge in current period earnings.

	See Note 3 for additional information.

Electric Revenues	'
	Electric Revenues

	We derive electric revenues primarily from sales of electricity to our regulated Native Load customers. Revenues related to the sale of electricity are generally recorded when service is rendered or electricity is delivered to customers. The billing of electricity sales to individual Native Load customers is based on the reading of their meters, which occurs on a systematic basis throughout the month. Unbilled revenues are estimated by applying an average revenue/kWh by customer class to the number of estimated kWhs delivered but not billed. Differences historically between the actual and estimated unbilled revenues are immaterial. We exclude sales taxes and franchise fees on electric revenues from both revenue and taxes other than income taxes.

	Revenues from our Native Load customers and non-derivative instruments are reported on a gross basis on Pinnacle West’s Consolidated Statements of Income. In the electricity business, some contracts to purchase energy are netted against other contracts to sell energy. This is called a “book-out” and usually occurs for contracts that have the same terms (quantities and delivery points) and for which power does not flow. We net these book-outs, which reduces both revenues and fuel and purchased power costs.

	For the period January 1, 2010 through June 30, 2012, electric revenues also include proceeds for line extension payments for new or upgraded service in accordance with the 2009 Settlement Agreement (see Note 3). Effective July 1, 2012, as a result of the 2012 Settlement Agreement, these amounts are now recorded as contributions in aid of construction and are not included in electric revenues.

	Some of our cost recovery mechanisms are alternative revenue programs. For alternative revenue programs that meet specified accounting criteria, we recognize revenues when the specific events permitting billing of the additional revenues have been completed.

Allowance for Doubtful Accounts	'
	Allowance for Doubtful Accounts

	The allowance for doubtful accounts represents our best estimate of existing accounts receivable that will ultimately be uncollectible. The allowance is calculated by applying estimated write-off factors to various classes of outstanding receivables, including accrued utility revenues. The write-off factors used to estimate uncollectible accounts are based upon consideration of both historical collections experience and management’s best estimate of future collections success given the existing collections environment.

Property, Plant and Equipment	'
	Property, Plant and Equipment

	Utility plant is the term we use to describe the business property and equipment that supports electric service, consisting primarily of generation, transmission and distribution facilities. We report utility plant at its original cost, which includes:

	· material and labor;
	· contractor costs;
	· capitalized leases;
	· construction overhead costs (where applicable); and
	· allowance for funds used during construction.

	We expense the costs of plant outages, major maintenance and routine maintenance as incurred. We charge retired utility plant to accumulated depreciation. Liabilities associated with the retirement of tangible long-lived assets are recognized at fair value as incurred and capitalized as part of the related tangible long-lived assets. Accretion of the liability due to the passage of time is an operating expense, and the capitalized cost is depreciated over the useful life of the long-lived asset. See Note 12.

	APS records a regulatory liability on its regulated assets for the difference between the amount that has been recovered in regulated rates and the amount calculated in accordance with guidance on accounting for asset retirement obligations. APS believes it can recover in regulated rates the costs calculated in accordance with this accounting guidance.

	We record depreciation on utility plant on a straight-line basis over the remaining useful life of the related assets. The approximate remaining average useful lives of our utility property at December 31, 2013 were as follows:

	· Fossil plant — 18 years;
	· Nuclear plant — 26 years;
	· Other generation — 26 years;
	· Transmission — 37 years;
	· Distribution — 34 years; and
	· Other — 7 years.

	APS applied for twenty-year extensions of its operating licenses for each of the three Palo Verde units in December 2008. On April 21, 2011, the NRC approved the extensions of the Palo Verde licenses. The nuclear plant remaining life takes into consideration an ACC decision which authorizes the use of the new Palo Verde nuclear plant lives, effective January 1, 2012.

	Pursuant to an ACC order, we defer operating costs related to APS’s acquisition of additional interests in Units 4 and 5 and the related closure of Units 1-3 of Four Corners. See Note 3 for further discussion. These costs are deferred on the depreciation line of the Consolidated Statements of Income.

	For the years 2011 through 2013, the depreciation rates ranged from a low of 0.45% to a high of 12.08%. The weighted-average rate was 3.00% for 2013, 2.71% for 2012, and 2.98% for 2011.

Allowance for Funds Used During Construction	'
	Allowance for Funds Used During Construction

	AFUDC represents the approximate net composite interest cost of borrowed funds and an allowed return on the equity funds used for construction of regulated utility plant. Both the debt and equity components of AFUDC are non-cash amounts within the Consolidated Statement of Income. Plant construction costs, including AFUDC, are recovered in authorized rates through depreciation when completed projects are placed into commercial operation.

	AFUDC was calculated by using a composite rate of 8.56% for 2013, 8.60% for 2012, and 10.25% for 2011. APS compounds AFUDC semi-annually and ceases to accrue AFUDC when construction work is completed and the property is placed in service.

Materials and Supplies	'
	Materials and Supplies

	APS values materials, supplies and fossil fuel inventory using a weighted-average cost method. APS materials, supplies and fossil fuel inventories are carried at the lower of weighted-average cost or market, unless evidence indicates that the weighted-average cost (even if in excess of market) will be recovered.

Fair Value Measurements	'
	Fair Value Measurements

	We account for derivative instruments, investments held in our nuclear decommissioning trust, certain cash equivalents and plan assets held in our retirement and other benefit plans at fair value on a recurring basis. Due to the short-term nature of net accounts receivable, accounts payable, and short-term borrowings, the carrying values of these instruments approximate fair value. Fair value measurements may also be applied on a nonrecurring basis to other assets and liabilities in certain circumstances such as impairments. We also disclose fair value information for our long-term debt, which is carried at amortized cost (see Note 6).

	Fair value is the price that would be received for an asset or paid to transfer a liability (exit price) in the principal or most advantageous market which we can access for the asset or liability in an orderly transaction between willing market participants on the measurement date. Inputs to fair value may include observable and unobservable data. We maximize the use of observable inputs and minimize the use of unobservable inputs when measuring fair value.

	We determine fair market value using observable inputs such as actively-quoted prices for identical instruments when available. When actively quoted prices are not available for the identical instruments, we use other observable inputs, such as prices for similar instruments, other corroborative market information, or prices provided by other external sources. For options, long-term contracts and other contracts for which observable price data are not available, we use models and other valuation methods, which may incorporate unobservable inputs to determine fair market value.

	The use of models and other valuation methods to determine fair market value often requires subjective and complex judgment. Actual results could differ from the results estimated through application of these methods.

	See Note 14 for additional information about fair value measurements.

Derivative Accounting	'
	Derivative Accounting

	We are exposed to the impact of market fluctuations in the commodity price and transportation costs of electricity, natural gas, coal, emission allowances and in interest rates. We manage risks associated with market volatility by utilizing various physical and financial 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. The changes in market value of such contracts have a high correlation to price changes in the hedged transactions. We also enter into derivative instruments for economic hedging purposes. 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 expenses in our Consolidated Statements of Income, but does not impact our financial condition, net income or cash flows.

	We account for our derivative contracts in accordance with derivatives and hedging guidance, which requires all derivatives not qualifying for a scope exception to be measured at fair value on the balance sheet as either assets or liabilities. Transactions with counterparties that have master netting arrangements are reported net on the balance sheet. See Note 17 for additional information about our derivative instruments.

Loss Contingencies and Environmental Liabilities	'
	Loss Contingencies and Environmental Liabilities

	Pinnacle West and APS are involved in certain legal and environmental matters that arise in the normal course of business. Contingent losses and environmental liabilities are recorded when it is determined that it is probable that a loss has occurred and the amount of the loss can be reasonably estimated. When a range of the probable loss exists and no amount within the range is a better estimate than any other amount, Pinnacle West and APS record a loss contingency at the minimum amount in the range. Unless otherwise required by GAAP, legal fees are expensed as incurred.

Retirement Plans and Other Benefits	'
	Retirement Plans and Other Benefits

	Pinnacle West sponsors a qualified defined benefit and account balance pension plan for the employees of Pinnacle West and its subsidiaries. We also sponsor an other postretirement benefit plan for the employees of Pinnacle West and our subsidiaries that provides medical and life insurance benefits to retired employees. Pension and other postretirement benefit expense are determined by actuarial valuations, based on assumptions that are evaluated annually. See Note 8 for additional information on pension and other postretirement benefits.

Nuclear Fuel	'
	Nuclear Fuel

	APS amortizes nuclear fuel by using the unit-of-production method. The unit-of-production method is based on actual physical usage. APS divides the cost of the fuel by the estimated number of thermal units it expects to produce with that fuel. APS then multiplies that rate by the number of thermal units produced within the current period. This calculation determines the current period nuclear fuel expense.

	APS also charges nuclear fuel expense for the interim storage and permanent disposal of spent nuclear fuel. The DOE is responsible for the permanent disposal of spent nuclear fuel and charges APS $0.001 per kWh of nuclear generation. See Note 11 for information on spent nuclear fuel disposal costs.

Income Taxes	'
	Income Taxes

	Income taxes are provided using the asset and liability approach prescribed by guidance relating to accounting for income taxes. We file our federal income tax return on a consolidated basis, and we file our state income tax returns on a consolidated or unitary basis. In accordance with our intercompany tax sharing agreement, federal and state income taxes are allocated to each first-tier subsidiary as though each first-tier subsidiary filed a separate income tax return. Any difference between that method and the consolidated (and unitary) income tax liability is attributed to the parent company. The income tax accounts reflect the tax and interest associated with management’s estimate of the largest amount of tax benefit that is greater than 50% likely of being realized upon settlement for all known and measurable tax exposures (see Note 4).

Cash and Cash Equivalents	'
	Cash and Cash Equivalents

	We consider all highly liquid investments with a remaining maturity of three months or less at acquisition to be cash equivalents.

	The following table summarizes supplemental Pinnacle West cash flow information for each of the last three years (dollars in thousands):

		Years ended December 31,
		2013		2012			2011

	Cash paid during the period for:
	Income taxes, net of refunds	$	18,537	$	2,543		$	10,324
	Interest, net of amounts capitalized	184,010		200,923			217,789
	Significant non-cash investing and financing activities:
	Accrued capital expenditures	$	33,184	$	26,208		$	27,245
	Dividends declared but not paid	62,528		59,789			—
	Liabilities assumed relating to acquisition of SCE Four Corners’ interest (see Note 3)	145,609		—			—

Intangible Assets	'
	Intangible Assets

	We have no goodwill recorded and have separately disclosed other intangible assets, primarily APS’s software, on Pinnacle West’s Consolidated Balance Sheets. The intangible assets are amortized over their finite useful lives. Amortization expense was $53 million in 2013, $50 million in 2012, and $47 million in 2011. Estimated amortization expense on existing intangible assets over the next five years is $47 million in 2014, $38 million in 2015, $29 million in 2016, $19 million in 2017, and $7 million in 2018. At December 31, 2013, the weighted-average remaining amortization period for intangible assets was 6 years.

Investments	'
	Investments

	El Dorado accounts for its investments using either the equity method (if significant influence) or the cost method (if less than 20% ownership).

	Our investments in the nuclear decommissioning trust fund are accounted for in accordance with guidance on accounting for certain investments in debt and equity securities. See Note 14 and Note 20 for more information on these investments.

Business Segments	'
	Business Segments

	Pinnacle West’s reportable business segment is our regulated electricity segment, which consists of traditional regulated retail and wholesale electricity businesses (primarily electricity service to Native Load customers) and related activities and includes electricity generation, transmission and distribution. All other segment activities are insignificant.

Summary_of_Significant_Account2

Summary of Significant Accounting Policies (Tables)	12 Months Ended
	Dec. 31, 2013
Summary of Significant Accounting Policies	'
Schedule of impacts of the reclassifications of prior years (previously reported)	'
	The following tables show the impacts of the reclassifications of prior years (previously reported) amounts (dollars in thousands):

	Balance Sheets - December 31, 2012	As		Reclassifications to			Amount reported
		previously		conform to current year			after reclassification
		reported		presentation			to conform to current
							year presentation
	Long-Term Debt less Current Maturities —
	Long-term debt less current maturities	$	3,160,219	$	38,869		$	3,199,088
	Long-Term Debt less Current Maturities —
	Palo Verde sale leaseback lessor notes less
	current maturities	38,869		(38,869		)	—


	Statement of Cash Flows for the	As previously		Reclassifications to			Amount reported after
	Year Ended December 31, 2012	reported		conform to current year			reclassification to
				presentation			conform to current
							year presentation
	Cash Flows from Operating Activities
	Deferred income taxes	$	228,602	$	(41,579	)	$	187,023
	Deferred investment tax credit	—		41,579			41,579
	Accrued taxes and income tax receivable	8,693		(8,693		)	—
	Income tax receivable	—		(4,043		)	(4,043		)
	Accrued taxes	—		12,736			12,736


	Statement of Cash Flows for the	As previously		Reclassifications to			Amount reported after
	Year Ended December 31, 2011	reported		conform to current year			reclassification to
				presentation			conform to current year
							presentation
	Cash Flows from Operating Activities
	Deferred income taxes	$	176,192	$	(58,240	)	$	117,952
	Deferred investment tax credit	—		58,240			58,240
	Accrued taxes and income tax receivable	12,068		(12,068		)	—
	Income tax receivable	—		3,983			3,983
	Accrued taxes	—		8,085			8,085


Summary of supplemental cash flow information	'
	The following table summarizes supplemental Pinnacle West cash flow information for each of the last three years (dollars in thousands):

		Years ended December 31,
		2013		2012			2011

	Cash paid during the period for:
	Income taxes, net of refunds	$	18,537	$	2,543		$	10,324
	Interest, net of amounts capitalized	184,010		200,923			217,789
	Significant non-cash investing and financing activities:
	Accrued capital expenditures	$	33,184	$	26,208		$	27,245
	Dividends declared but not paid	62,528		59,789			—
	Liabilities assumed relating to acquisition of SCE Four Corners’ interest (see Note 3)	145,609		—			—

Regulatory_Matters_Tables

Regulatory Matters (Tables)	12 Months Ended
Regulatory Matters (Tables)	Dec. 31, 2013
Regulatory Matters	'
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 for 2013 and 2012 (dollars in millions):

		Twelve Months Ended
		December 31,
		2013			2012
	Beginning balance	$	73		$	28
	Deferred fuel and purchased power costs - current period	(21		)	(72		)
	Amounts (charged) credited to customers	(31		)	117
	Ending balance	$	21		$	73
Schedule of regulatory assets	'
	The detail of regulatory assets is as follows (dollars in millions):

		Remaining		December 31, 2013					December 31, 2012
		Amortization		December 31, 2013					December 31, 2012
		Period		Current			Non-Current		Current		Non-Current
	Pension and other postretirement benefits	(a	)	$	—		$	314	$	—	$	780
	Income taxes — AFUDC equity	2043		4			105		4		92
	Deferred fuel and purchased power — mark-to-market (Note 17)	2016		5			29		19		21
	Transmission vegetation management	2016		9			14		9		23
	Coal reclamation	2038		8			18		8		24
	Palo Verde VIEs (Note 19)	2046		—			41		—		38
	Deferred compensation	2036		—			34		—		34
	Deferred fuel and purchased power (b) (c)	2014		21			—		73		—
	Tax expense of Medicare subsidy	2023		2			15		2		17
	Loss on reacquired debt	2034		1			17		2		18
	Income taxes — investment tax credit basis adjustment	2043		1			39		1		26
	Pension and other postretirement benefits deferral	2015		8			4		8		13
	Four Corners cost deferral	2024		—			37		—		—
	Lost fixed cost recovery	2014		25			—		7		—
	Transmission cost adjustor	2015		8			2		10		—
	Retired power plant costs	2020		3			18		—		—
	Other	Various		2			25		1		14
	Total regulatory assets (d)			$	97		$	712	$	144	$	1,100

	(a) This asset represents the future recovery of under-funded pension and other postretirement benefit obligations through retail rates. If these costs are disallowed by the ACC, this regulatory asset would be charged to OCI and result in lower future revenues. See Note 8 for further discussion.
	(b) See “Cost Recovery Mechanisms” discussion above.
	(c) Subject to a carrying charge.
	(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 and Transmission Cost Adjustor.”
Schedule of regulatory liabilities	'
	The detail of regulatory liabilities is as follows (dollars in millions):

		Remaining		December 31, 2013					December 31, 2012
		Amortization		December 31, 2013					December 31, 2012
		Period		Current			Non-Current		Current		Non-Current
	Removal costs	(a	)	$	28		$	303	$	27	$	321
	Asset retirement obligations	(a	)	—			266		—		256
	Renewable energy standard (b)	2015		33			15		43		—
	Income taxes — change in rates	2043		—			74		—		66
	Spent nuclear fuel	2047		6			36		10		36
	Deferred gains on utility property	2019		2			10		2		12
	Income taxes — deferred investment tax credit	2043		3			79		2		52
	Demand side management (b)	2014		27			—		4		—
	Other	Various		—			18		—		16
	Total regulatory liabilities			$	99		$	801	$	88	$	759

	(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 (see Note 12).
	(b) See “Cost Recovery Mechanisms” discussion above.

Income_Taxes_Tables

Income Taxes (Tables)	12 Months Ended
Income Taxes (Tables)	Dec. 31, 2013
Income Taxes	'
Tabular reconciliation of the total amounts of unrecognized tax benefits, excluding interest and penalties, at the beginning and end of the year	'
	The following is a tabular reconciliation of the total amounts of unrecognized tax benefits, excluding interest and penalties, at the beginning and end of the year that are included in accrued taxes and unrecognized tax benefits (dollars in thousands):

		2013			2012			2011
	Total unrecognized tax benefits, January 1	$	133,422		$	136,005		$	127,595
	Additions for tax positions of the current year	3,516			5,167			10,915
	Additions for tax positions of prior years	13,158			—			—
	Reductions for tax positions of prior years for:
	Changes in judgment	(108,099		)	(7,729		)	(1,555		)
	Settlements with taxing authorities	—			—			(124		)
	Lapses of applicable statute of limitations	—			(21		)	(826		)
	Total unrecognized tax benefits, December 31	$	41,997		$	133,422		$	136,005

Components of income tax expense	'
	The components of income tax expense are as follows (dollars in thousands):

		Year Ended December 31,
		2013			2012			2011
	Current:
	Federal	$	(81,784	)	$	(3,493	)	$	(310	)
	State	10,537			8,395			15,140
	Total current	(71,247		)	4,902			14,830
	Deferred:
	Federal	279,973			200,322			159,566
	State	21,865			28,280			16,626
	Total deferred	301,838			228,602			176,192
	Total income tax expense	230,591			233,504			191,022
	Less: income tax expense (benefit) on discontinued operations	—			(3,813		)	7,418
	Income tax expense — continuing operations	$	230,591		$	237,317		$	183,604

Comparison of pretax income from continuing operations at the federal income tax rate to income tax expense - continuing operations	'
	The following chart compares pretax income from continuing operations at the 35% federal income tax rate to income tax expense — continuing operations (dollars in thousands):

		Year Ended December 31,
		2013			2012			2011

	Federal income tax expense at 35% statutory rate	$	234,695		$	229,709		$	188,733
	Increases (reductions) in tax expense resulting from:
	State income tax net of federal income tax benefit	21,387			23,819			19,594
	Credits and favorable adjustments related to prior years resolved in current year	(3,356		)	—			—
	Medicare Subsidy Part-D	823			483			823
	Allowance for equity funds used during construction (see Note 1)	(6,997		)	(6,158		)	(6,881		)
	Palo Verde VIE noncontrolling interest (see Note 19)	(11,862		)	(11,065		)	(9,636		)
	Other	(4,099		)	529			(9,029		)
	Income tax expense — continuing operations	$	230,591		$	237,317		$	183,604

Net deferred income tax liability recognized on the Consolidated Balance Sheets	'
	The following table shows the net deferred income tax liability recognized on the Consolidated Balance Sheets (dollars in thousands):

		December 31,
		2013			2012
	Current asset	$	91,152		$	152,191
	Long-term liability	(2,351,882		)	(2,151,371		)
	Deferred income taxes — net	$	(2,260,730	)	$	(1,999,180	)

Components of the net deferred income tax liability	'
	The components of the net deferred income tax liability were as follows (dollars in thousands):

		December 31,
		2013			2012
	DEFERRED TAX ASSETS
	Risk management activities	$	44,920		$	72,243
	Regulatory liabilities:
	Asset retirement obligation and removal costs	235,959			238,669
	Unamortized investment tax credits	82,116			53,837
	Other	42,609			33,764
	Pension and other postretirement liabilities	198,642			408,764
	Renewable energy incentives	65,434			66,941
	Credit and loss carryforwards	133,070			139,022
	Other	148,492			68,844
	Total deferred tax assets	951,242			1,082,084
	DEFERRED TAX LIABILITIES
	Plant-related	(2,903,730		)	(2,584,166		)
	Risk management activities	(16,191		)	(23,940		)
	Regulatory assets:
	Allowance for equity funds used during construction	(43,058		)	(37,899		)
	Deferred fuel and purchased power	(8,282		)	(28,858		)
	Deferred fuel and purchased power — mark-to-market	(13,343		)	(15,796		)
	Pension and other postretirement benefits	(129,250		)	(316,757		)
	Other	(93,202		)	(68,170		)
	Other	(4,916		)	(5,678		)
	Total deferred tax liabilities	(3,211,972		)	(3,081,264		)
	Deferred income taxes — net	$	(2,260,730	)	$	(1,999,180	)

Lines_of_Credit_and_ShortTerm_1

Lines of Credit and Short-Term Borrowings (Tables)	12 Months Ended
	Dec. 31, 2013
Lines of Credit and Short-Term Borrowings	'
Schedule of consolidated credit facilities and amounts available and outstanding	'
	The table below presents the consolidated credit facilities and the amounts available and outstanding as of December 31, 2013 (dollars in millions):

	Credit Facility	Expiration	Amount		Unused		Commitment
			Committed		Amount (a)		Fees
	Pinnacle West Revolving Credit Facility	November 2016	$	200	$	200	0.175	%

	APS Revolving Credit Facility	November 2016	500		347		0.125	%

	APS Revolving Credit Facility	April 2018	500		500		0.125	%
	Total		$	1,200	$	1,047

	(a) At December 31, 2013, APS had $153 million of outstanding commercial paper. Accordingly, at such date, the total combined amount available under its two $500 million credit facilities was $847 million.


	The table below presents the consolidated credit facilities and the amounts available and outstanding as of December 31, 2012 (dollars in millions):

	Credit Facility	Expiration	Amount		Unused		Commitment
			Committed		Amount (a)		Fees
	Pinnacle West Revolving Credit Facility	November 2016	$	200	$	200	0.225	%

	APS Revolving Credit Facility	November 2016	500		408		0.175	%

	APS Revolving Credit Facility	February 2015	500		500		0.2	%
	Total		$	1,200	$	1,108

	(a) At December 31, 2012, APS had $92 million of outstanding commercial paper. Accordingly, at such date the total combined amount available under its two $500 million credit facilities was $908 million.

LongTerm_Debt_and_Liquidity_Ma1

Long-Term Debt and Liquidity Matters (Tables)	12 Months Ended
Long-Term Debt and Liquidity Matters (Tables)	Dec. 31, 2013
Long-Term Debt and Liquidity Matters	'
Components of long-term debt on the Consolidated Balance Sheets	'
	The following table presents the components of long-term debt on the Consolidated Balance Sheets outstanding at December 31, 2013 and 2012 (dollars in thousands):

		Maturity		Interest		December 31,
		Dates (a)		Rates		2013			2012
	APS
	Pollution Control Bonds:
	Variable	2029-2038		(b)		$	75,580		$	75,580
	Fixed	2024-2034		1.25%-6.00%		426,125			490,275
	Total Pollution Control Bonds					501,705			565,855

	Senior unsecured notes	2014-2042		4.50%-8.75%		2,675,000			2,575,000
	Palo Verde sale leaseback lessor notes	2015		8.00%		38,869			65,547
	Unamortized discount					(8,732		)	(9,486		)
	Unamortized premium					5,047			—
	Total APS long-term debt					3,211,889			3,196,916
	Less current maturities	(d)				540,424			122,828
	Total APS long-term debt less current maturities					2,671,465			3,074,088
	Pinnacle West
	Term loan	2015		(c)		125,000			125,000
	TOTAL LONG-TERM DEBT LESS CURRENT MATURITIES					$	2,796,465		$	3,199,088

	(a) This schedule does not reflect the timing of redemptions that may occur prior to maturities.
	(b) The weighted-average rate for the variable rate pollution control bonds was 0.03%-0.06% at December 31, 2013 and 0.13%-0.15% at December 31, 2012.
	(c) The weighted-average interest rate was 1.269% at December 31, 2013 and 1.312% at December 31, 2012.
	(d) Current maturities include $215 million of pollution control bonds expected to be remarketed in 2014 and $300 million in senior unsecured notes that mature in 2014.

Principal payments due on Pinnacle West's and APS's total long-term debt	'
	The following table shows principal payments due on Pinnacle West’s and APS’s total long-term debt (dollars in millions):

	Year	Consolidated			Consolidated
	Year	Pinnacle West			APS
	2014	$	540		$	540
	2015	470			345
	2016	358			358
	2017	—			—
	2018	32			32
	Thereafter	1,940			1,940
	Total	$	3,340		$	3,215

Schedule of estimated fair value of long-term debt, including current maturities	'
	The following table represents the estimated fair value of our long-term debt, including current maturities (dollars in millions):

		As of						As of
		December 31, 2013						December 31, 2012
		Carrying			Fair Value			Carrying			Fair Value
		Amount			Fair Value			Amount			Fair Value

	Pinnacle West	$	125		$	125		$	125		$	125
	APS	3,212			3,454			3,197			3,750
	Total	$	3,337		$	3,579		$	3,322		$	3,875

Common_Stock_and_Treasury_Stoc1

Common Stock and Treasury Stock (Tables)	12 Months Ended
Common Stock and Treasury Stock (Tables)	Dec. 31, 2013
Common Stock and Treasury Stock	'
Schedule of common stock and treasury stock activity	'
	Our common stock and treasury stock activity during each of the three years 2013, 2012 and 2011 is as follows (dollars in thousands):

		Common Stock			Treasury Stock
		Shares	Amount		Shares		Amount
	Balance at December 31, 2010	108,820,067	$	2,421,372	(50,410	)	$	(2,239	)

	Common stock issuance	536,907	22,875		—		—
	Purchase of treasury stock (a)	—	—		(88,440	)	(3,720		)
	Reissuance of treasury stock for stock compensation	—	—		27,689		1,242
	Balance at December 31, 2011	109,356,974	2,444,247		(111,161	)	(4,717		)

	Common stock issuance	480,983	22,676		—		—
	Purchase of treasury stock (a)	—	—		(89,629	)	(4,607		)
	Reissuance of treasury stock for stock compensation	—	—		105,598		5,113
	Balance at December 31, 2012	109,837,957	2,466,923		(95,192	)	(4,211		)

	Common stock issuance	442,746	24,635		—		—
	Purchase of treasury stock (a)	—	—		(174,290	)	(9,727		)
	Reissuance of treasury stock for stock compensation	—	—		170,538		9,630
	Balance at December 31, 2013	110,280,703	$	2,491,558	(98,944	)	$	(4,308	)

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

Retirement_Plans_and_Other_Ben1

Retirement Plans and Other Benefits (Tables)	12 Months Ended
Retirement Plans and Other Benefits (Tables)	Dec. 31, 2013
Retirement Plans and Other Benefits	'
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)	'
	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 to the regulatory asset) (dollars in thousands):

			Pension									Other Benefits
			2013			2012			2011			2013			2012			2011
	Service cost-benefits earned during the period		$	64,195		$	63,502		$	57,605		$	23,597		$	27,163		$	21,856
	Interest cost on benefit obligation		112,392			119,586			124,727			41,536			46,467			46,807
	Expected return on plan assets		(146,333		)	(140,979		)	(133,678		)	(45,717		)	(45,793		)	(41,536		)
	Amortization of:
	Transition obligation		—			—			—			—			452			452
	Prior service cost (credit)		1,097			1,143			1,400			(179		)	(179		)	(179		)
	Net actuarial loss		39,852			44,250			25,956			11,310			20,233			15,015
	Net periodic benefit cost		$	71,203		$	87,502		$	76,010		$	30,547		$	48,343		$	42,415
	Portion of cost charged to expense		$	38,968		$	36,333		$	29,312		$	18,469		$	19,321		$	15,208

Schedule of changes in the benefit obligations and funded status	'
	The following table shows the plans’ changes in the benefit obligations and funded status for the years 2013 and 2012 (dollars in thousands):

			Pension						Other Benefits
			2013			2012			2013			2012
	Change in Benefit Obligation
	Benefit obligation at January 1		$	2,850,846		$	2,699,126		$	990,418		$	1,047,094
	Service cost		64,195			63,502			23,597			27,163
	Interest cost		112,392			119,586			41,536			46,467
	Benefit payments		(125,269		)	(113,632		)	(26,675		)	(26,279		)
	Actuarial (gain) loss		(255,634		)	82,264			(138,458		)	(104,027		)
	Benefit obligation at December 31		2,646,530			2,850,846			890,418			990,418

	Change in Plan Assets
	Fair value of plan assets at January 1		2,079,181			1,850,550			684,221			608,663
	Actual return on plan assets		150,546			259,363			76,995			83,567
	Employer contributions		140,500			65,000			14,438			22,707
	Benefit payments		(106,106		)	(95,732		)	(27,315		)	(30,716		)
	Fair value of plan assets at December 31		2,264,121			2,079,181			748,339			684,221
	Funded Status at December 31		$	(382,409	)	$	(771,665	)	$	(142,079	)	$	(306,197	)

Schedule of projected benefit obligation and the accumulated benefit obligation for pension plans with an accumulated obligation in excess of plan assets	'
	The following table shows the projected benefit obligation and the accumulated benefit obligation for pension plans with an accumulated obligation in excess of plan assets as of December 31, 2013 and 2012 (dollars in thousands):

			2013			2012
	Projected benefit obligation		$	2,646,530		$	2,850,846
	Accumulated benefit obligation		2,469,889			2,646,306
	Fair value of plan assets		2,264,121			2,079,181


Schedule of amounts recognized on the Consolidated Balance Sheets	'
	The following table shows the amounts recognized on the Consolidated Balance Sheets as of December 31, 2013 and 2012 (dollars in thousands):

			Pension						Other Benefits
			2013			2012			2013			2012
	Current liability		$	(10,860	)	$	(19,107	)	$	—		$	—
	Noncurrent liability		(371,549		)	(752,558		)	(142,079		)	(306,197		)
	Net amount recognized		$	(382,409	)	$	(771,665	)	$	(142,079	)	$	(306,197	)

Schedule of accumulated other comprehensive loss	'
	The following table shows the details related to accumulated other comprehensive loss as of December 31, 2013 and 2012 (dollars in thousands):

			Pension						Other Benefits
			2013			2012			2013			2012
	Net actuarial loss		$	344,540		$	644,239		$	57,816		$	238,862
	Prior service cost (credit)		2,072			3,169			(296		)	(475		)
	APS’s portion recorded as a regulatory asset		(265,107		)	(550,471		)	(49,298		)	(230,020		)
	Income tax benefit		(32,204		)	(38,303		)	(2,528		)	(2,585		)
	Accumulated other comprehensive loss		$	49,301		$	58,634		$	5,694		$	5,782

Schedule of estimated amounts that will be amortized from accumulated other comprehensive loss and regulatory assets into net periodic benefit cost	'
	The following table shows the estimated amounts that will be amortized from accumulated other comprehensive loss and regulatory assets into net periodic benefit cost in 2014 (dollars in thousands):

			Pension			Other
			Pension			Benefits
	Net actuarial loss		$	8,363		$	—
	Prior service cost (credit)		874			(179		)
	Total amounts estimated to be amortized from accumulated other comprehensive loss and regulatory assets in 2014		$	9,237		$	(179	)

Schedule of weighted-average assumptions used for both the pension and other benefits to determine benefit obligations and net periodic benefit costs	'
	The following table shows the weighted-average assumptions used for both the pension and other benefits to determine benefit obligations and net periodic benefit costs:

			Benefit Obligations				Benefit Costs
			As of December 31,				For the Years Ended December 31,
			2013		2012		2013		2012		2011
	Discount rate – pension		4.88	%	4.01	%	4.01	%	4.42	%	5.31	%
	Discount rate – other benefits		5.1	%	4.2	%	4.2	%	4.59	%	5.49	%
	Rate of compensation increase		4	%	4	%	4	%	4	%	4	%
	Expected long-term return on plan assets		N/A		N/A		7	%	7.75	%	7.75	%
	Initial healthcare cost trend rate		7.5	%	7.5	%	7.5	%	7.5	%	8	%
	Ultimate healthcare cost trend rate		5	%	5	%	5	%	5	%	5	%
	Number of years to ultimate trend rate		4		4		4		4		4

Schedule of effects of one percentage point change in the assumed initial and ultimate health care cost trend rates	'
	A one percentage point change in the assumed initial and ultimate healthcare cost trend rates would have the following effects (dollars in millions):

			1% Increase			1% Decrease
	Effect on other postretirement benefits expense, after consideration of amounts capitalized or billed to electric plant participants		$	13		$	(10	)
	Effect on service and interest cost components of net periodic other postretirement benefit costs		14			(11		)
	Effect on the accumulated other postretirement benefit obligation		149			(120		)


Schedule of fair value of pension plan and other postretirement benefit plan assets, by asset category	'
	The fair value of Pinnacle West’s pension plan and other postretirement benefit plan assets at December 31, 2013, by asset category, are as follows (dollars in thousands):

			Quoted Prices			Significant			Significant			Other (c)			Balance at
			in Active			Other			Unobservable						December 31,
			Markets for			Observable			Inputs						2013
			Identical			Inputs			(Level 3)
			Assets			(Level 2)
			(Level 1)
	Pension Plan:
	Assets:
	Cash and cash equivalents		$	504		$	—		$	—		$	—		$	504
	Fixed Income Securities:
	Corporate		—			898,621			—			—			898,621
	U.S. Treasury		231,590			—			—			—			231,590
	Other (b)		—			84,011			—			—			84,011
	Equities:
	U.S. Companies		239,036			—			—			—			239,036
	International Companies		19,429			—			—			—			19,429
	Common and collective trusts:
	U.S. Equities		—			116,150			—			—			116,150
	International Equities		—			367,551			—			—			367,551
	Fixed Income					137,520									137,520
	Real estate		—			119,739			—			—			119,739
	Short-term investments and other		—			41,060			8,660		(a)	250			49,970

	Total Pension Plan		$	490,559		$	1,764,652		$	8,660		$	250		$	2,264,121
	Other Benefits:
	Assets:
	Fixed Income Securities:
	Corporate		$	—		$	153,888		$	—		$	—		$	153,888
	U.S. Treasury		98,704			—			—			—			98,704
	Other (b)		—			27,936			—			—			27,936
	Equities:
	U.S. Companies		252,181			—			—			—			252,181
	International Companies		20,892			—			—			—			20,892
	Common and collective trusts:
	U.S. Equities		—			80,751			—			—			80,751
	International Equities		—			92,382			—			—			92,382
	Real Estate		—			10,761			—			—			10,761
	Short-term investments and other		—			8,414			—			2,430			10,844

	Total Other Benefits		$	371,777		$	374,132		$	—		$	2,430		$	748,339

	(a) Represents investments in a partnership that invests in privately held portfolio companies.
	(b) This category consists primarily of debt securities issued by municipalities.
	(c) Represents plan receivables and payables.

	The fair value of Pinnacle West’s pension plan and other postretirement benefit plan assets at December 31, 2012, by asset category, are as follows (dollars in thousands):

			Quoted Prices			Significant			Significant			Other (c)			Balance at
			in Active			Other			Unobservable						December 31,
			Markets for			Observable			Inputs						2012
			Identical			Inputs			(Level 3)
			Assets			(Level 2)
			(Level 1)
	Pension Plan:
	Assets:
	Cash and cash equivalents		$	579		$	—		$	—		$	—		$	579
	Fixed Income Securities:
	Corporate		—			607,749			—			—			607,749
	U.S. Treasury		232,161			—			—			—			232,161
	Other (b)		—			67,992			—			—			67,992
	Equities:
U.S. Companies		531,291			—			—			—			531,291
International Companies		43,848			—			—			—			43,848
Common and collective trusts:
U.S. Equities		—			176,694			—			—			176,694
International Equities		—			271,735			—			—			271,735
Real estate		—			117,854			—			—			117,854
Short-term investments and other		—			26,922			2,419		(a)	(63		)	29,278

Total Pension Plan		$	807,879		$	1,268,946		$	2,419		$	(63	)	$	2,079,181
Other Benefits:
Assets:
Cash and cash equivalents		$	60		$	—		$	—		$	—		$	60
Fixed Income Securities:
Corporate		—			163,306			—			—			163,306
U.S. Treasury		112,558			—			—			—			112,558
Other (b)		—			33,998			—			—			33,998
Equities:
U.S. Companies		205,714			—			—			—			205,714
International Companies		14,412			—			—			—			14,412
Common and collective trusts:
U.S. Equities		—			60,038			—			—			60,038
International Equities		—			76,969			—			—			76,969
Real Estate		—			9,378			—			—			9,378
Short-term investments and other		402			6,340			—			1,046			7,788

Total Other Benefits		$	333,146		$	350,029		$	—		$	1,046		$	684,221

(a) Represents investments in a partnership that invests in privately held portfolio companies.
(b) This category consists primarily of debt securities issued by municipalities.
(c) Represents plan receivables and payables.

Schedule of changes in fair value for assets that are measured at fair value on a recurring basis using significant unobservable inputs (Level 3)	'
	The following table shows the changes in fair value for assets that are measured at fair value on a recurring basis using significant unobservable inputs (Level 3) for the year ended December 31, 2013 and 2012 (dollars in thousands):

			Pension
	Short-Term Investments and Other		2013			2012
	Beginning balance at January 1		$	2,419		$	—
	Actual return on assets still held at December 31		(498		)	(668		)
	Purchases, sales, and settlements		6,739			3,087
	Transfers in and/or out of Level 3		—			—
	Ending balance at December 31		$	8,660		$	2,419

Schedule of estimated future benefit payments, which reflect estimated future employee service, for the next five years and the succeeding five years thereafter	'
	Benefit payments, which reflect estimated future employee service, for the next five years and the succeeding five years thereafter, are estimated to be as follows (dollars in thousands):

	Year		Pension			Other Benefits
	2014		$	129,159		$	28,664
	2015		143,452			31,804
	2016		149,105			34,933
	2017		162,678			37,966
	2018		169,064			40,972
	Years 2019-2023		972,826			245,366

Leases_Tables

Leases (Tables)	12 Months Ended
	Dec. 31, 2013
Leases	'
Estimated future minimum lease payments for Pinnacle West's and APS's operating leases, excluding purchased power agreements	'
	Estimated future minimum lease payments for Pinnacle West’s and APS’s operating leases, excluding purchased power agreements, are approximately as follows (dollars in millions):

	Year	Pinnacle West		APS
		Consolidated
	2014	$	20	$	17
	2015	17		14
	2016	6		5
	2017	5		5
	2018	4		4
	Thereafter	59		59
	Total future lease commitments	$	111	$	104

JointlyOwned_Facilities_Tables

Jointly-Owned Facilities (Tables)	12 Months Ended
	Dec. 31, 2013
Jointly-Owned Facilities	'
APS's interests in jointly-owned facilities recorded on the Consolidated Balance Sheets	'
	The following table shows APS’s interests in those jointly-owned facilities recorded on the Consolidated Balance Sheets at December 31, 2013 (dollars in thousands):

		Percent		Plant in		Accumulated		Construction
		Owned		Service		Depreciation		Work in
								Progress
	Generating facilities:
	Palo Verde Units 1 and 3	29.1	%	$	1,701,844	$	1,027,523	$	22,400
	Palo Verde Unit 2 (a)	16.8	%	543,972		338,918		10,095
	Palo Verde Common	28	% (b)	538,818		219,801		81,599
	Palo Verde Sale Leaseback		(a)	351,050		225,925		—
	Four Corners Units 4, 5 and Common (d)	63	%	809,946		608,194		14,434
	Navajo Generating Station Units 1, 2 and 3	14	%	270,448		150,501		2,864
	Cholla common facilities (c)	63.3	% (b)	148,299		47,851		7,159
	Transmission facilities:
	ANPP 500kV System	34.2	% (b)	98,145		32,350		1,095
	Navajo Southern System	22.2	% (b)	58,702		16,937		518
	Palo Verde — Yuma 500kV System	18	% (b)	12,115		4,656		11,786
	Four Corners Switchyards	48.1	% (b)	33,460		9,052		185
	Phoenix — Mead System	17.1	% (b)	39,758		12,140		—
	Palo Verde — Estrella 500kV System	50	% (b)	89,571		14,883		21
	Morgan — Pinnacle Peak System	64.5	% (b)	130,132		6,651		1,042
	Round Valley System	50	% (b)	488		268		—
	Palo Verde — Morgan System	90	% (b)	—		—		36,601


	(a) See Note 19.
	(b) Weighted-average of interests.
	(c) PacifiCorp owns Cholla Unit 4 and APS operates the unit for PacifiCorp. The common facilities at Cholla are jointly-owned.
	(d) See Note 3.

Commitments_and_Contingencies_

Commitments and Contingencies (Tables)	12 Months Ended
Commitments and Contingencies (Tables)	Dec. 31, 2013
Commitments and Contingencies.	'
Summary of estimated coal take-or-pay commitments	'
	The following table summarizes our estimated coal take-or-pay commitments (dollars in millions):

				Years Ended December 31,
		2014		2015		2016		2017		2018		Thereafter
	Coal take-or-pay commitments (a)	$	152	$	157	$	166	$	180	$	175	$	2,539


	(a) Total take-or-pay commitments are approximately $3.4 billion. The total net present value of these commitments is approximately $2.2 billion.

Summary of actual take-or-pay commitments	'
	The following table summarizes the actual amounts purchased under the coal contracts which include take-or-pay provisions for each of the last three years (dollars in millions):

		Year Ended December 31,
		2013		2012		2011
	Total purchases	$	188	$	196	$	191

Asset_Retirement_Obligations_T

Asset Retirement Obligations (Tables)	12 Months Ended
	Dec. 31, 2013
Asset Retirement Obligations	'
Change in asset retirement obligations	'
	The following schedule shows the change in our asset retirement obligations for 2013 and 2012 (dollars in millions):

		2013			2012
	Asset retirement obligations at the beginning of year	$	357		$	280
	Changes attributable to:
	Accretion expense	24			19
	Settlements	(12		)	—
	Assumed SCE’s obligation	34			—
	Estimated cash flow revisions	(56		)	58
	Asset retirement obligations at the end of year	$	347		$	357

Selected_Quarterly_Financial_D1

Selected Quarterly Financial Data (Unaudited) (Tables)	12 Months Ended
	Dec. 31, 2013
Selected Quarterly Financial Data (Unaudited)	'
Schedule of quarterly financial information	'
	Consolidated quarterly financial information for 2013 and 2012 is provided in the tables below (dollars in thousands, except per share amounts).

		2013 Quarter Ended									2013
		March 31,			June 30,		Sept. 30,		Dec. 31,		Total

	Operating revenues	$	686,652		$	915,822	$	1,152,392	$	699,762	$	3,454,628
	Operations and maintenance	223,250			229,300		233,323		238,854		924,727
	Operating income	86,923			259,812		415,688		83,900		846,323
	Income taxes	12,469			77,043		131,912		9,167		230,591
	Income from continuing operations	32,836			139,598		234,718		32,814		439,966
	Net income attributable to common shareholders	24,444			131,207		226,163		24,260		406,074

	Earnings Per Share:
	Income from continuing operations attributable to common shareholders — Basic	$	0.22		$	1.19	$	2.06	$	0.22	$	3.69
	Net income attributable to common shareholders — Basic	0.22			1.19		2.06		0.22		3.69
	Income from continuing operations attributable to common shareholders — Diluted	0.22			1.18		2.04		0.22		3.66
	Net income attributable to common shareholders — Diluted	0.22			1.18		2.04		0.22		3.66

		2012 Quarter Ended									2012
		March 31,			June 30,		Sept. 30,		Dec. 31,		Total

	Operating revenues	$	620,631		$	878,576	$	1,109,475	$	693,122	$	3,301,804
	Operations and maintenance	210,663			216,236		220,729		237,141		884,769
	Operating income	48,007			254,489		447,970		101,289		851,755
	Income taxes	(4,645		)	76,689		147,116		18,157		237,317
	Income from continuing operations	284			130,930		252,874		34,905		418,993
	Net income (loss) attributable to common shareholders	(8,257		)	122,345		244,823		22,631		381,542

	Earnings Per Share:
	Income (loss) from continuing operations attributable to common shareholders — Basic	$	(0.07	)	$	1.12	$	2.23	$	0.24	$	3.54
	Net income (loss) attributable to common shareholders — Basic	(0.08		)	1.12		2.23		0.21		3.48
	Income (loss) from continuing operations attributable to common shareholders — Diluted	(0.07		)	1.12		2.21		0.24		3.5
	Net income (loss) attributable to common shareholders — Diluted	(0.08		)	1.11		2.21		0.2		3.45

Fair_Value_Measurements_Tables

Fair Value Measurements (Tables)	12 Months Ended
	Dec. 31, 2013
Fair Value Measurements	'
Fair value of assets and liabilities that are measured at fair value on a recurring basis	'
	The following table presents the fair value at December 31, 2013 of our assets and liabilities that are measured at fair value on a recurring basis (dollars in millions):

		Quoted Prices			Significant			Significant			Other			Balance at
		in Active			Other			Unobservable						December 31,
		Markets for			Observable			Inputs (a)						2013
		Identical			Inputs			(Level 3)
		Assets			(Level 2)
		(Level 1)
	Assets
	Risk management activities — derivative instruments:
	Commodity Contracts	$	—		$	9		$	41		$	(9	) (b)	$	41
	Nuclear decommissioning trust:
	U.S. commingled equity funds	—			272			—			—			272
	Fixed income securities:
	U.S. Treasury	107			—			—			—			107
	Cash and cash equivalent funds	—			11			—			(3		) (c)	8
	Corporate debt	—			88			—			—			88
	Mortgage-backed securities	—			85			—			—			85
	Municipality bonds	—			71			—			—			71
	Other	—			11			—			—			11
	Subtotal nuclear decommissioning trust	107			538			—			(3		)	642
	Total	$	107		$	547		$	41		$	(12	)	$	683

	Liabilities
	Risk management activities — derivative instruments:
	Commodity contracts	$	—		$	(33	)	$	(90	)	$	21	(b)	$	(102	)

	(a) Primarily consists of heat rate options and other long-dated electricity contracts.
	(b) Represents counterparty netting, margin and collateral. See Note 17.
	(c) Represents nuclear decommissioning trust net pending securities sales and purchases.

	The following table presents the fair value at December 31, 2012 of our assets and liabilities that are measured at fair value on a recurring basis (dollars in millions):

		Quoted Prices			Significant			Significant			Other			Balance at
		in Active			Other			Unobservable						December 31,
		Markets for			Observable			Inputs (a)						2012
		Identical			Inputs			(Level 3)
		Assets			(Level 2)
		(Level 1)
	Assets
	Cash equivalents	$	16		$	—		$	—		$	—		$	16
	Risk management activities — derivative instruments:
	Commodity Contracts	—			22			62			(22		) (b)	62
	Nuclear decommissioning trust:
	U.S. commingled equity funds	—			204			—			—			204
	Fixed income securities:
	U.S. Treasury	104			—			—			—			104
	Cash and cash equivalent funds	6			13			—			(4		) (c)	15
	Corporate debt	—			80			—			—			80
	Mortgage-backed securities	—			83			—			—			83
	Municipality bonds	—			74			—			—			74
	Other	—			11			—			—			11
	Subtotal nuclear decommissioning trust	110			465			—			(4		)	571
	Total	$	126		$	487		$	62		$	(26	)	$	649

	Liabilities
	Risk management activities — derivative instruments:
	Commodity contracts	$	—		$	(96	)	$	(110	)	$	47	(b)	$	(159	)

	(a) Primarily consists of heat rate options and other long-dated electricity contracts.
	(b) Represents counterparty netting, margin and collateral. See Note 17.
	(c) 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	'


		December 31, 2013						Valuation		Significant				Weighted-
		Fair Value (millions)
	Commodity Contracts	Assets			Liabilities			Technique		Unobservable Input		Range		Average
	Electricity:
	Forward Contracts (a)	$	40		$	66		Discounted cash flows		Electricity forward price (per MWh)		$24.89 - $65.04		$	41.09

	Option Contracts (b)	—			19			Option model		Electricity forward price (per MWh)		$39.91 - $85.41		$	58.7
										Natural gas forward price (per MMbtu)		$3.57 - $3.80		$	3.71
										Electricity price volatilities		35% - 94%		59		%
										Natural gas price volatilities		22% - 36%		27		%
	Natural Gas:
	Forward Contracts (a)	1			5			Discounted cash flows		Natural gas forward price (per MMbtu)		$3.47 - $4.31		$	3.87
	Total	$	41		$	90

	(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, 2012						Valuation		Significant				Weighted-
		Fair Value (millions)
	Commodity Contracts	Assets			Liabilities			Technique		Unobservable Input		Range		Average
	Electricity:
	Forward Contracts (a)	$	57		$	82		Discounted cash flows		Electricity forward price (per MWh)		$23.06 - $64.20		$	43.16

	Option Contracts	—			27			Option model		Electricity forward price (per MWh)		$36.66 - $92.19		$	60.97
										Natural gas forward price (per MMbtu)		$4.10 - $4.25		$	4.2
										Implied electricity price volatilities		15% - 66%		39		%
										Implied natural gas price volatilities		17% - 36%		23		%
	Natural Gas:
	Forward Contracts (a)	5			1			Discounted cash flows		Natural gas forward price (per MMbtu)		$3.25 - $4.44		$	3.93
	Total	$	62		$	110

	(a) Includes swaps and physical and financial contracts.
Changes in fair value for assets and liabilities that are measured at fair value on a recurring basis using Level 3 inputs	'
	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 years ended December 31, 2013 and 2012 (dollars in millions):

		Year Ended
		December 31,
	Commodity Contracts	2013			2012
	Net derivative balance at beginning of period	$	(48	)	$	(51	)
	Total net gains (losses) realized/unrealized:
	Included in earnings	—			2
	Included in OCI	—			(3		)
	Deferred as a regulatory asset or liability	(10		)	7
	Settlements	10			(5		)
	Transfers into Level 3 from Level 2	—			(2		)
	Transfers from Level 3 into Level 2	(1		)	4
	Net derivative balance at end of period	$	(49	)	$	(48	)

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

Earnings_Per_Share_Tables

Earnings Per Share (Tables)	12 Months Ended
Earnings Per Share (Tables)	Dec. 31, 2013
Earnings Per Share	'
Schedule of earnings per weighted average common share outstanding	'
		2013		2012			2011
	Basic earnings per share:
	Income from continuing operations attributable to common shareholders	$	3.69	$	3.54		$	3.01
	Income (loss) from discontinued operations	—		(0.06		)	0.1
	Earnings per share – basic	$	3.69	$	3.48		$	3.11
	Diluted earnings per share:
	Income from continuing operations attributable to common shareholders	$	3.66	$	3.5		$	2.99
	Income (loss) from discontinued operations	—		(0.05		)	0.1
	Earnings per share – diluted	$	3.66	$	3.45		$	3.09

StockBased_Compensation_Tables

Stock-Based Compensation (Tables)	12 Months Ended
Stock-Based Compensation (Tables)	Dec. 31, 2013
Stock-Based Compensation	'
Summary of granted restricted stock units and stock grants and the weighted average fair value	'


		2013			2012		2011
	Units granted	129,620			202,278		292,242
	Grant date fair value (a)	$	55.21		$	49.31	$	41.98


	(a) Weighted-average grant date fair value.

Summary of the status of restricted stock units and stock grants and changes during the year	'


	Nonvested shares	Shares		Weighted-Average
	Nonvested shares	Shares		Grant Date Fair Value
	Nonvested at January 1, 2013	480,753		$	43.58
	Granted	129,620		55.21
	Vested	191,988		40.33
	Forfeited	20,409		45.7
	Nonvested at December 31, 2013	397,976		47.74


Schedule of amount of cash required to settle the payments on restricted stock units	'
	The amount of cash required to settle the payments on restricted stock units is (dollars in millions):

	Year	2013			2012		2011
	2007 Grant	$	—		$	—	$	1
	2008 Grant	—			1.9		1.6
	2009 Grant	3			1.7		1.5
	2010 Grant	2.3			0.6		0.6
	2011 Grant	2.5			0.7		—
	2012 Grant	2.2			—		—


Summary of the performance shares granted and the weighted average fair value	'


		2013			2012		2011
	Units granted (a)	176,332			185,878		175,072
	Grant date fair value (b)	$	55.45		$	47.4	$	41.71


	(a) Reflects the target payout level.
	(b) Weighted-average grant date fair value.

Summary of the status of performance shares and changes during the year	'


	Nonvested shares (a)	Shares		Weighted-Average
	Nonvested shares (a)	Shares		Grant Date Fair Value
	Nonvested at January 1, 2013	347,690		$	44.67
	Granted	176,332		55.45
	Increase in performance factor	40,183		41.71
	Vested	200,915		41.71
	Forfeited	18,894		48.11
	Nonvested at December 31, 2013	344,396		51.13


	(a) Nonvested shares are reflected at target payout level. The increase or decrease in the number of shares from the target level to the estimated actual payout level is included in the increase for performance factor amounts in the year the award vests.

Summary of stock option activity under prior equity incentive plans	'


	Options	Shares		Weighted-
				Average
				Exercise
				Price
	Outstanding at January 1, 2013	7,925		$	32.29
	Exercised	3,625		32.29
	Forfeited or expired	4,300		32.29
	Outstanding at December 31, 2013	—		—

Derivative_Accounting_Tables

Derivative Accounting (Tables)	12 Months Ended
Derivative Accounting (Tables)	Dec. 31, 2013
Derivative Accounting	'
Outstanding gross notional amount of derivatives, which represents both purchases and sales (does not reflect net position)	'
	As of December 31, 2013, we had the following outstanding gross notional volume of derivatives, which represent both purchases and sales (does not reflect net position):

	Commodity	Quantity
	Power	5,765		GWh
	Gas	108		Bcfs (a)

	(a) “Bcf” is Billion Cubic Feet.

Gains and losses from derivative instruments in designated cash flow accounting hedges relationships	'
	The following table provides information about gains and losses from derivative instruments in designated cash flow accounting hedging relationships during the years ended December 31, 2013, 2012 and 2011 (dollars in thousands):

				Year Ended
		Financial Statement		December 31,
	Commodity Contracts	Location		2013			2012			2011

	Loss Recognized in OCI on Derivative Instruments (Effective Portion)	OCI — derivative instruments		$	(353	)	$	(37,663	)	$	(94,660	)
	Loss Reclassified from Accumulated OCI into Income (Effective Portion Realized) (a)	Fuel and purchased power (b)		(44,219		)	(99,007		)	(117,189		)
	Gain (Loss) Recognized in Income (Ineffective Portion and Amount Excluded from Effectiveness Testing)	Fuel and purchased power (b)		—			117			(211		)


	(a) During the years ended December 31, 2013, 2012, and 2011, we had zero, $1.8 million, and zero 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	'
	The following table provides information about gains and losses from derivative instruments not designated as accounting hedging instruments during the years ended December 31, 2013, 2012 and 2011 (dollars in thousands):

				Year Ended
		Financial Statement		December 31,
	Commodity Contracts	Location		2013			2012			2011

	Net Gain (Loss) Recognized in Income	Operating revenues (a)		$	289		$	103		$	(27	)

	Net Loss Recognized in Income	Fuel and purchased power (a)		(10,449		)	(2,747		)	(52,113		)
	Total			$	(10,160	)	$	(2,644	)	$	(52,140	)

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

Schedule of the entity's fair value of risk management activities reported on a gross basis and the impacts of offsetting	'


	As of December 31, 2013:	Gross			Amounts			Net			Other			Amount
	(dollars in thousands)	Recognized			Offset			Recognized			(c)			Reported on
		Derivatives			(b)			Derivatives						Balance Sheet
		(a)
	Current Assets	$	24,587		$	(7,425	)	$	17,162		$	7		$	17,169
	Investments and Other Assets	25,364			(1,549		)	23,815			—			23,815
	Total Assets	49,951			(8,974		)	40,977			7			40,984

	Current Liabilities	(50,540		)	26,166			(24,374		)	(7,518		)	(31,892		)
	Deferred Credits and Other	(72,123		)	1,808			(70,315		)	—			(70,315		)
	Total Liabilities	(122,663		)	27,974			(94,689		)	(7,518		)	(102,207		)
	Total	$	(72,712	)	$	19,000		$	(53,712	)	$	(7,511	)	$	(61,223	)

	(a) All of our gross recognized derivative instruments were subject to master netting arrangements.
	(b) Includes cash collateral provided to counterparties of $19,000.
	(c) Represents cash collateral and 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 $7,518, and cash margin provided to counterparties of $7.

	As of December 31, 2012:	Gross			Amounts			Net			Other			Amount
	(dollars in thousands)	Recognized			Offset			Recognized			(c)			Reported on
		Derivatives			(b)			Derivatives						Balance Sheet
		(a)
	Current Assets	$	42,495		$	(17,797	)	$	24,698		$	1,001		$	25,699
	Investments and Other Assets	41,563			(5,672		)	35,891			—			35,891
	Total Assets	84,058			(23,469		)	60,589			1,001			61,590

	Current Liabilities	(105,324		)	57,046			(48,278		)	(25,463		)	(73,741		)
	Deferred Credits and Other	(100,986		)	15,722			(85,264		)	—			(85,264		)
	Total Liabilities	(206,310		)	72,768			(133,542		)	(25,463		)	(159,005		)
	Total	$	(122,252	)	$	49,299		$	(72,953	)	$	(24,462	)	$	(97,415	)


	(a) All of our gross recognized derivative instruments were subject to master netting arrangements.
	(b) Includes cash collateral provided to counterparties of $49,299.
	(c) Represents cash collateral relating to non-derivative instruments or derivatives qualifying for scope exceptions. Includes cash collateral provided to counterparties of $1,001, and cash collateral received from counterparties of $25,463. This amount is not subject to offsetting.

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 December 31, 2013 (dollars in millions):

		December 31,
		2013
	Aggregate Fair Value of Derivative Instruments in a Net Liability Position	$	123
	Cash Collateral Posted	19
	Additional Cash Collateral in the Event Credit-Risk Related Contingent Features were Fully Triggered (a)	66



	(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_Expense1

Other Income and Other Expense (Tables)	12 Months Ended
Other Income and Other Expense (Tables)	Dec. 31, 2013
Other Income and Other Expense	'
Detail of other income and other expense	'
	The following table provides detail of other income and other expense for 2013, 2012 and 2011 (dollars in thousands):

		2013			2012			2011
	Other income:
	Interest income	$	1,629		$	1,239		$	1,850
	Investment gains — net	—			—			1,165
	Miscellaneous	75			367			96
	Total other income	$	1,704		$	1,606		$	3,111

	Other expense:
	Non-operating costs	$	(8,207	)	$	(7,777	)	$	(7,037	)
	Investment loss — net	(3,711		)	(2,453		)	—
	Miscellaneous	(4,106		)	(9,612		)	(3,414		)
	Total other expense	$	(16,024	)	$	(19,842	)	$	(10,451	)

Palo_Verde_Sale_Leaseback_Vari1

Palo Verde Sale Leaseback Variable Interest Entities (Tables)	12 Months Ended
	Dec. 31, 2013
Palo Verde Sale Leaseback Variable Interest Entities	'
Amounts relating to the VIEs included in Consolidated Balance Sheets	'
	Our Consolidated Balance Sheets at December 31, 2013 and December 31, 2012 include the following amounts relating to the VIEs (in millions):

		December 31,		December 31,
		2013		2012
	Palo Verde sale leaseback property plant and equipment, net of accumulated depreciation	$	125	$	129
	Current maturities of long-term debt	26		27
	Long-term debt excluding current maturities	13		39
	Equity-Noncontrolling interests	146		129

Nuclear_Decommissioning_Trusts1

Nuclear Decommissioning Trusts (Tables)	12 Months Ended
	Dec. 31, 2013
Nuclear Decommissioning Trusts	'
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 December 31, 2013 and December 31, 2012 (dollars in millions):

		Fair Value			Total			Total
					Unrealized			Unrealized
					Gains			Losses
	December 31, 2013
	Equity securities	$	272		$	129		$	—
	Fixed income securities	373			11			(6		)
	Net payables (a)	(3		)	—			—
	Total	$	642		$	140		$	(6	)

		Fair Value			Total			Total
					Unrealized			Unrealized
					Gains			Losses
	December 31, 2012
	Equity securities	$	204		$	67		$	—
	Fixed income securities	371			24			—
	Net payables (a)	(4		)	—			—
	Total	$	571		$	91		$	—

	(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 millions):

		Year Ended December 31,
		2013			2012			2011

	Realized gains	$	6		$	7		$	8
	Realized losses	(7		)	(4		)	(5		)
	Proceeds from the sale of securities (a)	446			418			498


	(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 December 31, 2013 is as follows (dollars in millions):

		Fair Value
	Less than one year	$	9
	1 year – 5 years	109
	5 years – 10 years	108
	Greater than 10 years	147
	Total	$	373

Changes_in_Accumulated_Other_C1

Changes in Accumulated Other Comprehensive Loss (Tables)	12 Months Ended
	Dec. 31, 2013
Changes in Accumulated Other Comprehensive Loss	'
Schedule of changes in accumulated other comprehensive loss including reclassification adjustments, by component	'
	The following table shows the changes in accumulated other comprehensive loss, including reclassification adjustments, net of tax, by component for the year ended December 31, 2013 (dollars in thousands):

		Year Ended December 31, 2013
		Derivative			Pension and			Total
		Instruments			Other
					Postretirement
					Benefits

	Beginning balance	$	(49,592	)	$	(64,416	)	$	(114,008	)
	OCI (loss) before reclassifications	(213		)	5,594			5,381
	Amounts reclassified from accumulated other comprehensive loss	26,747		(a)	3,827		(b)	30,574

	Net current period OCI	26,534			9,421			35,955
	Ending balance	$	(23,058	)	$	(54,995	)	$	(78,053	)

	(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 17.
	(b) These amounts primarily represent amortization of actuarial loss, and are included in the computation of net periodic pension cost. See Note 8.

Summary_of_Significant_Account3

Summary of Significant Accounting Policies (Details) (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Balance Sheets	'	'	'
Long-term debt less current maturities	$2,796,465	$3,199,088	'
Cash Flows from Operating Activities	'	'	'
Deferred income taxes	249,296	187,023	117,952
Deferred investment tax credit	52,542	41,579	58,240
Income tax receivable	-133,094	-4,043	3,983
Accrued taxes	6,059	12,736	8,085
As previously reported	'	'	'
Balance Sheets	'	'	'
Long-term debt less current maturities	'	3,160,219	'
Cash Flows from Operating Activities	'	'	'
Deferred income taxes	'	228,602	176,192
Accrued taxes and income tax receivable	'	8,693	12,068
As previously reported \| Palo Verde Sale Leaseback	'	'	'
Balance Sheets	'	'	'
Long-term debt less current maturities	'	38,869	'
Reclassifications to conform to current year presentation	'	'	'
Balance Sheets	'	'	'
Long-term debt less current maturities	'	38,869	'
Cash Flows from Operating Activities	'	'	'
Deferred income taxes	'	-41,579	-58,240
Deferred investment tax credit	'	41,579	58,240
Accrued taxes and income tax receivable	'	-8,693	-12,068
Income tax receivable	'	-4,043	3,983
Accrued taxes	'	12,736	8,085
Reclassifications to conform to current year presentation \| Palo Verde Sale Leaseback	'	'	'
Balance Sheets	'	'	'
Long-term debt less current maturities	'	($38,869)	'

Summary_of_Significant_Account4

Summary of Significant Accounting Policies (Details 2) (USD $)

12 Months Ended

36 Months Ended

12 Months Ended

36 Months Ended

12 Months Ended

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Dec. 31, 2008

Dec. 31, 1986

Dec. 31, 2013

ARIZONA PUBLIC SERVICE COMPANY

Minimum

Maximum

Fossil plant

Nuclear plant

Other generation

Transmission

Distribution

Other:

item

Approximate remaining average useful lives of utility property

Average useful life

'18 years

'26 years

'37 years

'34 years

'7 years

Extension period of operating licenses for each of the three Palo Verde units

'20 years

Number of VIE lessor trusts

Depreciation rates (as a percent)

3.00%

2.71%

2.98%

0.45%

12.08%

Allowance for Funds Used During Construction

Composite rate used to calculate AFUDC (as a percent)

8.56%

8.60%

10.25%

Nuclear Fuel

Charges for the permanent disposal of spent nuclear fuel (in dollars per kWh)

0.001

Cash paid during the year for:

Income taxes, net of refunds

$18,537,000

$2,543,000

$10,324,000

$7,524,000

$1,196,000

$25,975,000

Interest, net of amounts capitalized

184,010,000

200,923,000

217,789,000

180,757,000

196,038,000

210,995,000

Significant non-cash investing and financing activities:

Accrued capital expenditures

33,184,000

26,208,000

27,245,000

33,184,000

26,208,000

27,245,000

Dividends declared but not paid

62,528,000

59,789,000

62,500,000

59,800,000

Liabilities assumed relating to acquisition of SCE Four Corners' interest (see Note 3)

145,609,000

Intangible Assets

Amortization expense

53,000,000

50,000,000

47,000,000

Estimated amortization expense on existing intangible assets over the next five years

2014

47,000,000

2015

38,000,000

2016

29,000,000

2017

19,000,000

2018

$7,000,000

Weighted average remaining amortization period for intangible assets

'6 years

Investments

Ownership percentage for classification as cost method investments by El Dorado

20.00%

Regulatory_Matters_Details

Regulatory Matters (Details) (USD $)

12 Months Ended

0 Months Ended

1 Months Ended

0 Months Ended

1 Months Ended

3 Months Ended

12 Months Ended

0 Months Ended

12 Months Ended

0 Months Ended

12 Months Ended

1 Months Ended

12 Months Ended

0 Months Ended

1 Months Ended

12 Months Ended

1 Months Ended

0 Months Ended

1 Months Ended

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Dec. 03, 2013

Jan. 31, 2012

Jun. 30, 2011

Jan. 06, 2012

Jan. 31, 2012

Dec. 30, 2013

Dec. 31, 2009

Jun. 30, 2010

Dec. 30, 2009

Dec. 31, 2013

Oct. 30, 2013

Dec. 31, 2012

Dec. 31, 2013

Feb. 12, 2013

Dec. 31, 2013

Mar. 02, 2014

Dec. 31, 2013

Jun. 02, 2012

Jun. 30, 2012

Apr. 30, 2012

Jun. 30, 2011

Dec. 31, 2009

Jun. 02, 2011

Jul. 12, 2013

Feb. 28, 2013

Dec. 31, 2013

Dec. 31, 2012

Feb. 28, 2014

Jun. 01, 2013

Jun. 30, 2012

APS

Filing with the Arizona Corporation Commission

2008 General Retail Rate Case On-Going Impacts

Cost Recovery Mechanisms

ACC

APS

Power Supply Adjustor (PSA)

APS

RES implementation plan covering 2014-2018 timeframe

ACC

2013 DSMAC

Power Supply Adjustor (PSA)

Lost Fixed Cost Recovery Mechanism

ACC

FERC

Retail rate case filing

Residential customers rate case filing

2008 General retail rate case

Maximum

Subsequent event

RES

2013 DSMAC

2012 DSMAC

RES implementation plan covering 2014-2018 timeframe

Power Supply Adjustor (PSA)

Transmission Rates, Transmission Cost Adjustor and Other Transmission Matters

Maximum

item

Subsequent event

Regulatory Matters

Net retail rate increase

$95,500,000

Approximate percentage of increase in the average retail customer bill

6.60%

Approximate percentage of increase in the average retail customer bill under proposed Four Corners rate filing

2.00%

Settlement Agreement

Net change in base rates

Non-fuel base rate increase

116,300,000

Fuel-related base rate decrease

153,100,000

Current base fuel rate (in dollars per kWh)

0.03757

Approved base fuel rate (in dollars per 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%

Annual cost recovery due to modifications to the Environmental Improvement Surcharge

5,000,000

Elimination of the sharing provision of fuel and purchased power costs

Period to process the subsequent rate cases

'12 months

ACC staff sufficiency findings, general period of time

'30 days

2008 General Retail Rate Case on-going impacts

Number of other parties to the settlement agreement

Minimum amount of reduction of average annual operational expenses from 2010 through 2014

30,000,000

Authorization and requirements of equity infusions into APS beginning June 1, 2009 through December 31, 2014

700,000,000

Equity infusions into APS

253,000,000

Change in regulatory asset

Plan term

'5 years

Amount of proposed budget

68,900,000

87,600,000

143,000,000

Percentage of cumulative energy savings for prior year

3.00%

Percentage of annual energy savings to meet energy efficiency goal for 2011

2.75%

Period of energy savings goal

'2 years

Demand-side management adjustor charge (DSMAC)

72,000,000

Period beginning March 1, 2012, over which the costs will be recovered

'12 months

Costs already being recovered in general rates

10,000,000

Amortization of recovery of demand-side management adjustor charge included in costs already been recovered

5,000,000

Percentage of cumulative energy savings for current year

5.00%

Beginning balance

73,000,000

28,000,000

Deferred fuel and purchased power costs-current period

-21,678,000

-71,573,000

-69,166,000

-21,678,000

-71,573,000

-69,166,000

-21,000,000

-72,000,000

Amounts (charged) credited to customers

-31,190,000

116,716,000

155,157,000

-31,190,000

116,716,000

155,157,000

-31,000,000

117,000,000

Ending balance

21,000,000

73,000,000

Percentage of sale of distributed energy system's output at a market-based price for installing new rooftop solar system to all new residential customers

100.00%

Charge on future customers who install rooftop solar panels (in dollars per kWh)

0.7

Estimated monthly collection due to charge on future customers who install rooftop solar panels

4.9

PSA rate (in dollars per kWh)

0.001557

PSA rate for prior year (in dollars per kWh)

0.001329

Increase or decrease in PSA charge (in dollars per kWh)

0.000228

0.004

Forward component of increase in PSA (in dollars per kWh)

0.001277

Historical component of increase in PSA (in dollars per kWh)

0.00028

Increase in annual wholesale transmission rates

26,000,000

16,000,000

Fixed costs recoverable per residential power lost (in dollars per kWh)

0.031

Fixed costs recoverable per non-residential power lost (in dollars per kWh)

0.023

Amount of adjustment approved representing prorated sales losses

$5,100,000

$25,300,000

Regulatory_Matters_Details_2

Regulatory Matters (Details 2) (Four Corners, SCE, USD $)	Dec. 31, 2013	Dec. 30, 2013
In Millions, unless otherwise specified		APS
		MW
Acquisition	'	'
Total Entitlement	'	970
Ownership interest acquired	'	48.00%
Percent Owned	'	63.00%
Purchase price	'	$182
Plant-in-service	'	316
Acquisition adjustment	'	255
Decommissioning obligations	'	34
Mine reclamation obligations	'	93
Other various liabilities	'	18
Construction work in progress	'	11
Deferral balance related to the acquisition of SCE's interest in Units 4 and 5 and the closure of Four Corners Units 1-3	37	'
Capacity rights over the Arizona Transmission System assign to third-parties	'	1,555
Capacity rights related to marketing and trading group for transmission of the additional power received assign to third-parties	'	300
Net receipt due to negotiation of alternate arrangement	'	$40

Regulatory_Matters_Details_3

Regulatory Matters (Details 3) (USD $)	Dec. 31, 2013	Dec. 31, 2012
Detail of regulatory assets	'	'
Regulatory assets, current	$97,000,000	$144,000,000
Regulatory assets, non-current	711,712,000	1,099,900,000
Pension and other postretirement benefits	'	'
Detail of regulatory assets	'	'
Regulatory assets, non-current	314,000,000	780,000,000
Income taxes - AFUDC equity	'	'
Detail of regulatory assets	'	'
Regulatory assets, current	4,000,000	4,000,000
Regulatory assets, non-current	105,000,000	92,000,000
Deferred fuel and purchased power - mark-to-market	'	'
Detail of regulatory assets	'	'
Regulatory assets, current	5,000,000	19,000,000
Regulatory assets, non-current	29,000,000	21,000,000
Transmission vegetation management	'	'
Detail of regulatory assets	'	'
Regulatory assets, current	9,000,000	9,000,000
Regulatory assets, non-current	14,000,000	23,000,000
Coal reclamation	'	'
Detail of regulatory assets	'	'
Regulatory assets, current	8,000,000	8,000,000
Regulatory assets, non-current	18,000,000	24,000,000
Palo Verde VIE	'	'
Detail of regulatory assets	'	'
Regulatory assets, non-current	41,000,000	38,000,000
Deferred compensation	'	'
Detail of regulatory assets	'	'
Regulatory assets, non-current	34,000,000	34,000,000
Deferred fuel and purchased power	'	'
Detail of regulatory assets	'	'
Regulatory assets, current	21,000,000	73,000,000
Tax expense of Medicare subsidy	'	'
Detail of regulatory assets	'	'
Regulatory assets, current	2,000,000	2,000,000
Regulatory assets, non-current	15,000,000	17,000,000
Loss on reacquired debt	'	'
Detail of regulatory assets	'	'
Regulatory assets, current	1,000,000	2,000,000
Regulatory assets, non-current	17,000,000	18,000,000
Income taxes - investment tax credit basis adjustment	'	'
Detail of regulatory assets	'	'
Regulatory assets, current	1,000,000	1,000,000
Regulatory assets, non-current	39,000,000	26,000,000
Pension and other postretirement benefits deferral	'	'
Detail of regulatory assets	'	'
Regulatory assets, current	8,000,000	8,000,000
Regulatory assets, non-current	4,000,000	13,000,000
Four Corners cost deferral	'	'
Detail of regulatory assets	'	'
Regulatory assets, non-current	37,000,000	'
Lost fixed cost recovery	'	'
Detail of regulatory assets	'	'
Regulatory assets, current	25,000,000	7,000,000
Transmission cost adjustor	'	'
Detail of regulatory assets	'	'
Regulatory assets, current	8,000,000	10,000,000
Regulatory assets, non-current	2,000,000	'
Retired power plant costs	'	'
Detail of regulatory assets	'	'
Regulatory assets, current	3,000,000	'
Regulatory assets, non-current	18,000,000	'
Other	'	'
Detail of regulatory assets	'	'
Regulatory assets, current	2,000,000	1,000,000
Regulatory assets, non-current	$25,000,000	$14,000,000

Regulatory_Matters_Details_4

Regulatory Matters (Details 4) (USD $)	Dec. 31, 2013	Dec. 31, 2012
Detail of regulatory liabilities	'	'
Regulatory liabilities, current	$99,000,000	$88,000,000
Regulatory liabilities, non-current	801,297,000	759,201,000
Removal costs	'	'
Detail of regulatory liabilities	'	'
Regulatory liabilities, current	28,000,000	27,000,000
Regulatory liabilities, non-current	303,000,000	321,000,000
Asset retirement obligations	'	'
Detail of regulatory liabilities	'	'
Regulatory liabilities, non-current	266,000,000	256,000,000
Renewable energy standard	'	'
Detail of regulatory liabilities	'	'
Regulatory liabilities, current	33,000,000	43,000,000
Regulatory liabilities, non-current	15,000,000	'
Income taxes - change in rates	'	'
Detail of regulatory liabilities	'	'
Regulatory liabilities, non-current	74,000,000	66,000,000
Spent nuclear fuel	'	'
Detail of regulatory liabilities	'	'
Regulatory liabilities, current	6,000,000	10,000,000
Regulatory liabilities, non-current	36,000,000	36,000,000
Deferred gains on utility property	'	'
Detail of regulatory liabilities	'	'
Regulatory liabilities, current	2,000,000	2,000,000
Regulatory liabilities, non-current	10,000,000	12,000,000
Income taxes-deferred investment tax credit	'	'
Detail of regulatory liabilities	'	'
Regulatory liabilities, current	3,000,000	2,000,000
Regulatory liabilities, non-current	79,000,000	52,000,000
Demand side management	'	'
Detail of regulatory liabilities	'	'
Regulatory liabilities, current	27,000,000	4,000,000
Other	'	'
Detail of regulatory liabilities	'	'
Regulatory liabilities, non-current	$18,000,000	$16,000,000

Income_Taxes_Details

Income Taxes (Details) (USD $)

3 Months Ended

12 Months Ended

0 Months Ended

3 Months Ended

12 Months Ended

Sep. 30, 2013

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Dec. 31, 2013

Sep. 13, 2013

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Sep. 30, 2013

Sep. 30, 2009

Dec. 31, 2013

Maximum

Palo Verde VIE

ARIZONA PUBLIC SERVICE COMPANY

Maximum

Income Taxes

Long-term income tax receivables

$70,389,000

$70,784,000

$71,000,000

Decrease in uncertain tax positions

67,000,000

Income tax receivable that will be reclassified from long term to short-term

137,000,000

138,000,000

Anticipated refund reduction amount

-4,000,000

Decrease in long term deferred tax liability due to adoption of regulations

-84,000,000

Decrease in long term deferred tax liability due to rate changes

-75,000,000

-2,000,000

Period over which deferred income tax liability would have been repaid

'20 years

Income tax expense associates with the VIE's

Tabular reconciliation of the total amounts of unrecognized tax benefits, excluding interest and penalties, at the beginning and end of the year

Total unrecognized tax benefits at the beginning of the year

133,422,000

136,005,000

127,595,000

133,241,000

135,824,000

126,698,000

Additions for tax positions of the current year

3,516,000

5,167,000

10,915,000

3,516,000

5,167,000

10,915,000

Additions for tax positions of prior years

13,158,000

Reductions for tax positions of prior years for:

Changes in judgment

-108,099,000

-7,729,000

-1,555,000

-107,918,000

-7,729,000

-1,555,000

Settlements with taxing authorities

-124,000

Lapses of applicable statute of limitations

-21,000

-826,000

-21,000

-110,000,000

Total unrecognized tax benefits at the end of the year

41,997,000

133,422,000

136,005,000

41,997,000

133,241,000

135,824,000

Unrecognized tax benefits if recognized, would decrease effective tax rate

10,000,000

8,000,000

10,000,000

8,000,000

Pre-tax interest expense (benefit) related to unrecognized tax benefits

4,000,000

3,000,000

4,000,000

3,000,000

Accrued liabilities for interest related to unrecognized tax benefits

13,000,000

9,000,000

1,000,000

13,000,000

9,000,000

1,000,000

Interest income to be received on the overpayment of income taxes for certain adjustments that we have filed, or will file, with the IRS

$5,000,000

Income_Taxes_Details_2

Income Taxes (Details 2) (USD $)	3 Months Ended								12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2013	Sep. 30, 2013	Jun. 30, 2013	Mar. 31, 2013	Dec. 31, 2012	Sep. 30, 2012	Jun. 30, 2012	Mar. 31, 2012	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Current:	'	'	'	'	'	'	'	'	'	'	'
Federal	'	'	'	'	'	'	'	'	($81,784)	($3,493)	($310)
State	'	'	'	'	'	'	'	'	10,537	8,395	15,140
Total current	'	'	'	'	'	'	'	'	-71,247	4,902	14,830
Deferred:	'	'	'	'	'	'	'	'	'	'	'
Federal	'	'	'	'	'	'	'	'	279,973	200,322	159,566
State	'	'	'	'	'	'	'	'	21,865	28,280	16,626
Total deferred	'	'	'	'	'	'	'	'	301,838	228,602	176,192
Total income tax expense	'	'	'	'	'	'	'	'	230,591	233,504	191,022
Less: income tax expense (benefit) on discontinued operations	'	'	'	'	'	'	'	'	'	-3,813	7,418
Income tax expense - continuing operations	$9,167	$131,912	$77,043	$12,469	$18,157	$147,116	$76,689	($4,645)	$230,591	$237,317	$183,604

Income_Taxes_Details_3

Income Taxes (Details 3) (USD $)

3 Months Ended

12 Months Ended

0 Months Ended

3 Months Ended

12 Months Ended

Dec. 31, 2013

Sep. 30, 2013

Jun. 30, 2013

Mar. 31, 2013

Dec. 31, 2012

Sep. 30, 2012

Jun. 30, 2012

Mar. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Sep. 13, 2013

Apr. 04, 2013

Feb. 17, 2011

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

ARIZONA PUBLIC SERVICE COMPANY

Comparison of pretax income from continuing operations at the federal income tax rate to income tax expense - continuing operations

Federal income tax rate (as a percent)

35.00%

Federal income tax expense at 35% statutory rate

$234,695,000

$229,709,000

$188,733,000

$246,384,000

$235,027,000

$194,710,000

State income tax net of federal income tax benefit

21,387,000

23,819,000

19,594,000

23,970,000

25,379,000

21,139,000

Credits and favorable adjustments related to prior years resolved in current year

-3,356,000

-3,231,000

Medicare Subsidy Part-D

823,000

483,000

823,000

483,000

823,000

Allowance for equity funds used during construction

-6,997,000

-6,158,000

-6,881,000

-6,997,000

-6,158,000

-6,880,000

Palo Verde VIE noncontrolling interest

-11,862,000

-11,065,000

-9,636,000

-11,862,000

-11,065,000

-9,633,000

Other

-4,099,000

529,000

-9,029,000

-3,992,000

730,000

-7,617,000

Income tax expense - continuing operations

9,167,000

131,912,000

77,043,000

12,469,000

18,157,000

147,116,000

76,689,000

-4,645,000

230,591,000

237,317,000

183,604,000

245,095,000

244,396,000

192,542,000

Net deferred income tax liability recognized on the Consolidated Balance Sheets

Current asset (liability)

91,152,000

152,191,000

91,152,000

152,191,000

-2,033,000

74,420,000

Long-term liability

-2,351,882,000

-2,151,371,000

-2,351,882,000

-2,151,371,000

-2,347,724,000

-2,133,976,000

Deferred income taxes - net

-2,260,730,000

-1,999,180,000

-2,260,730,000

-1,999,180,000

-2,349,757,000

-2,059,556,000

Income Taxes, additional disclosures

Phase-in period of corporate income tax rate reductions beginning in 2014

'5 years

'4 years

Decrease in long term deferred tax liability due to adoption of regulations

-84,000,000

Decrease in long term deferred tax liability due to rate changes

($75,000,000)

($2,000,000)

Income_Taxes_Details_4

Income Taxes (Details 4) (USD $)	Dec. 31, 2013	Dec. 31, 2012
DEFERRED TAX ASSETS	'	'
Risk management activities	$44,920,000	$72,243,000
Regulatory liabilities:	'	'
Asset retirement obligation and removal costs	235,959,000	238,669,000
Unamortized investment tax credits	82,116,000	53,837,000
Other	42,609,000	33,764,000
Pension and other postretirement liabilities	198,642,000	408,764,000
Renewable energy incentives	65,434,000	66,941,000
Credit and loss carryforwards	133,070,000	139,022,000
Other	148,492,000	68,844,000
Total deferred tax assets	951,242,000	1,082,084,000
DEFERRED TAX LIABILITIES	'	'
Plant-related	-2,903,730,000	-2,584,166,000
Risk management activities	-16,191,000	-23,940,000
Regulatory assets:	'	'
Allowance for equity funds used during construction	-43,058,000	-37,899,000
Deferred fuel and purchased power	-8,282,000	-28,858,000
Deferred fuel and purchased power - mark-to-market	-13,343,000	-15,796,000
Pension and other postretirement benefits	-129,250,000	-316,757,000
Other	-93,202,000	-68,170,000
Other	-4,916,000	-5,678,000
Total deferred tax liabilities	-3,211,972,000	-3,081,264,000
Deferred income taxes - net	-2,260,730,000	-1,999,180,000
Amount of federal general business credits carryforwards which begin to expire in 2031	131,000,000	'
Amount of federal and state loss carryforwards which will begin to expire in 2018	$2,000,000	'

Lines_of_Credit_and_ShortTerm_2

Lines of Credit and Short-Term Borrowings (Details) (USD $)	12 Months Ended
Lines of Credit and Short-Term Borrowings (Details) (USD $)	Dec. 31, 2013	Dec. 31, 2012
Lines of Credit and Short-Term Borrowings	'	'
Amount Committed	$1,200,000,000	$1,200,000,000
Unused Amount	1,047,000,000	1,108,000,000
Long term debt	'	'
Lines of Credit and Short-Term Borrowings	'	'
Amount Committed	847,000,000	908,000,000
Number of credit facilities	2	2
Pinnacle West	'	'
Lines of Credit and Short-Term Borrowings	'	'
Outstanding amount of debt	3,340,000,000	'
Pinnacle West \| Long term debt	'	'
Lines of Credit and Short-Term Borrowings	'	'
Outstanding amount of debt	0	0
Pinnacle West \| Revolving credit facility maturing in 2016	'	'
Lines of Credit and Short-Term Borrowings	'	'
Amount Committed	200,000,000	200,000,000
Unused Amount	200,000,000	200,000,000
Commitment Fees (as a percent)	0.18%	0.23%
Maximum borrowing capacity on credit facility upon satisfaction of certain conditions and consent of lenders	300,000,000	300,000,000
Pinnacle West \| Commercial Paper	'	'
Lines of Credit and Short-Term Borrowings	'	'
Amount Committed	200,000,000	200,000,000
Outstanding amount of debt	0	0
Pinnacle West \| Letters of credit	'	'
Lines of Credit and Short-Term Borrowings	'	'
Outstanding amount of debt	0	0
ARIZONA PUBLIC SERVICE COMPANY	'	'
Lines of Credit and Short-Term Borrowings	'	'
Amount Committed	1,000,000,000	'
Outstanding amount of debt	3,215,000,000	'
Maximum borrowing capacity on credit facility upon satisfaction of certain conditions and consent of lenders	700,000,000	700,000,000
ARIZONA PUBLIC SERVICE COMPANY \| ACC	'	'
Debt Provisions	'	'
Percentage of APS's capitalization used in calculation of short-term debt authorization	7.00%	'
Required amount to be used in purchases of natural gas and power which is used in calculation of short-term debt authorization	500,000,000	'
Long-term debt authorization before increase	4,200,000,000	'
Long-term debt authorization	5,100,000,000	'
ARIZONA PUBLIC SERVICE COMPANY \| Long term debt	'	'
Lines of Credit and Short-Term Borrowings	'	'
Maximum commercial paper support available under credit facility	250,000,000	250,000,000
ARIZONA PUBLIC SERVICE COMPANY \| Revolving credit facility maturing in 2016	'	'
Lines of Credit and Short-Term Borrowings	'	'
Amount Committed	500,000,000	500,000,000
Unused Amount	347,000,000	408,000,000
Commitment Fees (as a percent)	0.13%	0.18%
ARIZONA PUBLIC SERVICE COMPANY \| Revolving credit facility maturing in 2015	'	'
Lines of Credit and Short-Term Borrowings	'	'
Amount Committed	'	500,000,000
Unused Amount	'	500,000,000
Commitment Fees (as a percent)	'	0.20%
ARIZONA PUBLIC SERVICE COMPANY \| Revolving credit facility maturing in 2018	'	'
Lines of Credit and Short-Term Borrowings	'	'
Amount Committed	500,000,000	'
Unused Amount	500,000,000	'
Commitment Fees (as a percent)	0.13%	'
ARIZONA PUBLIC SERVICE COMPANY \| Commercial Paper	'	'
Lines of Credit and Short-Term Borrowings	'	'
Outstanding amount of debt	153,000,000	92,000,000
ARIZONA PUBLIC SERVICE COMPANY \| Letters of credit	'	'
Lines of Credit and Short-Term Borrowings	'	'
Outstanding amount of debt	$0	$0

LongTerm_Debt_and_Liquidity_Ma2

Long-Term Debt and Liquidity Matters (Details) (USD $)

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Mar. 22, 2013

1-May-13

Jul. 12, 2013

Oct. 11, 2013

Maximum

Pinnacle West

APS

Pollution Control Bonds - Variable

Pollution Control Bonds - Fixed

Total Pollution Control Bonds

Senior unsecured notes

Palo Verde sale leaseback lessor notes

Term loan facility

4.50% unsecured senior notes that mature on April 1, 2042

Pollution Control Revenue Refunding Bonds, 2009 Series C

Pollution Control Revenue Refunding Bonds, 1994 Series A

Pollution Control Revenue Refunding Bonds, 1994 Series C

ACC

APS

Pinnacle West

APS

Minimum

Maximum

Minimum

Subsequent event

Long-Term Debt and Liquidity Matters

Long-term debt redemption

$3,340,000,000

$3,215,000,000

$75,580,000

$426,125,000

$490,275,000

$501,705,000

$565,855,000

$2,675,000,000

$2,575,000,000

$32,000,000

$33,000,000

$32,000,000

Palo Verde sale leaseback lessor notes long-term debt excluding current maturities

13,420,000

38,869,000

13,420,000

38,869,000

65,547,000

Unamortized discount

-8,732,000

-9,486,000

Unamortized premium

5,047,000

Long-term debt

3,337,000,000

3,322,000,000

125,000,000

Long-term debt

125,000,000

3,211,889,000

3,196,916,000

Less current maturities

-540,424,000

-122,828,000

-215,000,000

-300,000,000

Total long-term debt less current maturities

2,671,465,000

3,074,088,000

Interest rate (as a percent)

8.00%

4.50%

1.75%

Long-term debt less current maturities

2,796,465,000

3,199,088,000

125,000,000

Interest Rates, low end of range (as a percent)

1.25%

4.50%

Interest Rates, high end of range (as a percent)

6.00%

8.75%

Weighted-average interest rate (as a percent)

0.06%

0.15%

0.03%

0.13%

1.27%

1.31%

Estimated fair value of long-term debt, including current maturities

Carrying Amount

125,000,000

3,211,889,000

3,196,916,000

Long-term debt

3,337,000,000

3,322,000,000

125,000,000

Fair Value

3,579,000,000

3,875,000,000

125,000,000

3,454,000,000

3,750,000,000

Notes issued

100,000,000

Debt Provisions

Actual ratio of consolidated debt to total consolidated capitalization required to be maintained as per the debt covenant (as a percent)

47.00%

45.00%

Ratio of consolidated debt to consolidated capitalization (as a percent)

65.00%

Required common equity ratio ordered by ACC (as a percent)

40.00%

Total shareholder equity

4,194,470,000

3,972,806,000

4,194,470,000

3,972,806,000

4,308,884,000

4,093,000,000

4,300,000,000

Total capitalization

7,500,000,000

Dividend restrictions, shareholder equity required

$3,000,000,000

LongTerm_Debt_and_Liquidity_Ma3

Long-Term Debt and Liquidity Matters (Details 2) (USD $)	Dec. 31, 2013
ARIZONA PUBLIC SERVICE COMPANY	'
Principal payments due on long-term debt	'
2014	$540,000,000
2015	345,000,000
2016	358,000,000
2018	32,000,000
Thereafter	1,940,000,000
Total	3,215,000,000
Pinnacle West	'
Principal payments due on long-term debt	'
2014	540,000,000
2015	470,000,000
2016	358,000,000
2018	32,000,000
Thereafter	1,940,000,000
Total	$3,340,000,000

LongTerm_Debt_and_Liquidity_Ma4

Long-Term Debt and Liquidity Matters (Details 3) (ARIZONA PUBLIC SERVICE COMPANY, Subsequent event, USD $)	0 Months Ended
In Millions, unless otherwise specified	Jan. 10, 2014
	item
SCE \| Four Corners Units 4 and 5	'
Long-Term Debt and Liquidity Matters	'
Ownership interest acquired	48.00%
Number of tax-exempt indebtedness series re-acquired	2
4.70% unsecured senior notes that mature on January 15, 2044	'
Long-Term Debt and Liquidity Matters	'
Interest rate (as a percent)	4.70%
Notes issued	250

Common_Stock_and_Treasury_Stoc2

Common Stock and Treasury Stock (Details) (USD $)	12 Months Ended
In Thousands, except Share data, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Changes in equity	'	'	'
Balance	$4,340,460	$4,102,289	$3,930,586
Balance at the end of the period (in shares)	110,280,703	109,837,957	'
Pinnacle West	'	'	'
Changes in equity	'	'	'
Balance	4,340,460	4,102,289	'
Serial preferred stock authorized	10,000,000	'	'
Par value (in dollars per share)	$0	'	'
Preferred stock outstanding	0	'	'
ARIZONA PUBLIC SERVICE COMPANY	'	'	'
Changes in equity	'	'	'
Balance	4,454,874	4,222,483	4,051,406
Serial preferred stock authorized	15,535,000	'	'
Preferred stock outstanding	0	'	'
Par value of type 1 preferred stock authorized (in dollars per share)	$25	'	'
Par value of type 2 preferred stock authorized (in dollars per share)	$50	'	'
Par value of type 3 preferred stock authorized (in dollars per share)	$100	'	'
Common Stock	'	'	'
Changes in equity	'	'	'
Balance	2,466,923	2,444,247	2,421,372
Balance at the beginning of the period (in shares)	109,837,957	109,356,974	108,820,067
Common stock issuance	24,635	22,676	22,875
Common stock issuance (in shares)	442,746	480,983	536,907
Balance	2,491,558	2,466,923	2,444,247
Balance at the end of the period (in shares)	110,280,703	109,837,957	109,356,974
Common Stock \| ARIZONA PUBLIC SERVICE COMPANY	'	'	'
Changes in equity	'	'	'
Balance	178,162	178,162	178,162
Treasury Stock	'	'	'
Changes in equity	'	'	'
Balance	-4,211	-4,717	-2,239
Balance at the beginning of the period (in shares)	-95,192	-111,161	-50,410
Purchase of treasury stock	-9,727	-4,607	-3,720
Purchase of treasury stock (in shares)	-174,290	-89,629	-88,440
Reissuance of treasury stock used for stock compensation	9,630	5,113	1,242
Reissuance of treasury stock for stock compensation (in shares)	170,538	105,598	27,689
Balance	($4,308)	($4,211)	($4,717)
Balance at the end of the period (in shares)	-98,944	-95,192	-111,161

Retirement_Plans_and_Other_Ben2

Retirement Plans and Other Benefits (Details) (USD $)	1 Months Ended	12 Months Ended
Retirement Plans and Other Benefits (Details) (USD $)	Jul. 31, 2012	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Retirement Plans and Other Benefits	'	'	'	'
Amount of pension and other postretirement benefit costs deferred	'	'	$14,000,000	$11,000,000
Regulatory asset amortization period	'3 years	'	'	'
Amortization of regulatory assets	'	8,000,000	4,000,000	'
Amounts recognized on the Consolidated Balance Sheets	'	'	'	'
Noncurrent liability	'	-513,628,000	-1,058,755,000	'
Pension Benefits	'	'	'	'
Net periodic benefit costs and the portion of these costs charged to expense	'	'	'	'
Service cost - benefits earned during the period	'	64,195,000	63,502,000	57,605,000
Interest cost on benefit obligation	'	112,392,000	119,586,000	124,727,000
Expected return on plan assets	'	-146,333,000	-140,979,000	-133,678,000
Amortization of prior service cost (credit)	'	1,097,000	1,143,000	1,400,000
Amortization of net actuarial loss	'	39,852,000	44,250,000	25,956,000
Net periodic benefit cost	'	71,203,000	87,502,000	76,010,000
Portion of cost charged to expense	'	38,968,000	36,333,000	29,312,000
Change in Benefit Obligation	'	'	'	'
Benefit obligation at the beginning of the period	'	2,850,846,000	2,699,126,000	'
Service cost	'	64,195,000	63,502,000	57,605,000
Interest cost	'	112,392,000	119,586,000	124,727,000
Benefit payments	'	-125,269,000	-113,632,000	'
Actuarial (gain) loss	'	-255,634,000	82,264,000	'
Benefit obligation at the end of the period	'	2,646,530,000	2,850,846,000	2,699,126,000
Change in Plan Assets	'	'	'	'
Balance at the beginning of the period	'	2,079,181,000	1,850,550,000	'
Actual return on plan assets	'	150,546,000	259,363,000	'
Employer contributions	'	140,500,000	65,000,000	0
Benefit payments	'	-106,106,000	-95,732,000	'
Balance at the end of the period	'	2,264,121,000	2,079,181,000	1,850,550,000
Funded Status at the end of the period	'	-382,409,000	-771,665,000	'
Projected benefit obligation and the accumulated benefit obligation for pension plans with an accumulated obligation in excess of plan assets	'	'	'	'
Projected benefit obligation	'	2,646,530,000	2,850,846,000	'
Accumulated benefit obligation	'	2,469,889,000	2,646,306,000	'
Fair value of plan assets	'	2,264,121,000	2,079,181,000	'
Amounts recognized on the Consolidated Balance Sheets	'	'	'	'
Current liability	'	-10,860,000	-19,107,000	'
Noncurrent liability	'	-371,549,000	-752,558,000	'
Net amount recognized	'	-382,409,000	-771,665,000	'
Other Benefits	'	'	'	'
Net periodic benefit costs and the portion of these costs charged to expense	'	'	'	'
Service cost - benefits earned during the period	'	23,597,000	27,163,000	21,856,000
Interest cost on benefit obligation	'	41,536,000	46,467,000	46,807,000
Expected return on plan assets	'	-45,717,000	-45,793,000	-41,536,000
Amortization of transition obligation	'	'	452,000	452,000
Amortization of prior service cost (credit)	'	-179,000	-179,000	-179,000
Amortization of net actuarial loss	'	11,310,000	20,233,000	15,015,000
Net periodic benefit cost	'	30,547,000	48,343,000	42,415,000
Portion of cost charged to expense	'	18,469,000	19,321,000	15,208,000
Change in Benefit Obligation	'	'	'	'
Benefit obligation at the beginning of the period	'	990,418,000	1,047,094,000	'
Service cost	'	23,597,000	27,163,000	21,856,000
Interest cost	'	41,536,000	46,467,000	46,807,000
Benefit payments	'	-26,675,000	-26,279,000	'
Actuarial (gain) loss	'	-138,458,000	-104,027,000	'
Benefit obligation at the end of the period	'	890,418,000	990,418,000	1,047,094,000
Change in Plan Assets	'	'	'	'
Balance at the beginning of the period	'	684,221,000	608,663,000	'
Actual return on plan assets	'	76,995,000	83,567,000	'
Employer contributions	'	14,438,000	22,707,000	19,000,000
Benefit payments	'	-27,315,000	-30,716,000	'
Balance at the end of the period	'	748,339,000	684,221,000	608,663,000
Funded Status at the end of the period	'	-142,079,000	-306,197,000	'
Amounts recognized on the Consolidated Balance Sheets	'	'	'	'
Noncurrent liability	'	-142,079,000	-306,197,000	'
Net amount recognized	'	($142,079,000)	($306,197,000)	'

Retirement_Plans_and_Other_Ben3

Retirement Plans and Other Benefits (Details 2) (USD $)	12 Months Ended
Retirement Plans and Other Benefits (Details 2) (USD $)	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Details related to accumulated other comprehensive loss	'	'	'
Accumulated other comprehensive loss	$54,995,000	$64,416,000	'
Weighted-average assumptions used to determine benefit obligations	'	'	'
Rate of compensation increase (as a percent)	4.00%	4.00%	'
Initial healthcare cost trend rate (as a percent)	7.50%	7.50%	'
Ultimate healthcare cost trend rate (as a percent)	5.00%	5.00%	5.00%
Number of years to ultimate trend rate	'4 years	'4 years	'4 years
Weighted-average assumptions used to determine net periodic benefit costs	'	'	'
Rate of compensation increase (as a percent)	4.00%	4.00%	4.00%
Expected long-term return on plan assets	7.00%	7.75%	7.75%
Initial healthcare cost trend rate (as a percent)	7.50%	7.50%	8.00%
Ultimate healthcare cost trend rate (as a percent)	5.00%	5.00%	5.00%
Number of years to ultimate trend rate	'4 years	'4 years	'4 years
Pension Benefits	'	'	'
Details related to accumulated other comprehensive loss	'	'	'
Net actuarial loss	344,540,000	644,239,000	'
Prior service cost (credit)	2,072,000	3,169,000	'
APS's portion recorded as a regulatory asset	-265,107,000	-550,471,000	'
Income tax benefit	-32,204,000	-38,303,000	'
Accumulated other comprehensive loss	49,301,000	58,634,000	'
Estimated amounts that will be amortized from accumulated other comprehensive loss and regulatory assets into net periodic benefit cost in 2014	'	'	'
Net actuarial loss	8,363,000	'	'
Prior service cost (credit)	874,000	'	'
Total amounts estimated to be amortized from accumulated other comprehensive loss and regulatory assets in 2014	9,237,000	'	'
Weighted-average assumptions used to determine benefit obligations	'	'	'
Discount rate (as a percent)	4.88%	4.01%	'
Weighted-average assumptions used to determine net periodic benefit costs	'	'	'
Discount rate (as a percent)	4.01%	4.42%	5.31%
Expected long-term return on plan assets for next fiscal year (as a percent)	6.90%	'	'
Other Benefits	'	'	'
Details related to accumulated other comprehensive loss	'	'	'
Net actuarial loss	57,816,000	238,862,000	'
Prior service cost (credit)	-296,000	-475,000	'
APS's portion recorded as a regulatory asset	-49,298,000	-230,020,000	'
Income tax benefit	-2,528,000	-2,585,000	'
Accumulated other comprehensive loss	5,694,000	5,782,000	'
Estimated amounts that will be amortized from accumulated other comprehensive loss and regulatory assets into net periodic benefit cost in 2014	'	'	'
Prior service cost (credit)	-179,000	'	'
Total amounts estimated to be amortized from accumulated other comprehensive loss and regulatory assets in 2014	-179,000	'	'
Weighted-average assumptions used to determine benefit obligations	'	'	'
Discount rate (as a percent)	5.10%	4.20%	'
Weighted-average assumptions used to determine net periodic benefit costs	'	'	'
Discount rate (as a percent)	4.20%	4.59%	5.49%
Expected long-term return on plan assets for next fiscal year (as a percent)	7.10%	'	'
Effects of one percentage point change in the assumed initial and ultimate health care cost trend rates	'	'	'
Effect of 1% increase on other postretirement benefits expense, after consideration of amounts capitalized or billed to electric plant participants	13,000,000	'	'
Effect of 1% decrease on other postretirement benefits expense, after consideration of amounts capitalized or billed to electric plant participants	-10,000,000	'	'
Effect of 1% increase on service and interest cost components of net periodic other postretirement benefit costs	14,000,000	'	'
Effect of 1% decrease on service and interest cost components of net periodic other postretirement benefit costs	-11,000,000	'	'
Effect of 1% increase on the accumulated other postretirement benefit obligation	149,000,000	'	'
Effect of 1% decrease on the accumulated other postretirement benefit obligation	($120,000,000)	'	'

Retirement_Plans_and_Other_Ben4

Retirement Plans and Other Benefits (Details 3) (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Pension Benefits	'	'	'
Fair value of Pinnacle West's pension plan and other postretirement benefit plan assets, by asset category	'	'	'
Fair value of plan assets	$2,264,121	$2,079,181	$1,850,550
Pension Benefits \| Pinnacle West	'	'	'
Fair value of Pinnacle West's pension plan and other postretirement benefit plan assets, by asset category	'	'	'
Fair value of plan assets	2,264,121	2,079,181	'
Pension Benefits \| Quoted Prices in Active Markets for Identical Assets (Level 1) \| Pinnacle West	'	'	'
Fair value of Pinnacle West's pension plan and other postretirement benefit plan assets, by asset category	'	'	'
Fair value of plan assets	490,559	807,879	'
Pension Benefits \| Significant Other Observable Inputs (Level 2) \| Pinnacle West	'	'	'
Fair value of Pinnacle West's pension plan and other postretirement benefit plan assets, by asset category	'	'	'
Fair value of plan assets	1,764,652	1,268,946	'
Pension Benefits \| Significant Unobservable Inputs (Level 3) \| Pinnacle West	'	'	'
Fair value of Pinnacle West's pension plan and other postretirement benefit plan assets, by asset category	'	'	'
Fair value of plan assets	8,660	2,419	'
Pension Benefits \| Counterparty Netting and Other \| Pinnacle West	'	'	'
Fair value of Pinnacle West's pension plan and other postretirement benefit plan assets, by asset category	'	'	'
Fair value of plan assets	250	-63	'
Pension Benefits \| Fixed income securities.	'	'	'
Retirement Plans and Other Benefits	'	'	'
Actual asset allocation (as a percent)	55.00%	'	'
Target asset allocation	'	'	'
Target allocation (as a percent)	58.00%	'	'
Target allocation, minimum (as a percent)	55.00%	'	'
Target allocation, maximum (as a percent)	61.00%	'	'
Pension Benefits \| Return-generating assets	'	'	'
Retirement Plans and Other Benefits	'	'	'
Actual asset allocation (as a percent)	45.00%	'	'
Target asset allocation	'	'	'
Target allocation (as a percent)	42.00%	'	'
Target allocation, minimum (as a percent)	45.00%	'	'
Target allocation, maximum (as a percent)	39.00%	'	'
Pension Benefits \| Cash and cash equivalent funds \| Pinnacle West	'	'	'
Fair value of Pinnacle West's pension plan and other postretirement benefit plan assets, by asset category	'	'	'
Fair value of plan assets	504	579	'
Pension Benefits \| Cash and cash equivalent funds \| Quoted Prices in Active Markets for Identical Assets (Level 1) \| Pinnacle West	'	'	'
Fair value of Pinnacle West's pension plan and other postretirement benefit plan assets, by asset category	'	'	'
Fair value of plan assets	504	579	'
Pension Benefits \| Corporate debt \| Pinnacle West	'	'	'
Fair value of Pinnacle West's pension plan and other postretirement benefit plan assets, by asset category	'	'	'
Fair value of plan assets	898,621	607,749	'
Pension Benefits \| Corporate debt \| Significant Other Observable Inputs (Level 2) \| Pinnacle West	'	'	'
Fair value of Pinnacle West's pension plan and other postretirement benefit plan assets, by asset category	'	'	'
Fair value of plan assets	898,621	607,749	'
Pension Benefits \| U.S. Treasury \| Pinnacle West	'	'	'
Fair value of Pinnacle West's pension plan and other postretirement benefit plan assets, by asset category	'	'	'
Fair value of plan assets	231,590	232,161	'
Pension Benefits \| U.S. Treasury \| Quoted Prices in Active Markets for Identical Assets (Level 1) \| Pinnacle West	'	'	'
Fair value of Pinnacle West's pension plan and other postretirement benefit plan assets, by asset category	'	'	'
Fair value of plan assets	231,590	232,161	'
Pension Benefits \| Other \| Pinnacle West	'	'	'
Fair value of Pinnacle West's pension plan and other postretirement benefit plan assets, by asset category	'	'	'
Fair value of plan assets	84,011	67,992	'
Pension Benefits \| Other \| Significant Other Observable Inputs (Level 2) \| Pinnacle West	'	'	'
Fair value of Pinnacle West's pension plan and other postretirement benefit plan assets, by asset category	'	'	'
Fair value of plan assets	84,011	67,992	'
Pension Benefits \| Developed equities	'	'	'
Target asset allocation	'	'	'
Target allocation (as a percent)	22.00%	'	'
Pension Benefits \| Emerging equities	'	'	'
Target asset allocation	'	'	'
Target allocation (as a percent)	6.00%	'	'
Pension Benefits \| Alternative investments	'	'	'
Target asset allocation	'	'	'
Target allocation (as a percent)	14.00%	'	'
Pension Benefits \| U.S. Companies, Equities \| Pinnacle West	'	'	'
Fair value of Pinnacle West's pension plan and other postretirement benefit plan assets, by asset category	'	'	'
Fair value of plan assets	239,036	531,291	'
Pension Benefits \| U.S. Companies, Equities \| Quoted Prices in Active Markets for Identical Assets (Level 1) \| Pinnacle West	'	'	'
Fair value of Pinnacle West's pension plan and other postretirement benefit plan assets, by asset category	'	'	'
Fair value of plan assets	239,036	531,291	'
Pension Benefits \| International Companies, Equities \| Pinnacle West	'	'	'
Fair value of Pinnacle West's pension plan and other postretirement benefit plan assets, by asset category	'	'	'
Fair value of plan assets	19,429	43,848	'
Pension Benefits \| International Companies, Equities \| Quoted Prices in Active Markets for Identical Assets (Level 1) \| Pinnacle West	'	'	'
Fair value of Pinnacle West's pension plan and other postretirement benefit plan assets, by asset category	'	'	'
Fair value of plan assets	19,429	43,848	'
Pension Benefits \| U.S. Equities \| Pinnacle West	'	'	'
Fair value of Pinnacle West's pension plan and other postretirement benefit plan assets, by asset category	'	'	'
Fair value of plan assets	116,150	176,694	'
Pension Benefits \| U.S. Equities \| Significant Other Observable Inputs (Level 2) \| Pinnacle West	'	'	'
Fair value of Pinnacle West's pension plan and other postretirement benefit plan assets, by asset category	'	'	'
Fair value of plan assets	116,150	176,694	'
Pension Benefits \| International Equities \| Pinnacle West	'	'	'
Fair value of Pinnacle West's pension plan and other postretirement benefit plan assets, by asset category	'	'	'
Fair value of plan assets	367,551	271,735	'
Pension Benefits \| International Equities \| Significant Other Observable Inputs (Level 2) \| Pinnacle West	'	'	'
Fair value of Pinnacle West's pension plan and other postretirement benefit plan assets, by asset category	'	'	'
Fair value of plan assets	367,551	271,735	'
Pension Benefits \| FIXED INCOME \| Pinnacle West	'	'	'
Fair value of Pinnacle West's pension plan and other postretirement benefit plan assets, by asset category	'	'	'
Fair value of plan assets	137,520	'	'
Pension Benefits \| FIXED INCOME \| Significant Other Observable Inputs (Level 2) \| Pinnacle West	'	'	'
Fair value of Pinnacle West's pension plan and other postretirement benefit plan assets, by asset category	'	'	'
Fair value of plan assets	137,520	'	'
Pension Benefits \| Real estate \| Pinnacle West	'	'	'
Fair value of Pinnacle West's pension plan and other postretirement benefit plan assets, by asset category	'	'	'
Fair value of plan assets	119,739	117,854	'
Pension Benefits \| Real estate \| Significant Other Observable Inputs (Level 2) \| Pinnacle West	'	'	'
Fair value of Pinnacle West's pension plan and other postretirement benefit plan assets, by asset category	'	'	'
Fair value of plan assets	119,739	117,854	'
Pension Benefits \| Short-term investments and other \| Pinnacle West	'	'	'
Fair value of Pinnacle West's pension plan and other postretirement benefit plan assets, by asset category	'	'	'
Fair value of plan assets	49,970	29,278	'
Pension Benefits \| Short-term investments and other \| Significant Other Observable Inputs (Level 2) \| Pinnacle West	'	'	'
Fair value of Pinnacle West's pension plan and other postretirement benefit plan assets, by asset category	'	'	'
Fair value of plan assets	41,060	26,922	'
Pension Benefits \| Short-term investments and other \| Significant Unobservable Inputs (Level 3)	'	'	'
Fair value of Pinnacle West's pension plan and other postretirement benefit plan assets, by asset category	'	'	'
Fair value of plan assets	8,660	2,419	'
Pension Benefits \| Short-term investments and other \| Significant Unobservable Inputs (Level 3) \| Pinnacle West	'	'	'
Fair value of Pinnacle West's pension plan and other postretirement benefit plan assets, by asset category	'	'	'
Fair value of plan assets	8,660	2,419	'
Pension Benefits \| Short-term investments and other \| Counterparty Netting and Other \| Pinnacle West	'	'	'
Fair value of Pinnacle West's pension plan and other postretirement benefit plan assets, by asset category	'	'	'
Fair value of plan assets	250	-63	'
Other Benefits	'	'	'
Retirement Plans and Other Benefits	'	'	'
Actual asset allocation (as a percent)	62.00%	'	'
Target asset allocation	'	'	'
Target allocation (as a percent)	75.00%	'	'
Fair value of Pinnacle West's pension plan and other postretirement benefit plan assets, by asset category	'	'	'
Fair value of plan assets	748,339	684,221	608,663
Other Benefits \| Pinnacle West	'	'	'
Fair value of Pinnacle West's pension plan and other postretirement benefit plan assets, by asset category	'	'	'
Fair value of plan assets	748,339	684,221	'
Other Benefits \| Quoted Prices in Active Markets for Identical Assets (Level 1) \| Pinnacle West	'	'	'
Fair value of Pinnacle West's pension plan and other postretirement benefit plan assets, by asset category	'	'	'
Fair value of plan assets	371,777	333,146	'
Other Benefits \| Significant Other Observable Inputs (Level 2) \| Pinnacle West	'	'	'
Fair value of Pinnacle West's pension plan and other postretirement benefit plan assets, by asset category	'	'	'
Fair value of plan assets	374,132	350,029	'
Other Benefits \| Counterparty Netting and Other \| Pinnacle West	'	'	'
Fair value of Pinnacle West's pension plan and other postretirement benefit plan assets, by asset category	'	'	'
Fair value of plan assets	2,430	1,046	'
Other Benefits \| Fixed income securities.	'	'	'
Retirement Plans and Other Benefits	'	'	'
Actual asset allocation (as a percent)	38.00%	'	'
Target asset allocation	'	'	'
Target allocation (as a percent)	25.00%	'	'
Other Benefits \| Cash and cash equivalent funds \| Pinnacle West	'	'	'
Fair value of Pinnacle West's pension plan and other postretirement benefit plan assets, by asset category	'	'	'
Fair value of plan assets	'	60	'
Other Benefits \| Cash and cash equivalent funds \| Quoted Prices in Active Markets for Identical Assets (Level 1) \| Pinnacle West	'	'	'
Fair value of Pinnacle West's pension plan and other postretirement benefit plan assets, by asset category	'	'	'
Fair value of plan assets	'	60	'
Other Benefits \| Corporate debt \| Pinnacle West	'	'	'
Fair value of Pinnacle West's pension plan and other postretirement benefit plan assets, by asset category	'	'	'
Fair value of plan assets	153,888	163,306	'
Other Benefits \| Corporate debt \| Significant Other Observable Inputs (Level 2) \| Pinnacle West	'	'	'
Fair value of Pinnacle West's pension plan and other postretirement benefit plan assets, by asset category	'	'	'
Fair value of plan assets	153,888	163,306	'
Other Benefits \| U.S. Treasury \| Pinnacle West	'	'	'
Fair value of Pinnacle West's pension plan and other postretirement benefit plan assets, by asset category	'	'	'
Fair value of plan assets	98,704	112,558	'
Other Benefits \| U.S. Treasury \| Quoted Prices in Active Markets for Identical Assets (Level 1) \| Pinnacle West	'	'	'
Fair value of Pinnacle West's pension plan and other postretirement benefit plan assets, by asset category	'	'	'
Fair value of plan assets	98,704	112,558	'
Other Benefits \| Other \| Pinnacle West	'	'	'
Fair value of Pinnacle West's pension plan and other postretirement benefit plan assets, by asset category	'	'	'
Fair value of plan assets	27,936	33,998	'
Other Benefits \| Other \| Significant Other Observable Inputs (Level 2) \| Pinnacle West	'	'	'
Fair value of Pinnacle West's pension plan and other postretirement benefit plan assets, by asset category	'	'	'
Fair value of plan assets	27,936	33,998	'
Other Benefits \| U.S. Companies, Equities \| Pinnacle West	'	'	'
Fair value of Pinnacle West's pension plan and other postretirement benefit plan assets, by asset category	'	'	'
Fair value of plan assets	252,181	205,714	'
Other Benefits \| U.S. Companies, Equities \| Quoted Prices in Active Markets for Identical Assets (Level 1) \| Pinnacle West	'	'	'
Fair value of Pinnacle West's pension plan and other postretirement benefit plan assets, by asset category	'	'	'
Fair value of plan assets	252,181	205,714	'
Other Benefits \| International Companies, Equities \| Pinnacle West	'	'	'
Fair value of Pinnacle West's pension plan and other postretirement benefit plan assets, by asset category	'	'	'
Fair value of plan assets	20,892	14,412	'
Other Benefits \| International Companies, Equities \| Quoted Prices in Active Markets for Identical Assets (Level 1) \| Pinnacle West	'	'	'
Fair value of Pinnacle West's pension plan and other postretirement benefit plan assets, by asset category	'	'	'
Fair value of plan assets	20,892	14,412	'
Other Benefits \| U.S. Equities \| Pinnacle West	'	'	'
Fair value of Pinnacle West's pension plan and other postretirement benefit plan assets, by asset category	'	'	'
Fair value of plan assets	80,751	60,038	'
Other Benefits \| U.S. Equities \| Significant Other Observable Inputs (Level 2) \| Pinnacle West	'	'	'
Fair value of Pinnacle West's pension plan and other postretirement benefit plan assets, by asset category	'	'	'
Fair value of plan assets	80,751	60,038	'
Other Benefits \| International Equities \| Pinnacle West	'	'	'
Fair value of Pinnacle West's pension plan and other postretirement benefit plan assets, by asset category	'	'	'
Fair value of plan assets	92,382	76,969	'
Other Benefits \| International Equities \| Significant Other Observable Inputs (Level 2) \| Pinnacle West	'	'	'
Fair value of Pinnacle West's pension plan and other postretirement benefit plan assets, by asset category	'	'	'
Fair value of plan assets	92,382	76,969	'
Other Benefits \| Real estate \| Pinnacle West	'	'	'
Fair value of Pinnacle West's pension plan and other postretirement benefit plan assets, by asset category	'	'	'
Fair value of plan assets	10,761	9,378	'
Other Benefits \| Real estate \| Significant Other Observable Inputs (Level 2) \| Pinnacle West	'	'	'
Fair value of Pinnacle West's pension plan and other postretirement benefit plan assets, by asset category	'	'	'
Fair value of plan assets	10,761	9,378	'
Other Benefits \| Short-term investments and other \| Pinnacle West	'	'	'
Fair value of Pinnacle West's pension plan and other postretirement benefit plan assets, by asset category	'	'	'
Fair value of plan assets	10,844	7,788	'
Other Benefits \| Short-term investments and other \| Significant Other Observable Inputs (Level 2) \| Pinnacle West	'	'	'
Fair value of Pinnacle West's pension plan and other postretirement benefit plan assets, by asset category	'	'	'
Fair value of plan assets	8,414	6,340	'
Other Benefits \| Short-term investments and other \| Counterparty Netting and Other \| Pinnacle West	'	'	'
Fair value of Pinnacle West's pension plan and other postretirement benefit plan assets, by asset category	'	'	'
Fair value of plan assets	2,430	1,046	'
Other Benefits \| Short-term investments \| Quoted Prices in Active Markets for Identical Assets (Level 1) \| Pinnacle West	'	'	'
Fair value of Pinnacle West's pension plan and other postretirement benefit plan assets, by asset category	'	'	'
Fair value of plan assets	'	$402	'

Retirement_Plans_and_Other_Ben5

Retirement Plans and Other Benefits (Details 4) (USD $)

12 Months Ended

1 Months Ended

12 Months Ended

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Jan. 31, 2014

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Dec. 31, 2013

Dec. 31, 2012

Pinnacle West

ARIZONA PUBLIC SERVICE COMPANY

Pension Benefits

Other Benefits

Subsequent event

Expected contributions

Pinnacle West

ARIZONA PUBLIC SERVICE COMPANY

Significant Unobservable Inputs (Level 3)

Short-term investments and other

Pinnacle West

ARIZONA PUBLIC SERVICE COMPANY

Short-term investments and other

Maximum

Pinnacle West

Significant Unobservable Inputs (Level 3)

Pinnacle West

Changes in fair value for assets that are measured at fair value on a recurring basis

Balance at the beginning of the period

$2,079,181,000

$1,850,550,000

$2,264,121,000

$2,079,181,000

$8,660,000

$2,419,000

$49,970,000

$29,278,000

$2,419,000

$8,660,000

$2,419,000

$684,221,000

$608,663,000

$748,339,000

$684,221,000

$10,844,000

$7,788,000

Actual return on assets still held

-498,000

-668,000

Purchases, sales, and settlements

6,739,000

3,087,000

Balance at the end of the period

2,264,121,000

2,079,181,000

1,850,550,000

2,264,121,000

2,079,181,000

8,660,000

2,419,000

49,970,000

29,278,000

8,660,000

2,419,000

8,660,000

2,419,000

748,339,000

684,221,000

608,663,000

748,339,000

684,221,000

10,844,000

7,788,000

Contributions

Employer's contributions under the plan

140,500,000

65,000,000

70,000,000

140,000,000

64,000,000

14,438,000

22,707,000

19,000,000

14,000,000

22,000,000

19,000,000

Minimum Contributions under MAP-21

Minimum contributions under MAP-21

141,000,000

2014

2015

19,000,000

2016

122,000,000

Expected employer's contributions

300,000,000

2014

175,000,000

10,000,000

2015

100,000,000

10,000,000

2016

25,000,000

10,000,000

Estimated Future Benefit Payments

2014

129,159,000

28,664,000

2015

143,452,000

31,804,000

2016

149,105,000

34,933,000

2017

162,678,000

37,966,000

2018

169,064,000

40,972,000

Years 2019-2023

972,826,000

245,366,000

Employee Savings Plan Benefits

APS's employees share of total cost of the plans (as a percent)

99.00%

Expenses recorded for the defined contribution savings plan

$9,000,000

$8,000,000

Leases_Details

Leases (Details) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011	Dec. 31, 2008	Dec. 31, 1986
	item	Dec. 31, 2012	Dec. 31, 2011	item	item
Leases	'	'	'	'	'
Lease expense	$18	$19	$21	'	'
Estimated future minimum lease payments for operating leases, excluding purchased power agreements	'	'	'	'	'
2014	20	'	'	'	'
2015	17	'	'	'	'
2016	6	'	'	'	'
2017	5	'	'	'	'
2018	4	'	'	'	'
Thereafter	59	'	'	'	'
Total future lease commitments	111	'	'	'	'
APS	'	'	'	'	'
Leases	'	'	'	'	'
Lease expense	15	16	18	'	'
Estimated future minimum lease payments for operating leases, excluding purchased power agreements	'	'	'	'	'
2014	17	'	'	'	'
2015	14	'	'	'	'
2016	5	'	'	'	'
2017	5	'	'	'	'
2018	4	'	'	'	'
Thereafter	59	'	'	'	'
Total future lease commitments	$104	'	'	'	'
Number of VIE lessor trusts	3	'	'	3	3
Palo Verde Lessor Trusts	'	'	'	'	'
Estimated future minimum lease payments for operating leases, excluding purchased power agreements	'	'	'	'	'
Number of VIE lessor trusts	'	'	'	'	3

JointlyOwned_Facilities_Detail

Jointly-Owned Facilities (Details) (ARIZONA PUBLIC SERVICE COMPANY, USD $)	Dec. 31, 2013
In Thousands, unless otherwise specified	Dec. 31, 2013
Palo Verde Units 1 and 3	'
Interests in jointly-owned facilities	'
Percent Owned	29.10%
Plant in Service	$1,701,844
Accumulated Depreciation	1,027,523
Construction Work in Progress	22,400
Palo Verde Unit 2	'
Interests in jointly-owned facilities	'
Percent Owned	16.80%
Plant in Service	543,972
Accumulated Depreciation	338,918
Construction Work in Progress	10,095
Palo Verde Common	'
Interests in jointly-owned facilities	'
Percent Owned	28.00%
Plant in Service	538,818
Accumulated Depreciation	219,801
Construction Work in Progress	81,599
Palo Verde Sale Leaseback	'
Interests in jointly-owned facilities	'
Plant in Service	351,050
Accumulated Depreciation	225,925
Four Corners Units 4, 5 and Common	'
Interests in jointly-owned facilities	'
Percent Owned	63.00%
Plant in Service	809,946
Accumulated Depreciation	608,194
Construction Work in Progress	14,434
Navajo Generating Station Units 1, 2 and 3	'
Interests in jointly-owned facilities	'
Percent Owned	14.00%
Plant in Service	270,448
Accumulated Depreciation	150,501
Construction Work in Progress	2,864
Cholla common facilities	'
Interests in jointly-owned facilities	'
Percent Owned	63.30%
Plant in Service	148,299
Accumulated Depreciation	47,851
Construction Work in Progress	7,159
ANPP 500kV System	'
Interests in jointly-owned facilities	'
Percent Owned	34.20%
Plant in Service	98,145
Accumulated Depreciation	32,350
Construction Work in Progress	1,095
Navajo Southern System	'
Interests in jointly-owned facilities	'
Percent Owned	22.20%
Plant in Service	58,702
Accumulated Depreciation	16,937
Construction Work in Progress	518
Palo Verde - Yuma 500kV System	'
Interests in jointly-owned facilities	'
Percent Owned	18.00%
Plant in Service	12,115
Accumulated Depreciation	4,656
Construction Work in Progress	11,786
Four Corners Switchyards	'
Interests in jointly-owned facilities	'
Percent Owned	48.10%
Plant in Service	33,460
Accumulated Depreciation	9,052
Construction Work in Progress	185
Phoenix - Mead System	'
Interests in jointly-owned facilities	'
Percent Owned	17.10%
Plant in Service	39,758
Accumulated Depreciation	12,140
Palo Verde - Estrella 500kV System	'
Interests in jointly-owned facilities	'
Percent Owned	50.00%
Plant in Service	89,571
Accumulated Depreciation	14,883
Construction Work in Progress	21
Morgan-Pinnacle Peak System	'
Interests in jointly-owned facilities	'
Percent Owned	64.50%
Plant in Service	130,132
Accumulated Depreciation	6,651
Construction Work in Progress	1,042
Round Valley System	'
Interests in jointly-owned facilities	'
Percent Owned	50.00%
Plant in Service	488
Accumulated Depreciation	268
Palo Verde - Morgan System	'
Interests in jointly-owned facilities	'
Percent Owned	90.00%
Construction Work in Progress	$36,601

Commitments_and_Contingencies_1

Commitments and Contingencies (Details) (ARIZONA PUBLIC SERVICE COMPANY, USD $)	0 Months Ended	12 Months Ended
	Apr. 02, 2013	Dec. 31, 2013	Dec. 31, 2008	Dec. 31, 1986
	Apr. 02, 2013	item	item	item
ARIZONA PUBLIC SERVICE COMPANY	'	'	'	'
Palo Verde Nuclear Generating Station	'	'	'	'
Estimated share of the costs related to on-site interim storage of spent nuclear fuel	'	$122,000,000	'	'
Regulatory liability of amounts recovered in retail rates in excess of amounts spent for on-site interim spent fuel storage	'	42,000,000	'	'
Maximum insurance against public liability per occurrence for a nuclear incident	'	13,600,000,000	'	'
Maximum available nuclear liability insurance	'	375,000,000	'	'
Remaining nuclear liability insurance through mandatory industry wide retrospective assessment program	'	13,200,000,000	'	'
Maximum assessment per reactor for each nuclear incident	'	127,300,000	'	'
Annual limit per incident with respect to maximum assessment	'	19,000,000	'	'
Number of VIE lessor trusts	'	3	3	3
Maximum potential retrospective assessment per incident of APS	'	111,000,000	'	'
Annual payment limitation with respect to maximum potential retrospective assessment	'	16,400,000	'	'
Amount of "all risk" (including nuclear hazards) insurance for property damage to, and decontamination of, property at Palo Verde	'	2,750,000,000	'	'
Sublimit for non-nuclear property damage losses which has been imposed to the primary policy offered	1,500,000,000	'	'	'
Sublimit for non-nuclear losses which has been imposed to the accidental outage policy	327,600,000	'	'	'
Maximum amount that APS could incur under the current NEIL policies for each retrospective assessment	'	18,000,000	'	'
Collateral assurance provided based on rating triggers	'	$48,000,000	'	'
Period to provide collateral assurance based on rating triggers	'	'20 days	'	'

Commitments_and_Contingencies_2

Commitments and Contingencies (Details 2) (ARIZONA PUBLIC SERVICE COMPANY, USD $)	0 Months Ended	1 Months Ended	12 Months Ended		12 Months Ended						0 Months Ended
	Jan. 22, 2014	Sep. 30, 2011	Dec. 31, 2013	Sep. 08, 2011	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011	Dec. 31, 2013	Dec. 31, 2013	Dec. 31, 2012	Aug. 06, 2013
	item	kV	item		Coal take-or-pay commitments	Coal take-or-pay commitments	Coal take-or-pay commitments	Renewable energy credits	Coal Mine Reclamation Obligations	Coal Mine Reclamation Obligations	Contaminated groundwater wells
		item									item
		MW
Contractual Obligations	'	'	'	'	'	'	'	'	'	'	'
2014	'	'	$729,000,000	'	$152,000,000	'	'	$48,000,000	$1,000,000	'	'
2015	'	'	628,000,000	'	157,000,000	'	'	42,000,000	1,000,000	'	'
2016	'	'	638,000,000	'	166,000,000	'	'	42,000,000	8,000,000	'	'
2017	'	'	613,000,000	'	180,000,000	'	'	42,000,000	14,000,000	'	'
2018	'	'	580,000,000	'	175,000,000	'	'	42,000,000	14,000,000	'	'
Thereafter	'	'	8,700,000,000	'	2,539,000,000	'	'	453,000,000	170,000,000	'	'
Total commitments	'	'	'	'	3,400,000,000	'	'	'	207,000,000	119,000,000	'
Total net present value of commitments	'	'	'	'	2,200,000,000	'	'	'	'	'	'
Actual purchases under commitment obligations	'	'	'	'	188,000,000	196,000,000	191,000,000	'	'	'	'
Superfund	'	'	'	'	'	'	'	'	'	'	'
Costs related to investigation and study under Superfund site	'	'	2,000,000	'	'	'	'	'	'	'	'
Number of defendants against whom Roosevelt Irrigation District ("RID") filed lawsuit	'	'	'	'	'	'	'	'	'	'	24
Southwest Power Outage	'	'	'	'	'	'	'	'	'	'	'
Capacity of transmission line that tripped out of service (in 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	'	69,700	'	'	'	'	'	'	'	'	'
Capacity of firm load that were reported to have been affected due to outages affecting portions of southern Arizona, southern California and northern Mexico (in MW)	'	7,900	'	'	'	'	'	'	'	'	'
Number of customers that were reported to have been affected due to outages	'	2,700,000	'	'	'	'	'	'	'	'	'
Number of alleged entities	6	'	'	'	'	'	'	'	'	'	'
Number of Reliability Standard Requirements Violations alleged	7	'	'	'	'	'	'	'	'	'	'
Maximum possible fine per violation per day that the violation is found to have been in existence	'	'	'	1,000,000	'	'	'	'	'	'	'
Financial Assurances	'	'	'	'	'	'	'	'	'	'	'
Outstanding letters of credit to support existing variable interest rate pollution control bonds	'	'	76,000,000	'	'	'	'	'	'	'	'
Number of letters of credit expiring in 2015	'	'	1	'	'	'	'	'	'	'	'
Number of letters of credit expiring in 2016	'	'	2	'	'	'	'	'	'	'	'
Letters of credit to support certain equity lessors in the Palo Verde sale leaseback transactions	'	'	32,000,000	'	'	'	'	'	'	'	'
Outstanding letters of credit to support natural gas tolling contract obligations	'	'	$55,000,000	'	'	'	'	'	'	'	'

Commitments_and_Contingencies_3

Commitments and Contingencies (Details 3) (USD $)	0 Months Ended	12 Months Ended
In Millions, unless otherwise specified	23-May-13	Dec. 31, 2013	Dec. 31, 2013	Dec. 31, 2013	Dec. 31, 2013	Dec. 31, 2013
	Four Corners	Four Corners	Four Corners	Navajo Plant	Cholla	Cholla Units 1-3
	New Mexico Tax Matter	ARIZONA PUBLIC SERVICE COMPANY	ARIZONA PUBLIC SERVICE COMPANY	ARIZONA PUBLIC SERVICE COMPANY	ARIZONA PUBLIC SERVICE COMPANY	ARIZONA PUBLIC SERVICE COMPANY
			New Mexico Tax Matter
Environmental Matters	'	'	'	'	'	'
Expected environmental cost	'	$350	'	$200	$200	$120
Share of Cost of Control of Four Corners Units 4 and 5	'	63.00%	'	'	'	'
Coal severance surtax, penalty, and interest	30	'	'	'	'	'
Share of the assessment	'	'	$12	'	'	'

Asset_Retirement_Obligations_D

Asset Retirement Obligations (Details) (USD $)	12 Months Ended
Asset Retirement Obligations (Details) (USD $)	Dec. 31, 2013	Dec. 31, 2012
Changes attributable to:	'	'
Asset retirement obligations, current	$32,896,000	'
ARIZONA PUBLIC SERVICE COMPANY	'	'
Change in asset retirement obligations	'	'
Asset retirement obligations at the beginning of year	357,000,000	280,000,000
Changes attributable to:	'	'
Accretion expense	24,000,000	19,000,000
Settlements	-12,000,000	'
Assumed SCE's obligation	34,000,000	'
Estimated cash flow revisions	-56,000,000	58,000,000
Asset retirement obligations at the end of year	347,000,000	357,000,000
Asset retirement obligations, current	$33,000,000	'

Selected_Quarterly_Financial_D2

Selected Quarterly Financial Data (Unaudited) (Details) (USD $)	3 Months Ended								12 Months Ended
In Thousands, except Per Share data, unless otherwise specified	Dec. 31, 2013	Sep. 30, 2013	Jun. 30, 2013	Mar. 31, 2013	Dec. 31, 2012	Sep. 30, 2012	Jun. 30, 2012	Mar. 31, 2012	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Consolidated quarterly financial information	'	'	'	'	'	'	'	'	'	'	'
Operating revenues	$699,762	$1,152,392	$915,822	$686,652	$693,122	$1,109,475	$878,576	$620,631	$3,454,628	$3,301,804	$3,241,379
Operations and maintenance	238,854	233,323	229,300	223,250	237,141	220,729	216,236	210,663	924,727	884,769	904,286
Operating income	83,900	415,688	259,812	86,923	101,289	447,970	254,489	48,007	846,323	851,755	746,508
Income Taxes	9,167	131,912	77,043	12,469	18,157	147,116	76,689	-4,645	230,591	237,317	183,604
Income from continuing operations	32,814	234,718	139,598	32,836	34,905	252,874	130,930	284	439,966	418,993	355,634
Net income attributable to common shareholders	$24,260	$226,163	$131,207	$24,444	$22,631	$244,823	$122,345	($8,257)	$406,074	$381,542	$339,473
Earnings Per Share:	'	'	'	'	'	'	'	'	'	'	'
Income from continuing operations attributable to common shareholders - Basic (in dollars per share)	$0.22	$2.06	$1.19	$0.22	$0.24	$2.23	$1.12	($0.07)	$3.69	$3.54	$3.01
Net income attributable to common shareholders - Basic (in dollars per share)	$0.22	$2.06	$1.19	$0.22	$0.21	$2.23	$1.12	($0.08)	$3.69	$3.48	$3.11
Income from continuing operations attributable to common shareholders - Diluted (in dollars per share)	$0.22	$2.04	$1.18	$0.22	$0.24	$2.21	$1.12	($0.07)	$3.66	$3.50	$2.99
Net income attributable to common shareholders - Diluted (in dollars per share)	$0.22	$2.04	$1.18	$0.22	$0.20	$2.21	$1.11	($0.08)	$3.66	$3.45	$3.09

Fair_Value_Measurements_Detail

Fair Value Measurements (Details) (USD $)	Dec. 31, 2013	Dec. 31, 2012
Assets	'	'
Nuclear decommissioning trust	$642,007,000	$570,625,000
Total assets	41,000,000	62,000,000
Liabilities	'	'
Risk management activities-derivative instruments: Commodity Contracts	-102,207,000	-159,005,000
Fair value measurement on a recurring basis \| Quoted Prices in Active Markets for Identical Assets (Level 1)	'	'
Assets	'	'
Cash Equivalents	'	16,000,000
Nuclear decommissioning trust	107,000,000	110,000,000
Total assets	107,000,000	126,000,000
Fair value measurement on a recurring basis \| Quoted Prices in Active Markets for Identical Assets (Level 1) \| U.S. Treasury	'	'
Assets	'	'
Nuclear decommissioning trust	107,000,000	104,000,000
Fair value measurement on a recurring basis \| Quoted Prices in Active Markets for Identical Assets (Level 1) \| Cash and cash equivalent funds	'	'
Assets	'	'
Nuclear decommissioning trust	'	6,000,000
Fair value measurement on a recurring basis \| Significant Other Observable Inputs (Level 2)	'	'
Assets	'	'
Risk management activities-derivative instruments: Commodity Contracts	9,000,000	22,000,000
Nuclear decommissioning trust	538,000,000	465,000,000
Total assets	547,000,000	487,000,000
Liabilities	'	'
Risk management activities-derivative instruments: Commodity Contracts	-33,000,000	-96,000,000
Fair value measurement on a recurring basis \| Significant Other Observable Inputs (Level 2) \| US commingled equity funds	'	'
Assets	'	'
Nuclear decommissioning trust	272,000,000	204,000,000
Fair value measurement on a recurring basis \| Significant Other Observable Inputs (Level 2) \| Cash and cash equivalent funds	'	'
Assets	'	'
Nuclear decommissioning trust	11,000,000	13,000,000
Fair value measurement on a recurring basis \| Significant Other Observable Inputs (Level 2) \| Corporate debt	'	'
Assets	'	'
Nuclear decommissioning trust	88,000,000	80,000,000
Fair value measurement on a recurring basis \| Significant Other Observable Inputs (Level 2) \| Mortgage-backed securities	'	'
Assets	'	'
Nuclear decommissioning trust	85,000,000	83,000,000
Fair value measurement on a recurring basis \| Significant Other Observable Inputs (Level 2) \| Municipality bonds	'	'
Assets	'	'
Nuclear decommissioning trust	71,000,000	74,000,000
Fair value measurement on a recurring basis \| Significant Other Observable Inputs (Level 2) \| Other	'	'
Assets	'	'
Nuclear decommissioning trust	11,000,000	11,000,000
Fair value measurement on a recurring basis \| Significant Unobservable Inputs (Level 3)	'	'
Assets	'	'
Risk management activities-derivative instruments: Commodity Contracts	41,000,000	62,000,000
Total assets	41,000,000	62,000,000
Liabilities	'	'
Risk management activities-derivative instruments: Commodity Contracts	-90,000,000	-110,000,000
Fair value measurement on a recurring basis \| Other	'	'
Assets	'	'
Risk management activities-derivative instruments: Commodity Contracts	-9,000,000	-22,000,000
Nuclear decommissioning trust	-3,000,000	-4,000,000
Total assets	-12,000,000	-26,000,000
Liabilities	'	'
Risk management activities-derivative instruments: Commodity Contracts	21,000,000	47,000,000
Fair value measurement on a recurring basis \| Other \| Cash and cash equivalent funds	'	'
Assets	'	'
Nuclear decommissioning trust	-3,000,000	-4,000,000
Fair value measurement on a recurring basis \| Fair Value	'	'
Assets	'	'
Cash Equivalents	'	16,000,000
Risk management activities-derivative instruments: Commodity Contracts	41,000,000	62,000,000
Nuclear decommissioning trust	642,000,000	571,000,000
Total assets	683,000,000	649,000,000
Liabilities	'	'
Risk management activities-derivative instruments: Commodity Contracts	-102,000,000	-159,000,000
Fair value measurement on a recurring basis \| Fair Value \| US commingled equity funds	'	'
Assets	'	'
Nuclear decommissioning trust	272,000,000	204,000,000
Fair value measurement on a recurring basis \| Fair Value \| U.S. Treasury	'	'
Assets	'	'
Nuclear decommissioning trust	107,000,000	104,000,000
Fair value measurement on a recurring basis \| Fair Value \| Cash and cash equivalent funds	'	'
Assets	'	'
Nuclear decommissioning trust	8,000,000	15,000,000
Fair value measurement on a recurring basis \| Fair Value \| Corporate debt	'	'
Assets	'	'
Nuclear decommissioning trust	88,000,000	80,000,000
Fair value measurement on a recurring basis \| Fair Value \| Mortgage-backed securities	'	'
Assets	'	'
Nuclear decommissioning trust	85,000,000	83,000,000
Fair value measurement on a recurring basis \| Fair Value \| Municipality bonds	'	'
Assets	'	'
Nuclear decommissioning trust	71,000,000	74,000,000
Fair value measurement on a recurring basis \| Fair Value \| Other	'	'
Assets	'	'
Nuclear decommissioning trust	$11,000,000	$11,000,000

Fair_Value_Measurements_Detail1

Fair Value Measurements (Details 2) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012
Information regarding the entity's internally developed significant unobservable inputs used to value its level 3 instruments	'	'
Assets	$41	$62
Liabilities	90	110
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	'	'
Net derivative balance at beginning of period	-48	-51
Total net gains (losses) realized/unrealized:	'	'
Included in earnings	'	2
Included in OCI	'	-3
Deferred as a regulatory asset or liability	-10	7
Settlements	10	-5
Transfers into Level 3 from Level 2	'	-2
Transfers from Level 3 into Level 2	-1	4
Net derivative balance at end of period	-49	-48
Transfers in or out of Level 1 to or from any other hierarchy level	0	'
Electricity forward contracts	'	'
Information regarding the entity's internally developed significant unobservable inputs used to value its level 3 instruments	'	'
Assets	40	57
Liabilities	66	82
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)	24.89	23.06
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)	65.04	64.2
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)	41.09	43.16
Option Contracts	'	'
Information regarding the entity's internally developed significant unobservable inputs used to value its level 3 instruments	'	'
Liabilities	19	27
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)	39.91	36.66
Implied electricity price volatilities (as a percent)	35.00%	15.00%
Natural gas forward price (per MMbtu)	3.57	4.1
Implied natural gas price volatilities (as a percent)	22.00%	17.00%
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)	85.41	92.19
Implied electricity price volatilities (as a percent)	94.00%	66.00%
Natural gas forward price (per MMbtu)	3.8	4.25
Implied natural gas price volatilities (as a percent)	36.00%	36.00%
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)	58.7	60.97
Implied electricity price volatilities (as a percent)	59.00%	39.00%
Natural gas forward price (per MMbtu)	3.71	4.2
Implied natural gas price volatilities (as a percent)	27.00%	23.00%
Natural gas forward contracts	'	'
Information regarding the entity's internally developed significant unobservable inputs used to value its level 3 instruments	'	'
Assets	1	5
Liabilities	$5	$1
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)	3.47	3.25
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)	4.31	4.44
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)	3.87	3.93

Earnings_Per_Share_Details

Earnings Per Share (Details) (USD $)	3 Months Ended								12 Months Ended
Earnings Per Share (Details) (USD $)	Dec. 31, 2013	Sep. 30, 2013	Jun. 30, 2013	Mar. 31, 2013	Dec. 31, 2012	Sep. 30, 2012	Jun. 30, 2012	Mar. 31, 2012	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Basic earnings per share:	'	'	'	'	'	'	'	'	'	'	'
Income from continuing operations attributable to common shareholders (in dollars per share)	$0.22	$2.06	$1.19	$0.22	$0.24	$2.23	$1.12	($0.07)	$3.69	$3.54	$3.01
Income (loss) from discontinued operations (in dollars per share)	'	'	'	'	'	'	'	'	'	($0.06)	$0.10
Earnings per share - basic (in dollars per share)	$0.22	$2.06	$1.19	$0.22	$0.21	$2.23	$1.12	($0.08)	$3.69	$3.48	$3.11
Diluted earnings per share:	'	'	'	'	'	'	'	'	'	'	'
Income from continuing operations attributable to common shareholders (in dollars per share)	$0.22	$2.04	$1.18	$0.22	$0.24	$2.21	$1.12	($0.07)	$3.66	$3.50	$2.99
Income (loss) from discontinued operations (in dollars per share)	'	'	'	'	'	'	'	'	'	($0.05)	$0.10
Earnings per share - diluted (in dollars per share)	$0.22	$2.04	$1.18	$0.22	$0.20	$2.21	$1.11	($0.08)	$3.66	$3.45	$3.09
Dilutive stock options and performance shares	'	'	'	'	'	'	'	'	822,000	1,017,000	811,000
Total average common shares outstanding for the purposes of calculating diluted earnings per share	'	'	'	'	'	'	'	'	110,806,000	110,527,000	109,864,000
Options to purchase shares of common stock outstanding excluded from computation of diluted earnings per share due to its antidilutive effect	'	'	'	'	'	'	'	'	0	0	0

StockBased_Compensation_Detail

Stock-Based Compensation (Details) (USD $)

16-May-12

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Dec. 31, 2012

Dec. 31, 2011

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Dec. 31, 2013

Dec. 31, 2012

In Millions, except Share data, unless otherwise specified

2012 grant

Restricted stock unit awards

Restricted stock units and stock grants

Performance Share Awards

Retention Units

2007 grant

2008 grant

2009 grant

2010 grant

2011 grant

2012 grant

2007 grant

2011 grant

2012 grant

2013 grant

item

Maximum

Minimum

item

Maximum

Minimum

item

Maximum

Minimum

Stock-Based Compensation

Common shares to be available for grant under the 2012 Long Term Incentive Plan

4,595,500

Percentage of cash that the participant may elect as a deferral under the first option available under the plan

50.00%

Percentage of fully transferable shares of stock that the participant may elect as a deferral for the first option available under the plan

50.00%

The number of shares used to determine the cash award payable to an employee for each unit earned

Percentage of cash that the participant may elect as a dividend equivalent deferral under the first option available under the plan

50.00%

Percentage of fully transferable shares of stock that the participant may elect as a dividend equivalent deferral for the first option available under the plan

50.00%

Vesting period

'4 years

Additional shares to be granted as retention award if performance requirements are met

33,745

Percentage of awards vesting on February 15, 2013

50.00%

Percentage of awards vesting on February 15, 2014

25.00%

Percentage of awards vesting on February 15, 2015

25.00%

Stocks granted and the weighted average fair value

Units granted (in shares)

129,620

202,278

292,242

176,332

185,878

175,072

Grant date fair value (in dollars per share)

$55.21

$49.31

$41.98

$55.45

$47.40

$41.71

Nonvested shares

Balance at the beginning of the period (in shares)

480,753

347,690

Granted (in shares)

129,620

176,332

50,617

Increase in performance factor (in shares)

40,183

Vested (in shares)

191,988

200,915

Forfeited (in shares)

20,409

18,894

Balance at the end of the period (in shares)

397,976

480,753

344,396

347,690

Weighted-Average Grant-Date Fair Value

Balance at the beginning of the period (in dollars per share)

$43.58

$44.67

Granted (in dollars per share)

$55.21

$49.31

$41.98

$55.45

$47.40

$41.71

Increase in performance factor (in dollars per share)

$41.71

Vested (in dollars per share)

$40.33

$41.71

Forfeited (in dollars per share)

$45.70

$48.11

Balance at the end of the period (in dollars per share)

$47.74

$43.58

$51.13

$44.67

Cash required to settle the payment for grant

$1.90

$1.60

$1.70

$1.50

$2.30

$0.60

$2.50

$0.70

$2.20

Additional disclosures

Percentage of the awards that vest based on a percentile ranking of total shareholder return

50.00%

Percentage of the awards that vest based on non-financial separate performance metrics

50.00%

Number of performance element criteria

Number of non-financial separate performance metrics based on which awards vest

Performance period

'3 years

Exact number of shares issued as a percentage of the target award

200.00%

0.00%

200.00%

0.00%

200.00%

0.00%

Percentage of fully transferable shares of stock that the participant may elect as a deferral for the second option available under the plan

50.00%

Percentage of fully transferable shares of stock that the participant may elect as a dividend equivalent deferral for the second option available under the plan

50.00%

StockBased_Compensation_Detail1

Stock-Based Compensation (Details 2) (USD $)	12 Months Ended
In Millions, except Share data, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Additional disclosures	'	'	'
Total unrecognized compensation cost related to nonvested share-based compensation arrangements granted	$17	'	'
Expected weighted-average period of recognition of unrecognized compensation cost	'2 years	'	'
Total fair value of shares vested	20	19	14
Compensation cost that has been charged against income	25	32	23
Total income tax benefit recognized	10	13	9
ARIZONA PUBLIC SERVICE COMPANY	'	'	'
Additional disclosures	'	'	'
Compensation cost that has been charged against income	25	32	22
Stock Options	'	'	'
Stock option activity under prior equity incentive plans	'	'	'
Outstanding at the beginning of the period (in shares)	7,925	'	'
Exercised (in shares)	3,625	'	'
Forfeited or expired (in shares)	4,300	'	'
Outstanding at the end of the period (in shares)	'	7,925	'
Weighted-Average Exercise Price	'	'	'
Outstanding at the beginning of the period (in dollars per share)	$32.29	'	'
Exercised (in dollars per share)	$32.29	'	'
Forfeited or expired (in dollars per share)	$32.29	'	'
Outstanding at the end of the period (in dollars per share)	'	$32.29	'
Additional disclosures	'	'	'
Cash received from options exercised	$0.10	$0.50	$1.80

Derivative_Accounting_Details

Derivative Accounting (Details)	Dec. 31, 2013
Derivative Accounting	'
Percentage of unrealized gains and losses on certain derivatives deferred for future rate treatment	100.00%
Commodity - Power	'
Outstanding gross notional amount of derivatives	'
Outstanding gross notional amount of derivative instruments	5,765
Commodity - Gas	'
Outstanding gross notional amount of derivatives	'
Outstanding gross notional amount of derivative instruments	108
ARIZONA PUBLIC SERVICE COMPANY	'
Derivative Accounting	'
Percentage of unrealized gains and losses on certain derivatives deferred for future rate treatment before accounting treatment change	90.00%
Percentage of unrealized gains and losses on certain derivatives deferred for future rate treatment	100.00%

Derivative_Accounting_Details_

Derivative Accounting (Details 2) (Commodity Contracts, USD $)	12 Months Ended
	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Designated as Hedging Instruments	'	'	'
Gains and losses from derivative instruments	'	'	'
Loss Recognized in OCI on Derivative Instruments (Effective Portion)	($353,000)	($37,663,000)	($94,660,000)
Loss Reclassified from Accumulated OCI into Income (Effective Portion Realized)	-44,219,000	-99,007,000	-117,189,000
Gain (Loss) Recognized in Income (Ineffective Portion and Amount Excluded from Effectiveness Testing)	'	117,000	-211,000
Amount reclassified from accumulated other comprehensive income to earnings related to discontinued cash flow hedges	0	1,800,000	0
Estimated net loss before income taxes to be reclassified from accumulated other comprehensive income	21,000,000	'	'
Not Designated as Hedging Instruments	'	'	'
Gains and losses from derivative instruments	'	'	'
Net Gain (Loss) Recognized in Income from Derivative Instruments	-10,160,000	-2,644,000	-52,140,000
Not Designated as Hedging Instruments \| Revenue	'	'	'
Gains and losses from derivative instruments	'	'	'
Net Gain (Loss) Recognized in Income from Derivative Instruments	289,000	103,000	-27,000
Not Designated as Hedging Instruments \| Fuel and purchased power	'	'	'
Gains and losses from derivative instruments	'	'	'
Net Gain (Loss) Recognized in Income from Derivative Instruments	($10,449,000)	($2,747,000)	($52,113,000)

Derivative_Accounting_Details_1

Derivative Accounting (Details 3) (USD $)	Dec. 31, 2013	Dec. 31, 2012
In Thousands, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012
Liabilities	'	'
Amount Reported on Balance Sheet	($102,207)	($159,005)
Commodity Contracts	'	'
Assets	'	'
Amount Reported on Balance Sheet	41,000	'
Assets and Liabilities	'	'
Gross Recognized Derivatives	-72,712	-122,252
Amounts Offset	19,000	49,299
Net Recognized Derivatives	-53,712	-72,953
Other	-7,511	-24,462
Amount Reported on Balance Sheet	-61,223	-97,415
Commodity Contracts \| Current Assets	'	'
Assets	'	'
Gross Recognized Derivatives	24,587	42,495
Amounts Offset	-7,425	-17,797
Net Recognized Derivatives	17,162	24,698
Other	7	1,001
Amount Reported on Balance Sheet	17,169	25,699
Commodity Contracts \| Investments and Other Assets	'	'
Assets	'	'
Gross Recognized Derivatives	25,364	41,563
Amounts Offset	-1,549	-5,672
Net Recognized Derivatives	23,815	35,891
Amount Reported on Balance Sheet	23,815	35,891
Commodity Contracts \| Total Assets	'	'
Assets	'	'
Gross Recognized Derivatives	49,951	84,058
Amounts Offset	-8,974	-23,469
Net Recognized Derivatives	40,977	60,589
Other	7	1,001
Amount Reported on Balance Sheet	40,984	61,590
Commodity Contracts \| Current Liabilities	'	'
Liabilities	'	'
Gross Recognized Derivatives	-50,540	-105,324
Amounts Offset	26,166	57,046
Net Recognized Derivatives	-24,374	-48,278
Other	-7,518	-25,463
Amount Reported on Balance Sheet	-31,892	-73,741
Commodity Contracts \| Deferred Credits and Other	'	'
Liabilities	'	'
Gross Recognized Derivatives	-72,123	-100,986
Amounts Offset	1,808	15,722
Net Recognized Derivatives	-70,315	-85,264
Amount Reported on Balance Sheet	-70,315	-85,264
Commodity Contracts \| Total Liabilities	'	'
Liabilities	'	'
Gross Recognized Derivatives	-122,663	-206,310
Amounts Offset	27,974	72,768
Net Recognized Derivatives	-94,689	-133,542
Other	-7,518	-25,463
Amount Reported on Balance Sheet	-102,207	-159,005
Designated as Hedging Instruments	'	'
Liabilities	'	'
Amount Reported on Balance Sheet	$5,000	$5,000

Derivative_Accounting_Details_2

Derivative Accounting (Details 4) (Commodity Contracts, USD $)	12 Months Ended
	Dec. 31, 2013
	item
Commodity Contracts	'
Credit Risk and Credit-Related Contingent Features	'
Concentration of credit risk, number of counterparties	2
Concentration of risk with two counterparties, as a percentage of risk management assets	92.00%
Risk management activities-derivative instruments: Commodity Contracts	$41,000,000
Aggregate Fair Value of Derivative Instruments in a Net Liability Position	123,000,000
Cash Collateral Posted	19,000,000
Additional Cash Collateral in the Event Credit-Risk Related Contingent Features were Fully Triggered	66,000,000
Additional collateral to counterparties for energy related non-derivative instrument contracts	$180,000,000

Other_Income_and_Other_Expense2

Other Income and Other Expense (Details) (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Other income:	'	'	'
Interest income	$1,629	$1,239	$1,850
Investment gains - net	'	'	1,165
Miscellaneous	75	367	96
Total other income	1,704	1,606	3,111
Other expense:	'	'	'
Non-operating costs	-8,207	-7,777	-7,037
Investment loss - net	-3,711	-2,453	'
Miscellaneous	-4,106	-9,612	-3,414
Total other expense	($16,024)	($19,842)	($10,451)

Palo_Verde_Sale_Leaseback_Vari2

Palo Verde Sale Leaseback Variable Interest Entities (Details) (USD $)	12 Months Ended
	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011	Dec. 31, 2008	Dec. 31, 1986
	item	Dec. 31, 2012	Dec. 31, 2011	item	item
Palo Verde Sale Leaseback Variable Interest Entities	'	'	'	'	'
Increase in net income due to consolidation of Palo Verde Sale Leaseback Trusts	$33,892,000	$31,622,000	$27,467,000	'	'
Amounts relating to the VIEs included in Condensed Consolidated Balance Sheets	'	'	'	'	'
Palo Verde sale leaseback property plant and equipment, net of accumulated depreciation	125,125,000	128,995,000	'	'	'
Current maturities of long-term debt	540,424,000	122,828,000	'	'	'
Long-term debt excluding current maturities	13,420,000	38,869,000	'	'	'
Equity-Noncontrolling interests	145,990,000	129,483,000	'	'	'
ARIZONA PUBLIC SERVICE COMPANY	'	'	'	'	'
Palo Verde Sale Leaseback Variable Interest Entities	'	'	'	'	'
Number of VIE lessor trusts	3	'	'	3	3
Annual lease payments	49,000,000	'	'	'	'
Increase in net income due to consolidation of Palo Verde Sale Leaseback Trusts	33,892,000	31,613,000	27,524,000	'	'
Amounts relating to the VIEs included in Condensed Consolidated Balance Sheets	'	'	'	'	'
Palo Verde sale leaseback property plant and equipment, net of accumulated depreciation	125,125,000	128,995,000	'	'	'
Current maturities of long-term debt	540,424,000	122,828,000	'	'	'
Long-term debt excluding current maturities	13,420,000	38,869,000	'	'	'
Equity-Noncontrolling interests	145,990,000	129,483,000	'	'	'
ARIZONA PUBLIC SERVICE COMPANY \| Consolidation of VIEs	'	'	'	'	'
Palo Verde Sale Leaseback Variable Interest Entities	'	'	'	'	'
Annual lease payment if lease is extended	23,000,000	'	'	'	'
Number of options	2	'	'	'	'
Increase in net income due to consolidation of Palo Verde Sale Leaseback Trusts	34,000,000	32,000,000	28,000,000	'	'
Amounts relating to the VIEs included in Condensed Consolidated Balance Sheets	'	'	'	'	'
Palo Verde sale leaseback property plant and equipment, net of accumulated depreciation	125,000,000	129,000,000	'	'	'
Current maturities of long-term debt	26,000,000	27,000,000	'	'	'
Long-term debt excluding current maturities	13,000,000	39,000,000	'	'	'
Equity-Noncontrolling interests	146,000,000	129,000,000	'	'	'
Maximum payment to the VIEs' noncontrolling equity participants upon the occurrence of certain unlikely events	133,000,000	'	'	'	'
VIE debt to be assumed upon the occurrence of certain unlikely events	$39,000,000	'	'	'	'

Nuclear_Decommissioning_Trusts2

Nuclear Decommissioning Trusts (Details) (USD $)	12 Months Ended
Nuclear Decommissioning Trusts (Details) (USD $)	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Nuclear decommissioning trust fund assets	'	'	'
Fair Value	$642,007,000	$570,625,000	'
Realized gains and losses and proceeds from the sale of securities by the nuclear decommissioning trust funds	'	'	'
Proceeds from the sale of securities	446,025,000	417,603,000	497,780,000
Fair value of fixed income securities, summarized by contractual maturities	'	'	'
Total	642,007,000	570,625,000	'
ARIZONA PUBLIC SERVICE COMPANY	'	'	'
Nuclear decommissioning trust fund assets	'	'	'
Fair Value	642,007,000	570,625,000	'
Unrealized Gains	140,000,000	91,000,000	'
Unrealized Losses	-6,000,000	'	'
Net payables for securities purchases	-3,000,000	-4,000,000	'
Realized gains and losses and proceeds from the sale of securities by the nuclear decommissioning trust funds	'	'	'
Realized gains	6,000,000	7,000,000	8,000,000
Realized losses	-7,000,000	-4,000,000	-5,000,000
Proceeds from the sale of securities	446,025,000	417,603,000	497,780,000
Fair value of fixed income securities, summarized by contractual maturities	'	'	'
Total	642,007,000	570,625,000	'
ARIZONA PUBLIC SERVICE COMPANY \| Equity Securities	'	'	'
Nuclear decommissioning trust fund assets	'	'	'
Fair Value	272,000,000	204,000,000	'
Unrealized Gains	129,000,000	67,000,000	'
Fair value of fixed income securities, summarized by contractual maturities	'	'	'
Total	272,000,000	204,000,000	'
ARIZONA PUBLIC SERVICE COMPANY \| Fixed income securities.	'	'	'
Nuclear decommissioning trust fund assets	'	'	'
Fair Value	373,000,000	371,000,000	'
Unrealized Gains	11,000,000	24,000,000	'
Unrealized Losses	-6,000,000	'	'
Fair value of fixed income securities, summarized by contractual maturities	'	'	'
Less than one year	9,000,000	'	'
1 year - 5 years	109,000,000	'	'
5 years - 10 years	108,000,000	'	'
Greater than 10 years	147,000,000	'	'
Total	$373,000,000	$371,000,000	'

Changes_in_Accumulated_Other_C2

Changes in Accumulated Other Comprehensive Loss (Details) (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Changes in accumulated other comprehensive income (loss) by component	'	'	'
Beginning balance	($114,008)	'	'
OCI (loss) before reclassifications	5,381	'	'
Amounts reclassified from accumulated other comprehensive loss	30,574	'	'
Other comprehensive income (loss) attributable to common shareholders	35,955	38,155	7,605
Ending balance	-78,053	-114,008	'
Derivative Instruments	'	'	'
Changes in accumulated other comprehensive income (loss) by component	'	'	'
Beginning balance	-49,592	'	'
OCI (loss) before reclassifications	-213	'	'
Amounts reclassified from accumulated other comprehensive loss	26,747	'	'
Other comprehensive income (loss) attributable to common shareholders	26,534	'	'
Ending balance	-23,058	'	'
Pension and other postretirement benefits	'	'	'
Changes in accumulated other comprehensive income (loss) by component	'	'	'
Beginning balance	-64,416	'	'
OCI (loss) before reclassifications	5,594	'	'
Amounts reclassified from accumulated other comprehensive loss	3,827	'	'
Other comprehensive income (loss) attributable to common shareholders	9,421	'	'
Ending balance	($54,995)	'	'

SCHEDULE_I_CONDENSED_FINANCIAL1

SCHEDULE I - CONDENSED FINANCIAL INFORMATION OF REGISTRANT (Details) (USD $)	3 Months Ended								12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2013	Sep. 30, 2013	Jun. 30, 2013	Mar. 31, 2013	Dec. 31, 2012	Sep. 30, 2012	Jun. 30, 2012	Mar. 31, 2012	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
CONDENSED STATEMENTS OF INCOME	'	'	'	'	'	'	'	'	'	'	'
Operating revenues	$699,762	$1,152,392	$915,822	$686,652	$693,122	$1,109,475	$878,576	$620,631	$3,454,628	$3,301,804	$3,241,379
Operating expenses	'	'	'	'	'	'	'	'	2,608,305	2,450,049	2,494,871
OPERATING INCOME	83,900	415,688	259,812	86,923	101,289	447,970	254,489	48,007	846,323	851,755	746,508
Other	'	'	'	'	'	'	'	'	'	'	'
Total	'	'	'	'	'	'	'	'	11,261	4,200	16,367
Interest expense	'	'	'	'	'	'	'	'	201,888	214,616	241,995
INCOME FROM CONTINUING OPERATIONS BEFORE INCOME TAXES	'	'	'	'	'	'	'	'	670,557	656,310	539,238
Income tax benefit	9,167	131,912	77,043	12,469	18,157	147,116	76,689	-4,645	230,591	237,317	183,604
INCOME FROM CONTINUING OPERATIONS	32,814	234,718	139,598	32,836	34,905	252,874	130,930	284	439,966	418,993	355,634
Income (loss) from discontinued operations - net of income taxes	'	'	'	'	'	'	'	'	'	-5,829	11,306
NET INCOME ATTRIBUTABLE TO COMMON SHAREHOLDERS	24,260	226,163	131,207	24,444	22,631	244,823	122,345	-8,257	406,074	381,542	339,473
Other comprehensive income attributable to common shareholders	'	'	'	'	'	'	'	'	35,955	38,155	7,605
COMPREHENSIVE INCOME ATTRIBUTABLE TO COMMON SHAREHOLDERS	'	'	'	'	'	'	'	'	442,029	419,697	347,078
Pinnacle West	'	'	'	'	'	'	'	'	'	'	'
CONDENSED STATEMENTS OF INCOME	'	'	'	'	'	'	'	'	'	'	'
Operating revenues	'	'	'	'	'	'	'	'	799	6,133	1,034
Operating expenses	'	'	'	'	'	'	'	'	24,930	12,125	8,811
OPERATING INCOME	'	'	'	'	'	'	'	'	-24,131	-5,992	-7,777
Other	'	'	'	'	'	'	'	'	'	'	'
Equity in earnings of subsidiaries	'	'	'	'	'	'	'	'	420,926	391,528	335,859
Other expense	'	'	'	'	'	'	'	'	-1,999	-2,001	-1,481
Total	'	'	'	'	'	'	'	'	418,927	389,527	334,378
Interest expense	'	'	'	'	'	'	'	'	3,226	4,868	8,053
INCOME FROM CONTINUING OPERATIONS BEFORE INCOME TAXES	'	'	'	'	'	'	'	'	391,570	378,667	318,548
Income tax benefit	'	'	'	'	'	'	'	'	-14,504	-7,079	-8,938
INCOME FROM CONTINUING OPERATIONS	'	'	'	'	'	'	'	'	406,074	385,746	327,486
Income (loss) from discontinued operations - net of income taxes	'	'	'	'	'	'	'	'	'	-4,204	11,987
NET INCOME ATTRIBUTABLE TO COMMON SHAREHOLDERS	'	'	'	'	'	'	'	'	406,074	381,542	339,473
Other comprehensive income attributable to common shareholders	'	'	'	'	'	'	'	'	35,955	38,155	7,605
COMPREHENSIVE INCOME ATTRIBUTABLE TO COMMON SHAREHOLDERS	'	'	'	'	'	'	'	'	$442,029	$419,697	$347,078

SCHEDULE_I_CONDENSED_FINANCIAL2

SCHEDULE I - CONDENSED FINANCIAL INFORMATION OF REGISTRANT (Details 2) (USD $)	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011	Dec. 31, 2010
In Thousands, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011	Dec. 31, 2010
Current assets	'	'	'	'
Cash and cash equivalents	$9,526	$26,202	$33,583	$110,188
Accounts receivable	299,904	277,225	'	'
Current deferred income taxes	91,152	152,191	'	'
Income tax receivable	135,517	2,423	'	'
Other current assets	39,895	37,102	'	'
Total current assets	1,043,609	1,005,726	'	'
Investments and other assets	'	'	'	'
Other assets	60,875	62,694	'	'
Total investments and other assets	726,697	669,210	'	'
TOTAL ASSETS	13,508,686	13,379,615	'	'
Current liabilities	'	'	'	'
Accounts payable	284,516	221,312	'	'
Accrued taxes (Note 4)	130,998	124,939	'	'
Common dividends payable	62,528	59,789	'	'
Other current liabilities	158,540	171,573	'	'
Total current liabilities	1,618,644	1,083,542	'	'
Long-term debt less current maturities	2,796,465	3,199,088	'	'
Deferred credits and other	'	'	'	'
Deferred income taxes (Note 4)	2,351,882	2,151,371	'	'
Pension and other postretirement liabilities	513,628	1,058,755	'	'
Other	185,659	183,835	'	'
Total deferred credits and other	4,753,117	4,994,696	'	'
Common stock equity	'	'	'	'
Common stock	2,491,558	2,466,923	'	'
Accumulated other comprehensive loss	-78,053	-114,008	'	'
Retained earnings	1,785,273	1,624,102	'	'
Total shareholders' equity	4,194,470	3,972,806	'	'
Noncontrolling interests	145,990	129,483	'	'
Total equity	4,340,460	4,102,289	3,930,586	'
TOTAL LIABILITIES AND EQUITY	13,508,686	13,379,615	'	'
Pinnacle West	'	'	'	'
Current assets	'	'	'	'
Cash and cash equivalents	5,798	22,679	12,710	7,725
Accounts receivable	80,108	92,906	'	'
Current deferred income taxes	93,185	77,771	'	'
Income tax receivable	1,853	3,350	'	'
Other current assets	242	25	'	'
Total current assets	181,186	196,731	'	'
Investments and other assets	'	'	'	'
Investments in subsidiaries	4,455,049	4,223,301	'	'
Other assets	13,789	13,833	'	'
Total investments and other assets	4,468,838	4,237,134	'	'
TOTAL ASSETS	4,650,024	4,433,865	'	'
Current liabilities	'	'	'	'
Accounts payable	3,279	5,735	'	'
Accrued taxes (Note 4)	8,538	8,239	'	'
Common dividends payable	62,528	59,789	'	'
Other current liabilities	31,295	41,000	'	'
Total current liabilities	105,640	114,763	'	'
Long-term debt less current maturities	125,000	125,000	'	'
Deferred credits and other	'	'	'	'
Deferred income taxes (Note 4)	4,158	17,395	'	'
Pension and other postretirement liabilities	37,611	41,199	'	'
Other	37,155	33,219	'	'
Total deferred credits and other	78,924	91,813	'	'
Common stock equity	'	'	'	'
Common stock	2,487,250	2,462,712	'	'
Accumulated other comprehensive loss	-78,053	-114,008	'	'
Retained earnings	1,785,273	1,624,102	'	'
Total shareholders' equity	4,194,470	3,972,806	'	'
Noncontrolling interests	145,990	129,483	'	'
Total equity	4,340,460	4,102,289	'	'
TOTAL LIABILITIES AND EQUITY	$4,650,024	$4,433,865	'	'

SCHEDULE_I_CONDENSED_FINANCIAL3

SCHEDULE I - CONDENSED FINANCIAL INFORMATION OF REGISTRANT (Details 3) (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Cash flows from operating activities	'	'	'
Net Income	$439,966	$413,164	$366,940
Adjustments to reconcile net income to net cash provided by operating activities:	'	'	'
Depreciation and amortization	492,322	481,262	493,784
Deferred income taxes	249,296	187,023	117,952
Accounts receivable	44,991	-14,587	-40,626
Accounts payable	45,414	-96,600	58,346
Net cash flow provided by operating activities	1,153,307	1,171,122	1,125,583
Cash flows from investing activities	'	'	'
Proceeds from sale of energy-related products and services business	0	'	45,111
Net cash flow used for investing activities	-1,009,401	-872,994	-782,007
Cash flows from financing activities	'	'	'
Issuance of long-term debt	136,307	476,081	470,353
Short-term borrowings and payments - net	60,950	92,175	-16,600
Dividends paid on common stock	-235,244	-225,075	-221,728
Repayment of long-term debt	-122,828	-654,286	-655,169
Common stock equity issuance	17,319	15,955	15,841
Other	299	170	-2,668
Net cash flow used for financing activities	-160,582	-305,509	-420,181
NET DECREASE IN CASH AND CASH EQUIVALENTS	-16,676	-7,381	-76,605
CASH AND CASH EQUIVALENTS AT BEGINNING OF YEAR	26,202	33,583	110,188
CASH AND CASH EQUIVALENTS AT END OF YEAR	9,526	26,202	33,583
Pinnacle West	'	'	'
Cash flows from operating activities	'	'	'
Net Income	406,074	381,542	339,473
Adjustments to reconcile net income to net cash provided by operating activities:	'	'	'
Equity in earnings of subsidiaries - net	-420,926	-391,528	-335,859
Depreciation and amortization	95	94	97
Gain on sale of energy-related business	'	'	-10,404
Deferred income taxes	-28,806	-15,135	7,387
Accounts receivable	-21,671	-28,763	24,201
Accounts payable	-2,449	879	-2,677
Accrued taxes and income tax receivable - net	1,402	-3,103	7,512
Dividends received from subsidiaries	242,100	222,200	228,900
Other	-15,065	-4,589	19,270
Net cash flow provided by operating activities	204,096	219,123	229,498
Cash flows from investing activities	'	'	'
Investments in subsidiaries	-3,400	'	'
Repayments of loans from subsidiaries	2,149	996	61,143
Proceeds from sale of energy-related products and services business	'	'	45,111
Advances of loans to subsidiaries	-2,099	-1,200	-64,970
Proceeds from sale of life insurance policies	'	'	9,357
Net cash flow used for investing activities	-3,350	-204	50,641
Cash flows from financing activities	'	'	'
Issuance of long-term debt	'	125,000	175,000
Short-term borrowings and payments - net	'	'	-16,600
Dividends paid on common stock	-235,244	-225,075	-221,728
Repayment of long-term debt	'	-125,000	-225,000
Common stock equity issuance	17,319	15,955	15,841
Other	298	170	-2,667
Net cash flow used for financing activities	-217,627	-208,950	-275,154
NET DECREASE IN CASH AND CASH EQUIVALENTS	-16,881	9,969	4,985
CASH AND CASH EQUIVALENTS AT BEGINNING OF YEAR	22,679	12,710	7,725
CASH AND CASH EQUIVALENTS AT END OF YEAR	$5,798	$22,679	$12,710

SCHEDULE_II_RESERVE_FOR_UNCOLL1

SCHEDULE II - RESERVE FOR UNCOLLECTIBLES (Details) (Reserve for uncollectibles., Pinnacle West, USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Reserve for uncollectibles. \| Pinnacle West	'	'	'
Changes in reserve for uncollectibles	'	'	'
Balance at beginning of period	$3,340	$3,748	$4,709
Additions, Charged to cost and expenses	4,923	5,290	5,672
Deductions	5,060	5,698	6,633
Balance at end of period	$3,203	$3,340	$3,748

CONSOLIDATED_STATEMENTS_OF_INC2

CONSOLIDATED STATEMENTS OF INCOME (APSC) (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
OPERATING EXPENSES	'	'	'
Fuel and purchased power	$1,095,709	$994,790	$1,009,464
Operations and maintenance	924,727	884,769	904,286
Depreciation and amortization	415,708	404,336	427,054
Taxes other than income taxes	164,167	159,323	147,408
Total	2,608,305	2,450,049	2,494,871
OPERATING INCOME	846,323	851,755	746,508
OTHER INCOME (DEDUCTIONS)	'	'	'
Allowance for equity funds used during construction (Note 1)	25,581	22,436	23,707
Other income (Note S-3)	1,704	1,606	3,111
Other expense (Note S-3)	-16,024	-19,842	-10,451
Total	11,261	4,200	16,367
INTEREST EXPENSE	'	'	'
Allowance for borrowed funds used during construction (Note 1)	-14,861	-14,971	-18,358
Total	187,027	199,645	223,637
NET INCOME	439,966	413,164	366,940
Less: Net income attributable to noncontrolling interests (Note 19)	33,892	31,622	27,467
NET INCOME ATTRIBUTABLE TO COMMON SHAREHOLDERS	406,074	381,542	339,473
ARIZONA PUBLIC SERVICE COMPANY	'	'	'
ELECTRIC OPERATING REVENUES	3,451,251	3,293,489	3,237,241
OPERATING EXPENSES	'	'	'
Fuel and purchased power	1,095,709	994,790	1,009,464
Operations and maintenance	897,824	873,916	895,917
Depreciation and amortization	415,612	404,242	426,958
Income taxes (Notes 4 and S-1)	256,864	256,600	204,066
Taxes other than income taxes	163,377	158,412	146,453
Total	2,829,386	2,687,960	2,682,858
OPERATING INCOME	621,865	605,529	554,383
OTHER INCOME (DEDUCTIONS)	'	'	'
Income taxes (Notes 4 and S-1)	11,769	12,204	11,524
Allowance for equity funds used during construction (Note 1)	25,581	22,436	23,707
Other income (Note S-3)	3,896	2,868	5,071
Other expense (Note S-3)	-20,449	-21,150	-15,328
Total	20,797	16,358	24,974
INTEREST EXPENSE	'	'	'
Interest on long-term debt	188,011	198,398	218,981
Interest on short-term borrowings	6,605	7,135	10,345
Debt discount, premium and expense	4,046	4,215	4,616
Allowance for borrowed funds used during construction (Note 1)	-14,861	-14,971	-18,358
Total	183,801	194,777	215,584
NET INCOME	458,861	427,110	363,773
Less: Net income attributable to noncontrolling interests (Note 19)	33,892	31,613	27,524
NET INCOME ATTRIBUTABLE TO COMMON SHAREHOLDERS	$424,969	$395,497	$336,249

CONSOLIDATED_STATEMENTS_OF_COM2

CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (APSC) (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
NET INCOME	$439,966	$413,164	$366,940
Derivative instruments:	'	'	'
Net unrealized loss, net of tax benefit of $140, $14,888, and $37,397 (Note 17)	-213	-22,763	-57,271
Reclassification of net realized loss, net of tax benefit of $17,472, $39,119 and $46,298 (Note 17)	26,747	59,887	70,902
Pension and other postretirement benefits activity, net of tax (expense) benefit of $(6,003), $408 and $1,910 (Note 8)	9,421	1,031	-6,026
Total other comprehensive income	35,955	38,155	7,605
COMPREHENSIVE INCOME	475,921	451,319	374,545
Less: Comprehensive income attributable to noncontrolling interests	33,892	31,622	27,467
COMPREHENSIVE INCOME ATTRIBUTABLE TO COMMON SHAREHOLDERS	442,029	419,697	347,078
ARIZONA PUBLIC SERVICE COMPANY	'	'	'
NET INCOME	458,861	427,110	363,773
Derivative instruments:	'	'	'
Net unrealized loss, net of tax benefit of $140, $14,888, and $37,397 (Note 17)	-214	-22,775	-57,262
Reclassification of net realized loss, net of tax benefit of $17,472, $39,119 and $46,298 (Note 17)	26,747	59,888	70,891
Pension and other postretirement benefits activity, net of tax (expense) benefit of $(6,003), $408 and $1,910 (Note 8)	9,190	-617	-2,925
Total other comprehensive income	35,723	36,496	10,704
COMPREHENSIVE INCOME	494,584	463,606	374,477
Less: Comprehensive income attributable to noncontrolling interests	33,892	31,613	27,524
COMPREHENSIVE INCOME ATTRIBUTABLE TO COMMON SHAREHOLDERS	$460,692	$431,993	$346,953

CONSOLIDATED_STATEMENTS_OF_COM3

CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (APSC) (Parenthetical) (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Net unrealized loss, tax benefit	$140	$14,900	$37,389
Reclassification of net realized loss, tax benefit	17,472	39,120	46,288
Pension and other postretirement benefits activity, tax (expense) benefit	-6,156	-651	3,935
ARIZONA PUBLIC SERVICE COMPANY	'	'	'
Net unrealized loss, tax benefit	140	14,888	37,397
Reclassification of net realized loss, tax benefit	17,472	39,119	46,298
Pension and other postretirement benefits activity, tax (expense) benefit	($6,003)	$408	$1,910

CONSOLIDATED_BALANCE_SHEETS_AP

CONSOLIDATED BALANCE SHEETS (APSC) (USD $)	Dec. 31, 2013	Dec. 31, 2012
In Thousands, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012
PROPERTY, PLANT AND EQUIPMENT (Notes 1, 6 and 10)	'	'
Plant in service and held for future use	$15,200,464	$14,346,367
Accumulated depreciation and amortization	-5,300,219	-4,929,613
Net	9,900,245	9,416,754
Construction work in progress	581,369	565,716
Palo Verde sale leaseback, net of accumulated depreciation of $225,925 and $222,055 (Note 19)	125,125	128,995
Intangible assets, net of accumulated amortization of $439,703 and $411,543	157,689	162,150
Nuclear fuel, net of accumulated amortization of $146,057 and $133,950	124,557	122,778
Total property, plant and equipment	10,888,985	10,396,393
INVESTMENTS AND OTHER ASSETS	'	'
Nuclear decommissioning trust (Notes 14 and 20)	642,007	570,625
Assets from risk management activities (Note 17)	23,815	35,891
Other assets	60,875	62,694
Total investments and other assets	726,697	669,210
CURRENT ASSETS	'	'
Cash and cash equivalents	9,526	26,202
Customer and other receivables	299,904	277,225
Accrued unbilled revenues	96,796	94,845
Allowance for doubtful accounts	-3,203	-3,340
Materials and supplies (at average cost)	221,682	218,096
Fossil fuel (at average cost)	38,028	31,334
Income tax receivable	135,517	2,423
Assets from risk management activities (Note 17)	17,169	25,699
Deferred fuel and purchased power regulatory asset (Note 3)	20,755	72,692
Other regulatory assets (Note 3)	76,388	71,257
Deferred income taxes (Notes 4 and S-1)	91,152	152,191
Other current assets	39,895	37,102
Total current assets	1,043,609	1,005,726
DEFERRED DEBITS	'	'
Regulatory assets (Notes 1, 3, 4 and S-1)	711,712	1,099,900
Income tax receivable (Notes 4 and S-1)	'	70,389
Other	137,683	137,997
Total deferred debits	849,395	1,308,286
TOTAL ASSETS	13,508,686	13,379,615
CAPITALIZATION	'	'
Common stock	2,487,250	2,462,712
Retained earnings	1,785,273	1,624,102
Accumulated other comprehensive (loss):	'	'
Pension and other postretirement benefits (Note 8)	-54,995	-64,416
Derivative instruments (Note 17)	-23,058	-49,592
Total shareholders' equity	4,194,470	3,972,806
Noncontrolling interests (Note 19)	145,990	129,483
Total equity	4,340,460	4,102,289
Long-term debt less current maturities (Note 6)	'	3,160,219
CURRENT LIABILITIES	'	'
Short-term borrowings (Note 5)	153,125	92,175
Current maturities of long-term debt (Note 6)	540,424	122,828
Accounts payable	284,516	221,312
Accrued taxes (Notes 4 and S-1)	130,998	124,939
Accrued interest	48,351	49,380
Common dividends payable	62,528	59,789
Customer deposits	76,101	79,689
Liabilities from risk management activities (Note 17)	31,892	73,741
Regulatory liabilities (Note 3)	99,273	88,116
Other current liabilities	158,540	171,573
Total current liabilities	1,618,644	1,083,542
DEFERRED CREDITS AND OTHER	'	'
Deferred income taxes (Notes 4 and S-1)	2,351,882	2,151,371
Regulatory liabilities (Notes 1, 3, 4, and S-1)	801,297	759,201
Liability for asset retirements (Note 12)	313,833	357,097
Liabilities for pension and other postretirement benefits (Note 8)	513,628	1,058,755
Liabilities from risk management activities (Note 17)	70,315	85,264
Customer advances	114,480	109,359
Coal mine reclamation	207,453	118,860
Deferred investment tax credit	152,361	99,819
Unrecognized tax benefits (Notes 4 and S-1)	42,209	71,135
Other	185,659	183,835
Total deferred credits and other	4,753,117	4,994,696
COMMITMENTS AND CONTINGENCIES (SEE NOTES)	'	'
TOTAL LIABILITIES AND EQUITY	13,508,686	13,379,615
ARIZONA PUBLIC SERVICE COMPANY	'	'
PROPERTY, PLANT AND EQUIPMENT (Notes 1, 6 and 10)	'	'
Plant in service and held for future use	15,196,598	14,342,501
Accumulated depreciation and amortization	-5,296,501	-4,925,990
Net	9,900,097	9,416,511
Construction work in progress	581,369	565,716
Palo Verde sale leaseback, net of accumulated depreciation of $225,925 and $222,055 (Note 19)	125,125	128,995
Intangible assets, net of accumulated amortization of $439,703 and $411,543	157,534	161,995
Nuclear fuel, net of accumulated amortization of $146,057 and $133,950	124,557	122,778
Total property, plant and equipment	10,888,682	10,395,995
INVESTMENTS AND OTHER ASSETS	'	'
Nuclear decommissioning trust (Notes 14 and 20)	642,007	570,625
Assets from risk management activities (Note 17)	23,815	35,891
Other assets	33,709	31,650
Total investments and other assets	699,531	638,166
CURRENT ASSETS	'	'
Cash and cash equivalents	3,725	3,499
Customer and other receivables	299,055	274,815
Accrued unbilled revenues	96,796	94,845
Allowance for doubtful accounts	-3,203	-3,340
Materials and supplies (at average cost)	221,682	218,096
Fossil fuel (at average cost)	38,028	31,334
Income tax receivable	135,179	589
Assets from risk management activities (Note 17)	17,169	25,699
Deferred fuel and purchased power regulatory asset (Note 3)	20,755	72,692
Other regulatory assets (Note 3)	76,388	71,257
Deferred income taxes (Notes 4 and S-1)	-2,033	74,420
Deferred income taxes (Notes 4 and S-1)	0	74,420
Other current assets	39,153	37,077
Total current assets	944,727	900,983
DEFERRED DEBITS	'	'
Regulatory assets (Notes 1, 3, 4 and S-1)	711,712	1,099,900
Income tax receivable (Notes 4 and S-1)	'	70,784
Unamortized debt issue costs	21,860	22,492
Other	114,865	114,222
Total deferred debits	848,437	1,307,398
TOTAL ASSETS	13,381,377	13,242,542
CAPITALIZATION	'	'
Common stock	178,162	178,162
Additional paid-in capital	2,379,696	2,379,696
Retained earnings	1,804,398	1,624,237
Accumulated other comprehensive (loss):	'	'
Pension and other postretirement benefits (Note 8)	-30,313	-39,503
Derivative instruments (Note 17)	-23,059	-49,592
Total shareholders' equity	4,308,884	4,093,000
Noncontrolling interests (Note 19)	145,990	129,483
Total equity	4,454,874	4,222,483
Long-term debt less current maturities (Note 6)	2,671,465	3,074,088
Total capitalization	7,126,339	7,296,571
CURRENT LIABILITIES	'	'
Short-term borrowings (Note 5)	153,125	92,175
Current maturities of long-term debt (Note 6)	540,424	122,828
Accounts payable	281,237	215,577
Accrued taxes (Notes 4 and S-1)	122,460	116,700
Accrued interest	48,132	49,135
Common dividends payable	62,500	59,800
Customer deposits	76,101	79,689
Deferred income taxes	2,033	'
Liabilities from risk management activities (Note 17)	31,892	73,741
Liabilities for asset retirements (Note 12)	32,896	'
Regulatory liabilities (Note 3)	99,273	88,116
Other current liabilities	130,774	145,326
Total current liabilities	1,580,847	1,043,087
DEFERRED CREDITS AND OTHER	'	'
Deferred income taxes (Notes 4 and S-1)	2,347,724	2,133,976
Regulatory liabilities (Notes 1, 3, 4, and S-1)	801,297	759,201
Liability for asset retirements (Note 12)	313,833	357,097
Liabilities for pension and other postretirement benefits (Note 8)	476,017	1,017,556
Liabilities from risk management activities (Note 17)	70,315	85,264
Customer advances	114,480	109,359
Coal mine reclamation	207,453	118,860
Deferred investment tax credit	152,361	99,819
Unrecognized tax benefits (Notes 4 and S-1)	42,209	70,932
Other	148,502	150,820
Total deferred credits and other	4,674,191	4,902,884
TOTAL LIABILITIES AND EQUITY	$13,381,377	$13,242,542

CONSOLIDATED_BALANCE_SHEETS_AP1

CONSOLIDATED BALANCE SHEETS (APSC) (Parenthetical) (USD $)	Dec. 31, 2013	Dec. 31, 2012
In Thousands, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012
PROPERTY, PLANT AND EQUIPMENT (Notes 1, 6, and 10)	'	'
Accumulated depreciation of Palo Verde sale leaseback	$225,925	$222,055
Accumulated amortization on intangible assets	439,703	411,543
Accumulated amortization on nuclear fuel	146,057	133,950
ARIZONA PUBLIC SERVICE COMPANY	'	'
PROPERTY, PLANT AND EQUIPMENT (Notes 1, 6, and 10)	'	'
Accumulated depreciation of Palo Verde sale leaseback	225,925	222,055
Accumulated amortization on intangible assets	439,703	411,543
Accumulated amortization on nuclear fuel	$146,057	$133,950

CONSOLIDATED_STATEMENTS_OF_CAS1

CONSOLIDATED STATEMENTS OF CASH FLOWS (APSC) (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
CASH FLOWS FROM OPERATING ACTIVITIES	'	'	'
Net income	$439,966	$413,164	$366,940
Adjustments to reconcile net income to net cash provided by operating activities:	'	'	'
Depreciation and amortization including nuclear fuel	492,322	481,262	493,784
Deferred fuel and purchased power	21,678	71,573	69,166
Deferred fuel and purchased power amortization	31,190	-116,716	-155,157
Allowance for equity funds used during construction	-25,581	-22,436	-23,707
Deferred income taxes	249,296	187,023	117,952
Deferred investment tax credit	52,542	41,579	58,240
Change in derivative instruments fair value	534	-749	4,064
Changes in current assets and liabilities:	'	'	'
Customer and other receivables	-44,991	14,587	40,626
Accrued unbilled revenues	-1,951	30,394	-21,947
Materials, supplies and fossil fuel	-11,878	-23,043	-23,398
Income tax receivable	-133,094	-4,043	3,983
Other current assets	-17,913	-27,352	-3,079
Accounts payable	45,414	-96,600	58,346
Accrued taxes	6,059	12,736	8,085
Other current liabilities	-7,513	23,869	20,358
Change in margin and collateral accounts - assets	993	2,216	33,349
Change in margin and collateral accounts - liabilities	12,355	137,785	29,731
Change in long-term regulatory liabilities	64,473	13,539	37,009
Change in long-term income tax receivable	137,270	-1,756	-3,530
Change in unrecognized tax benefits	-91,425	-2,583	8,410
Change in other long-term assets	-41,757	6,872	-41,722
Change in other long-term liabilities	-24,682	29,801	58,484
Net cash flow provided by operating activities	1,153,307	1,171,122	1,125,583
CASH FLOWS FROM INVESTING ACTIVITIES	'	'	'
Capital expenditures	-1,016,322	-889,551	-884,350
Contributions in aid of construction	41,090	49,876	38,096
Allowance for borrowed funds used during construction	-14,861	-14,971	-18,358
Proceeds from nuclear decommissioning trust sales	446,025	417,603	497,780
Investment in nuclear decommissioning trust	-463,274	-434,852	-513,799
Proceeds from sale of life insurance policies	'	'	55,444
Other	-2,059	-1,099	-1,931
Net cash flow used for investing activities	-1,009,401	-872,994	-782,007
CASH FLOWS FROM FINANCING ACTIVITIES	'	'	'
Issuance of long-term debt	136,307	476,081	470,353
Repayment of long-term debt	-122,828	-654,286	-655,169
Short-term borrowings and payments - net	60,950	92,175	-16,600
Dividends paid on common stock	-235,244	-225,075	-221,728
Noncontrolling interests	-17,385	-10,529	-10,210
Net cash flow used for financing activities	-160,582	-305,509	-420,181
NET DECREASE IN CASH AND CASH EQUIVALENTS	-16,676	-7,381	-76,605
CASH AND CASH EQUIVALENTS AT BEGINNING OF YEAR	26,202	33,583	110,188
CASH AND CASH EQUIVALENTS AT END OF YEAR	9,526	26,202	33,583
Cash paid during the year for:	'	'	'
Income taxes, net of refunds	18,537	2,543	10,324
Interest, net of amounts capitalized	184,010	200,923	217,789
Significant non-cash investing and financing activities:	'	'	'
Accrued capital expenditures	33,184	26,208	27,245
Dividends declared but not paid	62,528	59,789	'
Liabilities assumed related to acquisition of SCE's Four Corners' interest	145,609	'	'
ARIZONA PUBLIC SERVICE COMPANY	'	'	'
CASH FLOWS FROM OPERATING ACTIVITIES	'	'	'
Net income	458,861	427,110	363,773
Adjustments to reconcile net income to net cash provided by operating activities:	'	'	'
Depreciation and amortization including nuclear fuel	492,226	481,168	493,653
Deferred fuel and purchased power	21,678	71,573	69,166
Deferred fuel and purchased power amortization	31,190	-116,716	-155,157
Allowance for equity funds used during construction	-25,581	-22,436	-23,707
Deferred income taxes	278,101	202,159	110,565
Deferred investment tax credit	52,542	41,579	58,240
Change in derivative instruments fair value	534	-749	4,064
Changes in current assets and liabilities:	'	'	'
Customer and other receivables	-46,552	12,914	34,913
Accrued unbilled revenues	-1,951	30,394	-21,947
Materials, supplies and fossil fuel	-11,878	-23,043	-23,398
Income tax receivable	-134,590	-2,280	2,869
Other current assets	-17,112	-27,745	-5,473
Accounts payable	47,870	-97,395	73,369
Accrued taxes	5,760	7,330	2,234
Other current liabilities	-9,005	6,070	18,762
Change in margin and collateral accounts - assets	993	2,216	33,349
Change in margin and collateral accounts - liabilities	12,355	137,785	29,731
Change in long-term regulatory liabilities	64,473	13,539	37,009
Change in long-term income tax receivable	137,665	-1,756	-3,530
Change in unrecognized tax benefits	-91,244	-2,583	9,125
Change in other long-term assets	-46,043	1,391	-41,788
Change in other long-term liabilities	-25,601	34,854	61,990
Net cash flow provided by operating activities	1,194,691	1,175,379	1,127,812
CASH FLOWS FROM INVESTING ACTIVITIES	'	'	'
Capital expenditures	-1,016,322	-889,551	-878,546
Contributions in aid of construction	41,090	49,876	38,096
Allowance for borrowed funds used during construction	-14,861	-14,971	-18,358
Proceeds from nuclear decommissioning trust sales	446,025	417,603	497,780
Investment in nuclear decommissioning trust	-463,274	-434,852	-513,799
Proceeds from sale of life insurance policies	'	'	44,183
Other	-2,067	-1,099	-3,306
Net cash flow used for investing activities	-1,009,409	-872,994	-833,950
CASH FLOWS FROM FINANCING ACTIVITIES	'	'	'
Issuance of long-term debt	136,307	351,081	295,353
Repayment of long-term debt	-122,828	-529,286	-430,169
Short-term borrowings and payments - net	60,950	92,175	'
Dividends paid on common stock	-242,100	-222,200	-228,900
Noncontrolling interests	-17,385	-10,529	-10,210
Net cash flow used for financing activities	-185,056	-318,759	-373,926
NET DECREASE IN CASH AND CASH EQUIVALENTS	226	-16,374	-80,064
CASH AND CASH EQUIVALENTS AT BEGINNING OF YEAR	3,499	19,873	99,937
CASH AND CASH EQUIVALENTS AT END OF YEAR	3,725	3,499	19,873
Cash paid during the year for:	'	'	'
Income taxes, net of refunds	7,524	1,196	25,975
Interest, net of amounts capitalized	180,757	196,038	210,995
Significant non-cash investing and financing activities:	'	'	'
Accrued capital expenditures	33,184	26,208	27,245
Dividends declared but not paid	62,500	59,800	'
Liabilities assumed related to acquisition of SCE's Four Corners' interest	$145,609	'	'

CONSOLIDATED_STATEMENTS_OF_CHA2

CONSOLIDATED STATEMENTS OF CHANGES IN EQUITY (APSC) (USD $)

Total

ARIZONA PUBLIC SERVICE COMPANY

COMMON STOCK

ADDITIONAL PAID-IN CAPITAL

RETAINED EARNINGS

ACCUMULATED OTHER COMPREHENSIVE INCOME (LOSS)

NONCONTROLLING INTERESTS

COMPREHENSIVE INCOME ATTRIBUTABLE TO COMMON SHAREHOLDER

In Thousands, unless otherwise specified

ARIZONA PUBLIC SERVICE COMPANY

Balance at Dec. 31, 2010

$2,421,372

$1,423,961

$1,403,390

($159,767)

($136,295)

$91,899

$91,084

Increase (Decrease) in Shareholders' Equity

Net income attributable to common shareholders

339,473

336,249

339,473

336,249

339,473

336,249

Dividends on common stock

-228,951

-228,900

Net income attributable to noncontrolling interests

27,467

27,524

-27,467

27,524

COMPREHENSIVE INCOME ATTRIBUTABLE TO COMMON SHAREHOLDER

Other comprehensive income attributable to common shareholders

7,605

10,704

7,604

10,704

7,605

10,704

Total comprehensive income attributable to common shareholders

347,078

346,953

347,078

346,953

Net capital activities by noncontrolling interests

-10,630

-10,209

Other

Balance at Dec. 31, 2011

3,930,586

4,051,406

2,444,247

178,162

2,379,696

1,534,483

1,510,740

-152,163

-125,591

108,736

108,399

Increase (Decrease) in Shareholders' Equity

Net income attributable to common shareholders

-8,257

-4,105

Balance at Mar. 31, 2012

Balance at Dec. 31, 2011

3,930,586

4,051,406

2,444,247

178,162

2,379,696

1,534,483

1,510,740

-152,163

-125,591

108,736

108,399

Increase (Decrease) in Shareholders' Equity

Net income attributable to common shareholders

381,542

395,497

381,542

395,497

381,542

395,497

Dividends on common stock

-291,923

-282,000

Net income attributable to noncontrolling interests

31,622

31,613

-31,622

31,613

COMPREHENSIVE INCOME ATTRIBUTABLE TO COMMON SHAREHOLDER

Other comprehensive income attributable to common shareholders

38,155

36,496

38,155

36,496

38,155

36,496

Total comprehensive income attributable to common shareholders

419,697

431,993

419,697

431,993

Net capital activities by noncontrolling interests

-10,875

-10,529

Balance at Dec. 31, 2012

4,102,289

4,222,483

2,466,923

178,162

2,379,696

1,624,102

1,624,237

-114,008

-89,095

129,483

Balance at Sep. 30, 2012

Increase (Decrease) in Shareholders' Equity

Net income attributable to common shareholders

22,631

26,843

Balance at Dec. 31, 2012

4,102,289

4,222,483

2,466,923

178,162

2,379,696

Increase (Decrease) in Shareholders' Equity

Net income attributable to common shareholders

24,444

26,042

Balance at Mar. 31, 2013

Balance at Dec. 31, 2012

4,102,289

4,222,483

2,466,923

178,162

2,379,696

1,624,102

1,624,237

-114,008

-89,095

129,483

Increase (Decrease) in Shareholders' Equity

Net income attributable to common shareholders

406,074

424,969

406,074

424,969

406,074

424,969

Dividends on common stock

-244,903

-244,800

Net income attributable to noncontrolling interests

33,892

-33,892

33,892

COMPREHENSIVE INCOME ATTRIBUTABLE TO COMMON SHAREHOLDER

Other comprehensive income attributable to common shareholders

35,955

35,723

35,955

35,723

35,955

35,723

Total comprehensive income attributable to common shareholders

442,029

460,692

442,029

460,692

Net capital activities by noncontrolling interests

-17,385

Other

-8

Balance at Dec. 31, 2013

4,340,460

4,454,874

2,491,558

178,162

2,379,696

1,785,273

1,804,398

-78,053

-53,372

145,990

Balance at Sep. 30, 2013

Increase (Decrease) in Shareholders' Equity

Net income attributable to common shareholders

24,260

30,024

Balance at Dec. 31, 2013

$4,340,460

$4,454,874

$2,491,558

$178,162

$2,379,696

Income_Taxes_APSC

Income Taxes (APSC)	12 Months Ended
Income Taxes (APSC)	Dec. 31, 2013
Income Taxes	'
	4. Income Taxes

	Certain assets and liabilities are reported differently for income tax purposes than they are for financial statement purposes. The tax effect of these differences is recorded as deferred taxes. We calculate deferred taxes using currently enacted income tax rates.

	APS has recorded regulatory assets and regulatory liabilities related to income taxes on its Balance Sheets in accordance with accounting guidance for regulated operations. The regulatory assets are for certain temporary differences, primarily the allowance for equity funds used during construction and pension and other postretirement benefits. The regulatory liabilities primarily relate to deferred taxes resulting from investment tax credits (“ITC”) and the change in income tax rates.

	In accordance with regulatory requirements, APS ITCs are deferred and are amortized over the life of the related property with such amortization applied as a credit to reduce current income tax expense in the statement of income.

	The $70 million long-term income tax receivable on the Consolidated Balance Sheets as of December 31, 2012 represented the anticipated refund related to an APS tax accounting method change approved by the IRS in the third quarter of 2009. On July 9, 2013, IRS guidance was released which provided clarification regarding the timing and amount of this cash receipt. As a result of this guidance, uncertain tax positions decreased $67 million during the third quarter. This decrease in uncertain tax positions resulted in a corresponding increase to the total anticipated refund due from the IRS and an offsetting increase in long-term deferred tax liabilities. Additionally, as a result of this IRS guidance, the resulting $137 million anticipated refund was reclassified to current income tax receivable.

	During the year ended December 31, 2013, the IRS finalized the examination of tax returns for the years ended December 31, 2008 and 2009, and the $137 million anticipated refund was reduced by approximately $4 million to reflect the outcome of this examination. On December 17, 2013, the Joint Committee on Taxation approved the anticipated refund. Cash related to this refund was received in the first quarter of 2014.

	On September 13, 2013, the U.S. Treasury Department released final income tax regulations on the deduction and capitalization of expenditures related to tangible property. These final regulations apply to tax years beginning on or after January 1, 2014. Several of the provisions within the regulations will require a tax accounting method change to be filed with the IRS, resulting in a cumulative effect adjustment. To account for the adoption of these regulations, plant-related long-term deferred tax liabilities decreased by $84 million, with the offsetting decrease to current deferred income tax assets. Prior to the issuance of these regulations, this $84 million would have been repaid over 20 years through lower tax depreciation deductions.

	Net income associated with the Palo Verde sale leaseback VIEs is not subject to tax (see Note 19). As a result, there is no income tax expense associated with the VIEs recorded on the Consolidated Statements of Income.

	The following is a tabular reconciliation of the total amounts of unrecognized tax benefits, excluding interest and penalties, at the beginning and end of the year that are included in accrued taxes and unrecognized tax benefits (dollars in thousands):

			2013			2012			2011
	Total unrecognized tax benefits, January 1		$	133,422		$	136,005		$	127,595
	Additions for tax positions of the current year		3,516			5,167			10,915
	Additions for tax positions of prior years		13,158			—			—
	Reductions for tax positions of prior years for:
	Changes in judgment		(108,099		)	(7,729		)	(1,555		)
	Settlements with taxing authorities		—			—			(124		)
	Lapses of applicable statute of limitations		—			(21		)	(826		)
	Total unrecognized tax benefits, December 31		$	41,997		$	133,422		$	136,005

	Included in the balances of unrecognized tax benefits at December 31, 2013, 2012 and 2011 were approximately $10 million, $10 million and $8 million, respectively, of tax positions that, if recognized, would decrease our effective tax rate.

	As of the balance sheet date, the tax year ended December 31, 2010 and all subsequent tax years remain subject to examination by the IRS. With a few exceptions, we are no longer subject to state income tax examinations by tax authorities for years before 2010.

	We reflect interest and penalties, if any, on unrecognized tax benefits in the Consolidated Statements of Income as income tax expense. The amount of interest recognized in the Consolidated Statements of Income related to unrecognized tax benefits was a pre-tax benefit of $4 million for 2013, a pre-tax expense of $4 million for 2012, and a pre-tax expense of $3 million for 2011.

	The total amount of accrued liabilities for interest recognized in the Consolidated Balance Sheets related to unrecognized tax benefits was less than $1 million as of December 31, 2013, $13 million as of December 31, 2012 and $9 million as of December 31, 2011. To the extent that matters are settled favorably, this amount could reverse and decrease our effective tax rate. Additionally, as of December 31, 2013, we have recognized $5 million of interest income to be received on the overpayment of income taxes for certain adjustments that we have filed, or will file, with the IRS.

	The components of income tax expense are as follows (dollars in thousands):

			Year Ended December 31,
			2013			2012			2011
	Current:
	Federal		$	(81,784	)	$	(3,493	)	$	(310	)
	State		10,537			8,395			15,140
	Total current		(71,247		)	4,902			14,830
	Deferred:
	Federal		279,973			200,322			159,566
	State		21,865			28,280			16,626
	Total deferred		301,838			228,602			176,192
	Total income tax expense		230,591			233,504			191,022
	Less: income tax expense (benefit) on discontinued operations		—			(3,813		)	7,418
	Income tax expense — continuing operations		$	230,591		$	237,317		$	183,604

	The following chart compares pretax income from continuing operations at the 35% federal income tax rate to income tax expense — continuing operations (dollars in thousands):

			Year Ended December 31,
			2013			2012			2011

	Federal income tax expense at 35% statutory rate		$	234,695		$	229,709		$	188,733
	Increases (reductions) in tax expense resulting from:
	State income tax net of federal income tax benefit		21,387			23,819			19,594
	Credits and favorable adjustments related to prior years resolved in current year		(3,356		)	—			—
	Medicare Subsidy Part-D		823			483			823
	Allowance for equity funds used during construction (see Note 1)		(6,997		)	(6,158		)	(6,881		)
Palo Verde VIE noncontrolling interest (see Note 19)		(11,862		)	(11,065		)	(9,636		)
Other		(4,099		)	529			(9,029		)
Income tax expense — continuing operations		$	230,591		$	237,317		$	183,604

The following table shows the net deferred income tax liability recognized on the Consolidated Balance Sheets (dollars in thousands):

		December 31,
		2013			2012
Current asset		$	91,152		$	152,191
Long-term liability		(2,351,882		)	(2,151,371		)
Deferred income taxes — net		$	(2,260,730	)	$	(1,999,180	)

On February 17, 2011, Arizona enacted legislation (H.B. 2001) that included a four-year phase-in of corporate income tax rate reductions beginning in 2014. As a result of these tax rate reductions, Pinnacle West has revised the tax rate applicable to reversing temporary items in Arizona. In accordance with accounting for regulated companies, the benefit of this rate reduction is substantially offset by a regulatory liability. As of December 31, 2013 APS has recorded a regulatory liability of $75 million, with a corresponding decrease in accumulated deferred income tax liabilities, to reflect the impact of this change in tax law.

On April 4, 2013, New Mexico enacted legislation (H.B. 641) that included a five-year phase-in of corporate income tax rate reductions beginning in 2014. As a result of these tax rate reductions, Pinnacle West has revised the tax rate applicable to reversing temporary items in New Mexico. In accordance with accounting for regulated companies, the benefit of this rate reduction is substantially offset by a regulatory liability. As of December 31, 2013, APS has recorded a regulatory liability of $2 million, with a corresponding decrease in accumulated deferred income tax liabilities, to reflect the impact of this change in tax law.

The components of the net deferred income tax liability were as follows (dollars in thousands):

		December 31,
		2013			2012
DEFERRED TAX ASSETS
Risk management activities		$	44,920		$	72,243
Regulatory liabilities:
Asset retirement obligation and removal costs		235,959			238,669
Unamortized investment tax credits		82,116			53,837
Other		42,609			33,764
Pension and other postretirement liabilities		198,642			408,764
Renewable energy incentives		65,434			66,941
Credit and loss carryforwards		133,070			139,022
Other		148,492			68,844
Total deferred tax assets		951,242			1,082,084
DEFERRED TAX LIABILITIES
Plant-related		(2,903,730		)	(2,584,166		)
Risk management activities		(16,191		)	(23,940		)
Regulatory assets:
Allowance for equity funds used during construction		(43,058		)	(37,899		)
Deferred fuel and purchased power		(8,282		)	(28,858		)
Deferred fuel and purchased power — mark-to-market		(13,343		)	(15,796		)
Pension and other postretirement benefits		(129,250		)	(316,757		)
Other		(93,202		)	(68,170		)
Other		(4,916		)	(5,678		)
Total deferred tax liabilities		(3,211,972		)	(3,081,264		)
Deferred income taxes — net		$	(2,260,730	)	$	(1,999,180	)

As of December 31, 2013, the deferred tax assets for credit and loss carryforwards relate to federal general business credits of $131 million which first begin to expire in 2031, and other federal and state loss carryforwards of $2 million which first begin to expire in 2018.

ARIZONA PUBLIC SERVICE COMPANY	'
Income Taxes	'
	S-1. Income Taxes

	APS is included in Pinnacle West’s consolidated tax return. However, when Pinnacle West allocates income taxes to APS, it is done based upon APS’s taxable income computed on a stand-alone basis, in accordance with the tax sharing agreement.

	Certain assets and liabilities are reported differently for income tax purposes than they are for financial statements purposes. The tax effect of these differences is recorded as deferred taxes. We calculate deferred taxes using currently enacted tax rates.

	APS has recorded regulatory assets and regulatory liabilities related to income taxes on its Balance Sheets in accordance with accounting guidance for regulated operations. The regulatory assets are for certain temporary differences, primarily the allowance for equity funds used during construction and pension and other postretirement benefits. The regulatory liabilities primarily relate to deferred taxes resulting from ITCs and the change in income tax rates.

	In accordance with regulatory requirements, APS ITCs are deferred and are amortized over the life of the related property, with such amortization applied as a credit to reduce current income tax expense in the statement of income.

	The $71 million long-term income tax receivable on APS’s Consolidated Balance Sheets as of December 31, 2012 represented the anticipated refund related to an APS tax accounting method change approved by the IRS in the third quarter of 2009. On July 9, 2013, IRS guidance was released which provided clarification regarding the timing and amount of this cash receipt. As a result of this guidance, uncertain tax positions decreased $67 million during the third quarter. This decrease in uncertain tax positions resulted in a corresponding increase to the total anticipated refund due from the IRS and an offsetting increase in long-term deferred tax liabilities. Additionally, as a result of this IRS guidance, the $138 million anticipated refund was reclassified to current income tax receivable.

	During the year ended December 31, 2013, the IRS finalized the examination of tax returns for the years ended December 31, 2008 and 2009, and the $138 million anticipated refund was reduced by approximately $2 million to reflect the outcome of this examination. On December 17, 2013, the Joint Committee on Taxation approved the anticipated refund. Cash related to this refund was received in the first quarter of 2014.

	On September 13, 2013, the U.S. Treasury Department released final income tax regulations on the deduction and capitalization of expenditures related to tangible property. These final regulations apply to tax years beginning on or after January 1, 2014. Several of the provisions within the regulations will require a tax accounting method change to be filed with the IRS resulting in a cumulative effect adjustment. To account for the adoption of these regulations plant-related long-term deferred tax liabilities decreased by $84 million, with the offsetting decrease to current deferred income tax assets. Prior to the issuance of these regulations, this $84 million would have been repaid over 20 years through lower tax depreciation deductions.

	Net income associated with the Palo Verde sale leaseback VIEs is not subject to tax (see Note 19). As a result, there is no income tax expense associated with the VIEs recorded on APS’s Consolidated Statements of Income.

	The following is a tabular reconciliation of the total amounts of unrecognized tax benefits, excluding interest and penalties, at the beginning and end of the year that are included in accrued taxes and unrecognized tax benefits (dollars in thousands):

			2013			2012			2011
	Total unrecognized tax benefits, January 1		$	133,241		$	135,824		$	126,698
	Additions for tax positions of the current year		3,516			5,167			10,915
	Additions for tax positions of prior years		13,158			—			—
	Reductions for tax positions of prior years for:
	Changes in judgment		(107,918		)	(7,729		)	(1,555		)
	Settlements with taxing authorities		—			—			(124		)
	Lapses of applicable statute of limitations		—			(21		)	(110		)
	Total unrecognized tax benefits, December 31		$	41,997		$	133,241		$	135,824

	Included in the balance of unrecognized tax benefits at December 31, 2013, 2012 and 2011 were approximately $10 million, $10 million and $8 million, respectively, of tax positions that, if recognized, would decrease our effective tax rate.

	As of the balance sheet date, the tax year ended December 31, 2010 and all subsequent tax years remain subject to examination by the IRS. With a few exceptions, we are no longer subject to state income tax examinations by tax authorities for years before 2010.

	We reflect interest and penalties, if any, on unrecognized tax benefits in the Statements of Income as income tax expense. The amount of interest recognized in the Statements of Income related to unrecognized tax benefits was a pre-tax benefit of $4 million for 2013, a pre-tax expense of $4 million for 2012 and a pre-tax expense of $3 million for 2011.

	The total amount of accrued liabilities for interest recognized in the Balance Sheets related to unrecognized tax benefits was less than $1 million as of December 31, 2013, $13 million as of December 31, 2012 and $9 million as of December 31, 2011. To the extent that matters are settled favorably, this amount could be reversed and decrease our effective tax rate. Additionally, as of December 31, 2013, we have recognized $5 million of interest income to be received on the overpayment of income taxes for certain adjustments that we have filed, or will file, with the IRS.

	The components of APS’s income tax expense are as follows (dollars in thousands):

			Year Ended December 31,
			2013			2012			2011
	Current:
	Federal		$	(97,531	)	$	(11,650	)	$	4,633
	State		11,983			12,308			19,104
	Total current		(85,548		)	658			23,737
	Deferred:
	Federal		305,389			216,367			154,632
	State		25,254			27,371			14,173
	Total deferred		330,643			243,738			168,805
	Total income tax expense		$	245,095		$	244,396		$	192,542

	On the APS Statements of Income, federal and state income taxes are allocated between operating income and other income.

	The following chart compares APS’s pretax income at the 35% federal income tax rate to income tax expense (dollars in thousands):

			Year Ended December 31,
			2013			2012			2011

	Federal income tax expense at 35% statutory rate		$	246,384		$	235,027		$	194,710
	Increases (reductions) in tax expense resulting from:
	State income tax net of federal income tax benefit		23,970			25,379			21,139
	Credits and favorable adjustments related to prior years resolved in current year		(3,231		)	—			—
Medicare Subsidy Part-D		823			483			823
Allowance for equity funds used during construction (see Note 1)		(6,997		)	(6,158		)	(6,880		)
Palo Verde VIE noncontrolling interest (see Note 19)		(11,862		)	(11,065		)	(9,633		)
Other		(3,992		)	730			(7,617		)
Income tax expense		$	245,095		$	244,396		$	192,542

The following table shows the net deferred income tax liability recognized on the APS Balance Sheets (dollars in thousands):

		December 31,
		2013			2012
Current asset (liability)		$	(2,033	)	$	74,420
Long-term liability		(2,347,724		)	(2,133,976		)
Deferred income taxes — net		$	(2,349,757	)	$	(2,059,556	)

On February 17, 2011, Arizona enacted legislation (H.B. 2001) that included a four-year phase-in of corporate income tax rate reductions beginning in 2014. As a result of these tax rate reductions, Pinnacle West has revised the tax rate applicable to reversing temporary items in Arizona. In accordance with accounting for regulated companies, the benefit of this rate reduction is substantially offset by a regulatory liability. As of December 31, 2013, APS has recorded a regulatory liability of $75 million, with a corresponding decrease in accumulated deferred income tax liabilities, to reflect the impact of this change in tax law.

On April 4, 2013, New Mexico enacted legislation (H.B. 641) that included a five-year phase-in of corporate income tax rate reductions beginning in 2014. As a result of these tax rate reductions, Pinnacle West has revised the tax rate applicable to reversing temporary items in New Mexico. In accordance with accounting for regulated companies, the benefit of this rate reduction is substantially offset by a regulatory liability. As of December 31, 2013, APS has recorded a regulatory liability of $2 million, with a corresponding decrease in accumulated deferred income tax liabilities, to reflect the impact of this change in tax law.

The components of the net deferred income tax liability were as follows (dollars in thousands):

		December 31,
		2013			2012
DEFERRED TAX ASSETS
Regulatory liabilities:
Asset retirement obligation and removal costs		$	235,959		$	238,669
Unamortized investment tax credits		82,116			53,837
Other		42,609			33,764
Risk management activities		44,920			72,243
Pension and other postretirement liabilities		186,213			392,486
Renewable energy incentives		65,434			66,941
Credit and loss carryforwards		38,183			52,441
Other		166,781			111,327
Total deferred tax assets		862,215			1,021,708
DEFERRED TAX LIABILITIES
Plant-related		(2,903,730		)	(2,584,166		)
Risk management activities		(16,191		)	(23,940		)
Regulatory assets:
Allowance for equity funds used during construction		(43,058		)	(37,899		)
Deferred fuel and purchased power		(8,282		)	(28,858		)
Deferred fuel and purchased power — mark-to-market		(13,343		)	(15,796		)
Pension and other postretirement benefits		(129,250		)	(316,757		)
Other		(93,202		)	(68,170		)
Other		(4,916		)	(5,678		)
Total deferred tax liabilities		(3,211,972		)	(3,081,264		)
Deferred income taxes — net		$	(2,349,757	)	$	(2,059,556	)

As of December 31, 2013, the deferred tax assets for credit and loss carryforwards relate primarily to federal general business credits which first begin to expire in 2031.

Selected_Quarterly_Financial_D3

Selected Quarterly Financial Data (Unaudited) (APSC)	12 Months Ended
	Dec. 31, 2013
Selected Quarterly Financial Data (Unaudited)	'
	13. Selected Quarterly Financial Data (Unaudited)

	Consolidated quarterly financial information for 2013 and 2012 is provided in the tables below (dollars in thousands, except per share amounts). Weather conditions cause significant seasonal fluctuations in our revenues; therefore, results for interim periods do not necessarily represent results expected for the year.

		2013 Quarter Ended									2013
		March 31,			June 30,		Sept. 30,		Dec. 31,		Total

	Operating revenues	$	686,652		$	915,822	$	1,152,392	$	699,762	$	3,454,628
	Operations and maintenance	223,250			229,300		233,323		238,854		924,727
	Operating income	86,923			259,812		415,688		83,900		846,323
	Income taxes	12,469			77,043		131,912		9,167		230,591
	Income from continuing operations	32,836			139,598		234,718		32,814		439,966
	Net income attributable to common shareholders	24,444			131,207		226,163		24,260		406,074

	Earnings Per Share:
	Income from continuing operations attributable to common shareholders — Basic	$	0.22		$	1.19	$	2.06	$	0.22	$	3.69
	Net income attributable to common shareholders — Basic	0.22			1.19		2.06		0.22		3.69
	Income from continuing operations attributable to common shareholders — Diluted	0.22			1.18		2.04		0.22		3.66
	Net income attributable to common shareholders — Diluted	0.22			1.18		2.04		0.22		3.66

		2012 Quarter Ended									2012
		March 31,			June 30,		Sept. 30,		Dec. 31,		Total

	Operating revenues	$	620,631		$	878,576	$	1,109,475	$	693,122	$	3,301,804
	Operations and maintenance	210,663			216,236		220,729		237,141		884,769
	Operating income	48,007			254,489		447,970		101,289		851,755
	Income taxes	(4,645		)	76,689		147,116		18,157		237,317
	Income from continuing operations	284			130,930		252,874		34,905		418,993
	Net income (loss) attributable to common shareholders	(8,257		)	122,345		244,823		22,631		381,542

	Earnings Per Share:
	Income (loss) from continuing operations attributable to common shareholders — Basic	$	(0.07	)	$	1.12	$	2.23	$	0.24	$	3.54
	Net income (loss) attributable to common shareholders — Basic	(0.08		)	1.12		2.23		0.21		3.48
	Income (loss) from continuing operations attributable to common shareholders — Diluted	(0.07		)	1.12		2.21		0.24		3.5
	Net income (loss) attributable to common shareholders — Diluted	(0.08		)	1.11		2.21		0.2		3.45

ARIZONA PUBLIC SERVICE COMPANY	'
Selected Quarterly Financial Data (Unaudited)	'
	S-2. Selected Quarterly Financial Data (Unaudited)

	Quarterly financial information for 2013 and 2012 is as follows (dollars in thousands):

		2013 Quarter Ended,									2013
		March 31,			June 30,		September 30,		December 31,		Total

	Operating revenues	$	685,827		$	915,065	$	1,151,535	$	698,824	$	3,451,251
	Operations and maintenance	220,752			224,950		222,617		229,505		897,824
	Operating income	74,862			183,728		284,251		79,024		621,865
	Net income attributable to common shareholder	26,042			133,949		234,954		30,024		424,969


		2012 Quarter Ended,									2012
		March 31,			June 30,		September 30,		December 31,		Total

	Operating revenues	$	620,248		$	877,587	$	1,108,623	$	687,031	$	3,293,489
	Operations and maintenance	208,447			213,746		218,403		233,320		873,916
	Operating income	53,995			176,821		296,945		77,768		605,529
	Net income (loss) attributable to common shareholder	(4,105		)	124,928		247,831		26,843		395,497

Other_Income_and_Other_Expense3

Other Income and Other Expense (APSC)	12 Months Ended
Other Income and Other Expense (APSC)	Dec. 31, 2013
Other Income and Other Expense	'
	18. Other Income and Other Expense

	The following table provides detail of other income and other expense for 2013, 2012 and 2011 (dollars in thousands):

		2013			2012			2011
	Other income:
	Interest income	$	1,629		$	1,239		$	1,850
	Investment gains — net	—			—			1,165
	Miscellaneous	75			367			96
	Total other income	$	1,704		$	1,606		$	3,111

	Other expense:
	Non-operating costs	$	(8,207	)	$	(7,777	)	$	(7,037	)
	Investment loss — net	(3,711		)	(2,453		)	—
	Miscellaneous	(4,106		)	(9,612		)	(3,414		)
	Total other expense	$	(16,024	)	$	(19,842	)	$	(10,451	)

ARIZONA PUBLIC SERVICE COMPANY	'
Other Income and Other Expense	'
	S-3. Other Income and Other Expense

	The following table provides detail of APS’s other income and other expense for 2013, 2012 and 2011 (dollars in thousands):

		2013			2012			2011
	Other income:
	Interest income	$	1,234		$	310		$	406
	Investment gains — net	—			—			1,418
	Miscellaneous	2,662			2,558			3,247
	Total other income	$	3,896		$	2,868		$	5,071

	Other expense:
	Non-operating costs (a)	$	(9,626	)	$	(8,706	)	$	(8,810	)
	Asset dispositions	(4,992		)	(1,511		)	(1,352		)
	Miscellaneous	(5,831		)	(10,933		)	(5,166		)
	Total other expense	$	(20,449	)	$	(21,150	)	$	(15,328	)

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

Changes_in_Accumulated_Other_C3

Changes in Accumulated Other Comprehensive Loss (APSC)	12 Months Ended
	Dec. 31, 2013
Changes in Accumulated Other Comprehensive Loss	'
	21. Changes in Accumulated Other Comprehensive Loss

	The following table shows the changes in accumulated other comprehensive loss, including reclassification adjustments, net of tax, by component for the year ended December 31, 2013 (dollars in thousands):

		Year Ended December 31, 2013
		Derivative			Pension and			Total
		Instruments			Other
					Postretirement
					Benefits

	Beginning balance	$	(49,592	)	$	(64,416	)	$	(114,008	)
	OCI (loss) before reclassifications	(213		)	5,594			5,381
	Amounts reclassified from accumulated other comprehensive loss	26,747		(a)	3,827		(b)	30,574

	Net current period OCI	26,534			9,421			35,955
	Ending balance	$	(23,058	)	$	(54,995	)	$	(78,053	)

	(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 17.
	(b) These amounts primarily represent amortization of actuarial loss, and are included in the computation of net periodic pension cost. See Note 8.

ARIZONA PUBLIC SERVICE COMPANY	'
Changes in Accumulated Other Comprehensive Loss	'
	S-4. Changes in Accumulated Other Comprehensive Loss

	The following table shows the changes in accumulated other comprehensive loss, including reclassification adjustments, net of tax, by component for the year ended December 31, 2013 (dollars in thousands):

		Year Ended December 31, 2013
		Derivative			Pension and			Total
		Instruments			Other
					Postretirement
					Benefits

	Beginning balance	$	(49,592	)	$	(39,503	)	$	(89,095	)
	OCI (loss) before reclassifications	(214		)	5,387			5,173
	Amounts reclassified from accumulated other comprehensive loss	26,747		(a)	3,803		(b)	30,550

	Net current period OCI	26,533			9,190			35,723
	Ending balance	$	(23,059	)	$	(30,313	)	$	(53,372	)

	(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 17.
	(b) These amounts primarily represent amortization of actuarial loss, and are included in the computation of net periodic pension cost. See Note 8.

SCHEDULE_II_RESERVE_FOR_UNCOLL2

SCHEDULE II - RESERVE FOR UNCOLLECTIBLES (APSC)	12 Months Ended
	Dec. 31, 2013
SCHEDULE II - RESERVE FOR UNCOLLECTIBLES	'
	PINNACLE WEST CAPITAL CORPORATION
	SCHEDULE II — RESERVE FOR UNCOLLECTIBLES
	(dollars in thousands)

	Column A	Column B		Column C				Column D		Column E
				Additions
	Description	Balance at		Charged to		Charged		Deductions		Balance
		beginning		cost and		to other				at end of
		of period		expenses		accounts				period

	Reserve for uncollectibles:
	2013	$	3,340	$	4,923	$	—	$	5,060	$	3,203
	2012	3,748		5,290		—		5,698		3,340
	2011	4,709		5,672		—		6,633		3,748


ARIZONA PUBLIC SERVICE COMPANY	'
SCHEDULE II - RESERVE FOR UNCOLLECTIBLES	'
	ARIZONA PUBLIC SERVICE COMPANY
	SCHEDULE II — RESERVE FOR UNCOLLECTIBLES
	(dollars in thousands)

	Column A	Column B		Column C				Column D		Column E
				Additions
	Description	Balance at		Charged to		Charged		Deductions		Balance
		beginning		cost and		to other				at end of
		of period		expenses		accounts				period

	Reserve for uncollectibles:
	2013	$	3,340	$	4,923	$	—	$	5,060	$	3,203
	2012	3,748		5,290		—		5,698		3,340
	2011	4,376		5,751		—		6,379		3,748

Income_Taxes_APSC_Tables

Income Taxes (APSC) (Tables)	12 Months Ended
Income Taxes (APSC) (Tables)	Dec. 31, 2013
Tabular reconciliation of the total amounts of unrecognized tax benefits, excluding interest and penalties, at the beginning and end of the year	'
	The following is a tabular reconciliation of the total amounts of unrecognized tax benefits, excluding interest and penalties, at the beginning and end of the year that are included in accrued taxes and unrecognized tax benefits (dollars in thousands):

		2013			2012			2011
	Total unrecognized tax benefits, January 1	$	133,422		$	136,005		$	127,595
	Additions for tax positions of the current year	3,516			5,167			10,915
	Additions for tax positions of prior years	13,158			—			—
	Reductions for tax positions of prior years for:
	Changes in judgment	(108,099		)	(7,729		)	(1,555		)
	Settlements with taxing authorities	—			—			(124		)
	Lapses of applicable statute of limitations	—			(21		)	(826		)
	Total unrecognized tax benefits, December 31	$	41,997		$	133,422		$	136,005

Components of income tax expense	'
	The components of income tax expense are as follows (dollars in thousands):

		Year Ended December 31,
		2013			2012			2011
	Current:
	Federal	$	(81,784	)	$	(3,493	)	$	(310	)
	State	10,537			8,395			15,140
	Total current	(71,247		)	4,902			14,830
	Deferred:
	Federal	279,973			200,322			159,566
	State	21,865			28,280			16,626
	Total deferred	301,838			228,602			176,192
	Total income tax expense	230,591			233,504			191,022
	Less: income tax expense (benefit) on discontinued operations	—			(3,813		)	7,418
	Income tax expense — continuing operations	$	230,591		$	237,317		$	183,604

Comparison of pretax income from continuing operations at the federal income tax rate to income tax expense - continuing operations	'
	The following chart compares pretax income from continuing operations at the 35% federal income tax rate to income tax expense — continuing operations (dollars in thousands):

		Year Ended December 31,
		2013			2012			2011

	Federal income tax expense at 35% statutory rate	$	234,695		$	229,709		$	188,733
	Increases (reductions) in tax expense resulting from:
	State income tax net of federal income tax benefit	21,387			23,819			19,594
	Credits and favorable adjustments related to prior years resolved in current year	(3,356		)	—			—
	Medicare Subsidy Part-D	823			483			823
	Allowance for equity funds used during construction (see Note 1)	(6,997		)	(6,158		)	(6,881		)
	Palo Verde VIE noncontrolling interest (see Note 19)	(11,862		)	(11,065		)	(9,636		)
	Other	(4,099		)	529			(9,029		)
	Income tax expense — continuing operations	$	230,591		$	237,317		$	183,604

Net deferred income tax liability recognized on the Balance Sheets	'
	The following table shows the net deferred income tax liability recognized on the Consolidated Balance Sheets (dollars in thousands):

		December 31,
		2013			2012
	Current asset	$	91,152		$	152,191
	Long-term liability	(2,351,882		)	(2,151,371		)
	Deferred income taxes — net	$	(2,260,730	)	$	(1,999,180	)

Components of the net deferred income tax liability	'
	The components of the net deferred income tax liability were as follows (dollars in thousands):

		December 31,
		2013			2012
	DEFERRED TAX ASSETS
	Risk management activities	$	44,920		$	72,243
	Regulatory liabilities:
	Asset retirement obligation and removal costs	235,959			238,669
	Unamortized investment tax credits	82,116			53,837
	Other	42,609			33,764
	Pension and other postretirement liabilities	198,642			408,764
	Renewable energy incentives	65,434			66,941
	Credit and loss carryforwards	133,070			139,022
	Other	148,492			68,844
	Total deferred tax assets	951,242			1,082,084
	DEFERRED TAX LIABILITIES
	Plant-related	(2,903,730		)	(2,584,166		)
	Risk management activities	(16,191		)	(23,940		)
	Regulatory assets:
	Allowance for equity funds used during construction	(43,058		)	(37,899		)
	Deferred fuel and purchased power	(8,282		)	(28,858		)
	Deferred fuel and purchased power — mark-to-market	(13,343		)	(15,796		)
	Pension and other postretirement benefits	(129,250		)	(316,757		)
	Other	(93,202		)	(68,170		)
	Other	(4,916		)	(5,678		)
	Total deferred tax liabilities	(3,211,972		)	(3,081,264		)
	Deferred income taxes — net	$	(2,260,730	)	$	(1,999,180	)

ARIZONA PUBLIC SERVICE COMPANY	'
Tabular reconciliation of the total amounts of unrecognized tax benefits, excluding interest and penalties, at the beginning and end of the year	'
	The following is a tabular reconciliation of the total amounts of unrecognized tax benefits, excluding interest and penalties, at the beginning and end of the year that are included in accrued taxes and unrecognized tax benefits (dollars in thousands):

		2013			2012			2011
	Total unrecognized tax benefits, January 1	$	133,241		$	135,824		$	126,698
	Additions for tax positions of the current year	3,516			5,167			10,915
	Additions for tax positions of prior years	13,158			—			—
	Reductions for tax positions of prior years for:
	Changes in judgment	(107,918		)	(7,729		)	(1,555		)
	Settlements with taxing authorities	—			—			(124		)
	Lapses of applicable statute of limitations	—			(21		)	(110		)
	Total unrecognized tax benefits, December 31	$	41,997		$	133,241		$	135,824

Components of income tax expense	'
	The components of APS’s income tax expense are as follows (dollars in thousands):

		Year Ended December 31,
		2013			2012			2011
	Current:
	Federal	$	(97,531	)	$	(11,650	)	$	4,633
	State	11,983			12,308			19,104
	Total current	(85,548		)	658			23,737
	Deferred:
	Federal	305,389			216,367			154,632
	State	25,254			27,371			14,173
	Total deferred	330,643			243,738			168,805
	Total income tax expense	$	245,095		$	244,396		$	192,542

Comparison of pretax income from continuing operations at the federal income tax rate to income tax expense - continuing operations	'
	The following chart compares APS’s pretax income at the 35% federal income tax rate to income tax expense (dollars in thousands):

		Year Ended December 31,
		2013			2012			2011

	Federal income tax expense at 35% statutory rate	$	246,384		$	235,027		$	194,710
	Increases (reductions) in tax expense resulting from:
	State income tax net of federal income tax benefit	23,970			25,379			21,139
	Credits and favorable adjustments related to prior years resolved in current year	(3,231		)	—			—
	Medicare Subsidy Part-D	823			483			823
	Allowance for equity funds used during construction (see Note 1)	(6,997		)	(6,158		)	(6,880		)
	Palo Verde VIE noncontrolling interest (see Note 19)	(11,862		)	(11,065		)	(9,633		)
	Other	(3,992		)	730			(7,617		)
	Income tax expense	$	245,095		$	244,396		$	192,542

Net deferred income tax liability recognized on the Balance Sheets	'
	The following table shows the net deferred income tax liability recognized on the APS Balance Sheets (dollars in thousands):

		December 31,
		2013			2012
	Current asset (liability)	$	(2,033	)	$	74,420
	Long-term liability	(2,347,724		)	(2,133,976		)
	Deferred income taxes — net	$	(2,349,757	)	$	(2,059,556	)

Components of the net deferred income tax liability	'
	The components of the net deferred income tax liability were as follows (dollars in thousands):

		December 31,
		2013			2012
	DEFERRED TAX ASSETS
	Regulatory liabilities:
	Asset retirement obligation and removal costs	$	235,959		$	238,669
	Unamortized investment tax credits	82,116			53,837
	Other	42,609			33,764
	Risk management activities	44,920			72,243
	Pension and other postretirement liabilities	186,213			392,486
	Renewable energy incentives	65,434			66,941
	Credit and loss carryforwards	38,183			52,441
	Other	166,781			111,327
	Total deferred tax assets	862,215			1,021,708
	DEFERRED TAX LIABILITIES
	Plant-related	(2,903,730		)	(2,584,166		)
	Risk management activities	(16,191		)	(23,940		)
	Regulatory assets:
	Allowance for equity funds used during construction	(43,058		)	(37,899		)
	Deferred fuel and purchased power	(8,282		)	(28,858		)
	Deferred fuel and purchased power — mark-to-market	(13,343		)	(15,796		)
	Pension and other postretirement benefits	(129,250		)	(316,757		)
	Other	(93,202		)	(68,170		)
	Other	(4,916		)	(5,678		)
	Total deferred tax liabilities	(3,211,972		)	(3,081,264		)
	Deferred income taxes — net	$	(2,349,757	)	$	(2,059,556	)

Selected_Quarterly_Financial_D4

Selected Quarterly Financial Data (Unaudited) (APSC) (Tables)	12 Months Ended
	Dec. 31, 2013
Schedule of quarterly financial information	'
	Consolidated quarterly financial information for 2013 and 2012 is provided in the tables below (dollars in thousands, except per share amounts).

		2013 Quarter Ended									2013
		March 31,			June 30,		Sept. 30,		Dec. 31,		Total

	Operating revenues	$	686,652		$	915,822	$	1,152,392	$	699,762	$	3,454,628
	Operations and maintenance	223,250			229,300		233,323		238,854		924,727
	Operating income	86,923			259,812		415,688		83,900		846,323
	Income taxes	12,469			77,043		131,912		9,167		230,591
	Income from continuing operations	32,836			139,598		234,718		32,814		439,966
	Net income attributable to common shareholders	24,444			131,207		226,163		24,260		406,074

	Earnings Per Share:
	Income from continuing operations attributable to common shareholders — Basic	$	0.22		$	1.19	$	2.06	$	0.22	$	3.69
	Net income attributable to common shareholders — Basic	0.22			1.19		2.06		0.22		3.69
	Income from continuing operations attributable to common shareholders — Diluted	0.22			1.18		2.04		0.22		3.66
	Net income attributable to common shareholders — Diluted	0.22			1.18		2.04		0.22		3.66

		2012 Quarter Ended									2012
		March 31,			June 30,		Sept. 30,		Dec. 31,		Total

	Operating revenues	$	620,631		$	878,576	$	1,109,475	$	693,122	$	3,301,804
	Operations and maintenance	210,663			216,236		220,729		237,141		884,769
	Operating income	48,007			254,489		447,970		101,289		851,755
	Income taxes	(4,645		)	76,689		147,116		18,157		237,317
	Income from continuing operations	284			130,930		252,874		34,905		418,993
	Net income (loss) attributable to common shareholders	(8,257		)	122,345		244,823		22,631		381,542

	Earnings Per Share:
	Income (loss) from continuing operations attributable to common shareholders — Basic	$	(0.07	)	$	1.12	$	2.23	$	0.24	$	3.54
	Net income (loss) attributable to common shareholders — Basic	(0.08		)	1.12		2.23		0.21		3.48
	Income (loss) from continuing operations attributable to common shareholders — Diluted	(0.07		)	1.12		2.21		0.24		3.5
	Net income (loss) attributable to common shareholders — Diluted	(0.08		)	1.11		2.21		0.2		3.45
ARIZONA PUBLIC SERVICE COMPANY	'
Schedule of quarterly financial information	'
	Quarterly financial information for 2013 and 2012 is as follows (dollars in thousands):

		2013 Quarter Ended,									2013
		March 31,			June 30,		September 30,		December 31,		Total

	Operating revenues	$	685,827		$	915,065	$	1,151,535	$	698,824	$	3,451,251
	Operations and maintenance	220,752			224,950		222,617		229,505		897,824
	Operating income	74,862			183,728		284,251		79,024		621,865
	Net income attributable to common shareholder	26,042			133,949		234,954		30,024		424,969


		2012 Quarter Ended,									2012
		March 31,			June 30,		September 30,		December 31,		Total

	Operating revenues	$	620,248		$	877,587	$	1,108,623	$	687,031	$	3,293,489
	Operations and maintenance	208,447			213,746		218,403		233,320		873,916
	Operating income	53,995			176,821		296,945		77,768		605,529
	Net income (loss) attributable to common shareholder	(4,105		)	124,928		247,831		26,843		395,497

Other_Income_and_Other_Expense4

Other Income and Other Expense (APSC) (Tables)	12 Months Ended
Other Income and Other Expense (APSC) (Tables)	Dec. 31, 2013
Detail of other income and other expense	'
	The following table provides detail of other income and other expense for 2013, 2012 and 2011 (dollars in thousands):

		2013			2012			2011
	Other income:
	Interest income	$	1,629		$	1,239		$	1,850
	Investment gains — net	—			—			1,165
	Miscellaneous	75			367			96
	Total other income	$	1,704		$	1,606		$	3,111

	Other expense:
	Non-operating costs	$	(8,207	)	$	(7,777	)	$	(7,037	)
	Investment loss — net	(3,711		)	(2,453		)	—
	Miscellaneous	(4,106		)	(9,612		)	(3,414		)
	Total other expense	$	(16,024	)	$	(19,842	)	$	(10,451	)

ARIZONA PUBLIC SERVICE COMPANY	'
Detail of other income and other expense	'
	The following table provides detail of APS’s other income and other expense for 2013, 2012 and 2011 (dollars in thousands):

		2013			2012			2011
	Other income:
	Interest income	$	1,234		$	310		$	406
	Investment gains — net	—			—			1,418
	Miscellaneous	2,662			2,558			3,247
	Total other income	$	3,896		$	2,868		$	5,071

	Other expense:
	Non-operating costs (a)	$	(9,626	)	$	(8,706	)	$	(8,810	)
	Asset dispositions	(4,992		)	(1,511		)	(1,352		)
	Miscellaneous	(5,831		)	(10,933		)	(5,166		)
	Total other expense	$	(20,449	)	$	(21,150	)	$	(15,328	)

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

Changes_in_Accumulated_Other_C4

Changes in Accumulated Other Comprehensive Loss (APSC) (Tables)	12 Months Ended
	Dec. 31, 2013
Schedule of changes in accumulated other comprehensive loss including reclassification adjustments, by component	'
	The following table shows the changes in accumulated other comprehensive loss, including reclassification adjustments, net of tax, by component for the year ended December 31, 2013 (dollars in thousands):

		Year Ended December 31, 2013
		Derivative			Pension and			Total
		Instruments			Other
					Postretirement
					Benefits

	Beginning balance	$	(49,592	)	$	(64,416	)	$	(114,008	)
	OCI (loss) before reclassifications	(213		)	5,594			5,381
	Amounts reclassified from accumulated other comprehensive loss	26,747		(a)	3,827		(b)	30,574

	Net current period OCI	26,534			9,421			35,955
	Ending balance	$	(23,058	)	$	(54,995	)	$	(78,053	)

	(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 17.
	(b) These amounts primarily represent amortization of actuarial loss, and are included in the computation of net periodic pension cost. See Note 8.

ARIZONA PUBLIC SERVICE COMPANY	'
Schedule of changes in accumulated other comprehensive loss including reclassification adjustments, by component	'
	The following table shows the changes in accumulated other comprehensive loss, including reclassification adjustments, net of tax, by component for the year ended December 31, 2013 (dollars in thousands):

		Year Ended December 31, 2013
		Derivative			Pension and			Total
		Instruments			Other
					Postretirement
					Benefits

	Beginning balance	$	(49,592	)	$	(39,503	)	$	(89,095	)
	OCI (loss) before reclassifications	(214		)	5,387			5,173
	Amounts reclassified from accumulated other comprehensive loss	26,747		(a)	3,803		(b)	30,550

	Net current period OCI	26,533			9,190			35,723
	Ending balance	$	(23,059	)	$	(30,313	)	$	(53,372	)

	(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 17.
	(b) These amounts primarily represent amortization of actuarial loss, and are included in the computation of net periodic pension cost. See Note 8.

Income_Taxes_APSC_Details

Income Taxes (APSC) (Details) (USD $)

3 Months Ended

12 Months Ended

0 Months Ended

3 Months Ended

12 Months Ended

Sep. 30, 2013

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Dec. 31, 2013

Sep. 13, 2013

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Sep. 30, 2013

Sep. 30, 2009

Dec. 31, 2013

Palo Verde VIE

Maximum

ARIZONA PUBLIC SERVICE COMPANY

Maximum

Income taxes

Long-term income tax receivables

$70,389,000

$70,784,000

$71,000,000

Decrease in uncertain tax positions

67,000,000

Income tax receivable that will be reclassified from long term to short-term

137,000,000

138,000,000

Anticipated refund reduction amount

-4,000,000

Decrease in long term deferred tax liability due to adoption of regulations

-84,000,000

Decrease in long term deferred tax liability due to rate changes

-75,000,000

-2,000,000

Period over which deferred income tax liability would have been repaid

'20 years

Income tax expense associates with the VIE's

Tabular reconciliation of the total amounts of unrecognized tax benefits, excluding interest and penalties, at the beginning and end of the year

Total unrecognized tax benefits at the beginning of the year

133,422,000

136,005,000

127,595,000

133,241,000

135,824,000

126,698,000

Additions for tax positions of the current year

3,516,000

5,167,000

10,915,000

3,516,000

5,167,000

10,915,000

Additions for tax positions of prior years

13,158,000

Reductions for tax positions of prior years for:

Changes in judgment

-108,099,000

-7,729,000

-1,555,000

-107,918,000

-7,729,000

-1,555,000

Settlements with taxing authorities

-124,000

Lapses of applicable statute of limitations

-21,000

-826,000

-21,000

-110,000,000

Total unrecognized tax benefits at the end of the year

41,997,000

133,422,000

136,005,000

41,997,000

133,241,000

135,824,000

Unrecognized tax benefits if recognized, would decrease effective tax rate

10,000,000

8,000,000

10,000,000

8,000,000

Pre-tax interest benefit related to unrecognized tax benefits

4,000,000

3,000,000

4,000,000

3,000,000

Accrued liabilities for interest related to unrecognized tax benefits

13,000,000

9,000,000

1,000,000

13,000,000

9,000,000

1,000,000

Interest income to be received on the overpayment of income taxes for certain adjustments that we have filed, or will file, with the IRS

$5,000,000

Income_Taxes_APSC_Details_2

Income Taxes (APSC) (Details 2) (USD $)

3 Months Ended

12 Months Ended

0 Months Ended

3 Months Ended

12 Months Ended

Dec. 31, 2013

Sep. 30, 2013

Jun. 30, 2013

Mar. 31, 2013

Dec. 31, 2012

Sep. 30, 2012

Jun. 30, 2012

Mar. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Sep. 13, 2013

Apr. 04, 2013

Feb. 17, 2011

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

ARIZONA PUBLIC SERVICE COMPANY

Current:

Federal

($81,784,000)

($3,493,000)

($310,000)

($97,531,000)

($11,650,000)

$4,633,000

State

10,537,000

8,395,000

15,140,000

11,983,000

12,308,000

19,104,000

Total current

-71,247,000

4,902,000

14,830,000

-85,548,000

658,000

23,737,000

Deferred:

Federal

279,973,000

200,322,000

159,566,000

305,389,000

216,367,000

154,632,000

State

21,865,000

28,280,000

16,626,000

25,254,000

27,371,000

14,173,000

Total deferred

330,643,000

243,738,000

168,805,000

Income tax expense - continuing operations

9,167,000

131,912,000

77,043,000

12,469,000

18,157,000

147,116,000

76,689,000

-4,645,000

230,591,000

237,317,000

183,604,000

245,095,000

244,396,000

192,542,000

Comparison of pretax income from continuing operations at the federal income tax rate to income tax expense - continuing operations

Federal income tax rate (as a percent)

35.00%

Federal income tax expense at 35% statutory rate

234,695,000

229,709,000

188,733,000

246,384,000

235,027,000

194,710,000

Increases (reductions) in tax expense resulting from:

State income tax net of federal income tax benefit

21,387,000

23,819,000

19,594,000

23,970,000

25,379,000

21,139,000

Credits and favorable adjustments related to prior years resolved in current year

-3,356,000

-3,231,000

Medicare Subsidy Part-D

823,000

483,000

823,000

483,000

823,000

Allowance for equity funds used during construction

-6,997,000

-6,158,000

-6,881,000

-6,997,000

-6,158,000

-6,880,000

Palo Verde VIE noncontrolling interest

-11,862,000

-11,065,000

-9,636,000

-11,862,000

-11,065,000

-9,633,000

Other

-4,099,000

529,000

-9,029,000

-3,992,000

730,000

-7,617,000

Income tax expense - continuing operations

9,167,000

131,912,000

77,043,000

12,469,000

18,157,000

147,116,000

76,689,000

-4,645,000

230,591,000

237,317,000

183,604,000

245,095,000

244,396,000

192,542,000

Net deferred income tax liability recognized on the Consolidated Balance Sheets

Current asset (liability)

91,152,000

152,191,000

91,152,000

152,191,000

-2,033,000

74,420,000

Long-term liability

-2,351,882,000

-2,151,371,000

-2,351,882,000

-2,151,371,000

-2,347,724,000

-2,133,976,000

Deferred income taxes - net

-2,260,730,000

-1,999,180,000

-2,260,730,000

-1,999,180,000

-2,349,757,000

-2,059,556,000

Income Taxes, additional disclosures

Phase-in period of corporate income tax rate reductions beginning in 2014

'5 years

'4 years

Decrease in long term deferred tax liability due to adoption of regulations

-84,000,000

Decrease in long term deferred tax liability due to rate changes

($75,000,000)

($2,000,000)

Income_Taxes_APSC_Details_3

Income Taxes (APSC) (Details 3) (USD $)	Dec. 31, 2013	Dec. 31, 2012
In Thousands, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012
Regulatory liabilities:	'	'
Asset retirement obligation and removal costs	$235,959	$238,669
Unamortized investment tax credits	82,116	53,837
Other	42,609	33,764
Risk management activities	44,920	72,243
Pension and other postretirement liabilities	198,642	408,764
Renewable energy incentives	65,434	66,941
Credit and loss carryforwards	133,070	139,022
Other	148,492	68,844
Total deferred tax assets	951,242	1,082,084
DEFERRED TAX LIABILITIES	'	'
Plant-related	-2,903,730	-2,584,166
Risk management activities	-16,191	-23,940
Regulatory assets:	'	'
Allowance for equity funds used during construction	-43,058	-37,899
Deferred fuel and purchased power	-8,282	-28,858
Deferred fuel and purchased power - mark-to-market	-13,343	-15,796
Pension and other postretirement benefits	-129,250	-316,757
Other	-93,202	-68,170
Other	-4,916	-5,678
Total deferred tax liabilities	-3,211,972	-3,081,264
Deferred income taxes - net	-2,260,730	-1,999,180
ARIZONA PUBLIC SERVICE COMPANY	'	'
Regulatory liabilities:	'	'
Asset retirement obligation and removal costs	235,959	238,669
Unamortized investment tax credits	82,116	53,837
Other	42,609	33,764
Risk management activities	44,920	72,243
Pension and other postretirement liabilities	186,213	392,486
Renewable energy incentives	65,434	66,941
Credit and loss carryforwards	38,183	52,441
Other	166,781	111,327
Total deferred tax assets	862,215	1,021,708
DEFERRED TAX LIABILITIES	'	'
Plant-related	-2,903,730	-2,584,166
Risk management activities	-16,191	-23,940
Regulatory assets:	'	'
Allowance for equity funds used during construction	-43,058	-37,899
Deferred fuel and purchased power	-8,282	-28,858
Deferred fuel and purchased power - mark-to-market	-13,343	-15,796
Pension and other postretirement benefits	-129,250	-316,757
Other	-93,202	-68,170
Other	-4,916	-5,678
Total deferred tax liabilities	-3,211,972	-3,081,264
Deferred income taxes - net	($2,349,757)	($2,059,556)

Selected_Quarterly_Financial_D5

Selected Quarterly Financial Data (Unaudited) (APSC) (Details) (USD $)	3 Months Ended								12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2013	Sep. 30, 2013	Jun. 30, 2013	Mar. 31, 2013	Dec. 31, 2012	Sep. 30, 2012	Jun. 30, 2012	Mar. 31, 2012	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Consolidated quarterly financial information	'	'	'	'	'	'	'	'	'	'	'
Operating revenues	$699,762	$1,152,392	$915,822	$686,652	$693,122	$1,109,475	$878,576	$620,631	$3,454,628	$3,301,804	$3,241,379
Operations and maintenance	238,854	233,323	229,300	223,250	237,141	220,729	216,236	210,663	924,727	884,769	904,286
Operating income	83,900	415,688	259,812	86,923	101,289	447,970	254,489	48,007	846,323	851,755	746,508
Net income (loss) attributable to common shareholder	24,260	226,163	131,207	24,444	22,631	244,823	122,345	-8,257	406,074	381,542	339,473
ARIZONA PUBLIC SERVICE COMPANY	'	'	'	'	'	'	'	'	'	'	'
Consolidated quarterly financial information	'	'	'	'	'	'	'	'	'	'	'
Operating revenues	698,824	1,151,535	915,065	685,827	687,031	1,108,623	877,587	620,248	3,451,251	3,293,489	'
Operations and maintenance	229,505	222,617	224,950	220,752	233,320	218,403	213,746	208,447	897,824	873,916	895,917
Operating income	79,024	284,251	183,728	74,862	77,768	296,945	176,821	53,995	621,865	605,529	554,383
Net income (loss) attributable to common shareholder	$30,024	$234,954	$133,949	$26,042	$26,843	$247,831	$124,928	($4,105)	$424,969	$395,497	$336,249

Other_Income_and_Other_Expense5

Other Income and Other Expense (APSC) (Details) (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Other income:	'	'	'
Interest income	$1,629	$1,239	$1,850
Investment gains - net	'	'	1,165
Miscellaneous	75	367	96
Total other income	1,704	1,606	3,111
Other expense:	'	'	'
Non-operating costs	-8,207	-7,777	-7,037
Miscellaneous	-4,106	-9,612	-3,414
Total other expense	-16,024	-19,842	-10,451
ARIZONA PUBLIC SERVICE COMPANY	'	'	'
Other income:	'	'	'
Interest income	1,234	310	406
Investment gains - net	'	'	1,418
Miscellaneous	2,662	2,558	3,247
Total other income	3,896	2,868	5,071
Other expense:	'	'	'
Non-operating costs	-9,626	-8,706	-8,810
Asset dispositions	-4,992	-1,511	-1,352
Miscellaneous	-5,831	-10,933	-5,166
Total other expense	($20,449)	($21,150)	($15,328)

Changes_in_Accumulated_Other_C5

Changes in Accumulated Other Comprehensive Loss (APSC) (Details) (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Changes in accumulated other comprehensive income (loss) by component	'	'	'
Beginning balance	($114,008)	'	'
OCI (loss) before reclassifications	5,381	'	'
Amounts reclassified from accumulated other comprehensive loss	30,574	'	'
Other comprehensive income (loss) attributable to common shareholders	35,955	38,155	7,605
Ending balance	-78,053	-114,008	'
Derivative Instruments	'	'	'
Changes in accumulated other comprehensive income (loss) by component	'	'	'
Beginning balance	-49,592	'	'
OCI (loss) before reclassifications	-213	'	'
Amounts reclassified from accumulated other comprehensive loss	26,747	'	'
Other comprehensive income (loss) attributable to common shareholders	26,534	'	'
Ending balance	-23,058	'	'
Pension and other postretirement benefits	'	'	'
Changes in accumulated other comprehensive income (loss) by component	'	'	'
Beginning balance	-64,416	'	'
OCI (loss) before reclassifications	5,594	'	'
Amounts reclassified from accumulated other comprehensive loss	3,827	'	'
Other comprehensive income (loss) attributable to common shareholders	9,421	'	'
Ending balance	-54,995	'	'
ARIZONA PUBLIC SERVICE COMPANY	'	'	'
Changes in accumulated other comprehensive income (loss) by component	'	'	'
Beginning balance	-89,095	'	'
OCI (loss) before reclassifications	5,173	'	'
Amounts reclassified from accumulated other comprehensive loss	30,550	'	'
Other comprehensive income (loss) attributable to common shareholders	35,723	36,496	10,704
Ending balance	-53,372	-89,095	'
ARIZONA PUBLIC SERVICE COMPANY \| Derivative Instruments	'	'	'
Changes in accumulated other comprehensive income (loss) by component	'	'	'
Beginning balance	-49,592	'	'
OCI (loss) before reclassifications	-214	'	'
Amounts reclassified from accumulated other comprehensive loss	26,747	'	'
Other comprehensive income (loss) attributable to common shareholders	26,533	'	'
Ending balance	-23,059	'	'
ARIZONA PUBLIC SERVICE COMPANY \| Pension and other postretirement benefits	'	'	'
Changes in accumulated other comprehensive income (loss) by component	'	'	'
Beginning balance	-39,503	'	'
OCI (loss) before reclassifications	5,387	'	'
Amounts reclassified from accumulated other comprehensive loss	3,803	'	'
Other comprehensive income (loss) attributable to common shareholders	9,190	'	'
Ending balance	($30,313)	'	'

SCHEDULE_II_RESERVE_FOR_UNCOLL3

SCHEDULE II - RESERVE FOR UNCOLLECTIBLES (APSC) (Details) (Reserve for uncollectibles., ARIZONA PUBLIC SERVICE COMPANY, USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Reserve for uncollectibles. \| ARIZONA PUBLIC SERVICE COMPANY	'	'	'
Changes in reserve for uncollectibles	'	'	'
Balance at beginning of period	$3,340	$3,748	$4,376
Additions, Charged to cost and expenses	4,923	5,290	5,751
Deductions	5,060	5,698	6,379
Balance at end of period	$3,203	$3,340	$3,748