PINNACLE WEST CAPITAL CORP, 10-K filed on 2/24/2012
Annual Report
Document and Entity Information (USD $)
12 Months Ended
Dec. 31, 2011
Feb. 15, 2012
Jun. 30, 2011
Document and Entity Information
 
 
 
Entity Registrant Name
PINNACLE WEST CAPITAL CORP 
 
 
Entity Central Index Key
0000764622 
 
 
Document Type
10-K 
 
 
Document Period End Date
Dec. 31, 2011 
 
 
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
 
 
$ 4,848,522,427 
Entity Common Stock, Shares Outstanding
 
109,254,312 
 
Document Fiscal Year Focus
2011 
 
 
Document Fiscal Period Focus
FY 
 
 
CONSOLIDATED STATEMENTS OF INCOME (USD $)
In Thousands, except Per Share data, unless otherwise specified
12 Months Ended
Dec. 31, 2011
Dec. 31, 2010
Dec. 31, 2009
OPERATING REVENUES
 
 
 
Regulated electricity
$ 3,237,194 
$ 3,180,678 
$ 3,149,187 
Other revenues
4,185 
8,521 
4,469 
Total
3,241,379 
3,189,199 
3,153,656 
OPERATING EXPENSES
 
 
 
Regulated electricity fuel and purchased power
1,009,464 
1,046,815 
1,178,620 
Operations and maintenance
904,286 
870,185 
822,300 
Depreciation and amortization
427,054 
414,479 
407,354 
Taxes other than income taxes
147,408 
135,328 
123,270 
Other expenses
6,659 
7,509 
5,984 
Total
2,494,871 
2,474,316 
2,537,528 
OPERATING INCOME
746,508 
714,883 
616,128 
OTHER INCOME (DEDUCTIONS)
 
 
 
Allowance for equity funds used during construction (Note 1)
23,707 
22,066 
14,999 
Other income (Note 19)
3,111 
6,387 
5,159 
Other expense (Note 19)
(10,451)
(9,921)
(14,300)
Total
16,367 
18,532 
5,858 
INTEREST EXPENSE
 
 
 
Interest charges
241,995 
244,174 
237,766 
Allowance for borrowed funds used during construction (Note 1)
(18,358)
(16,479)
(10,379)
Total
223,637 
227,695 
227,387 
INCOME FROM CONTINUING OPERATIONS BEFORE INCOME TAXES
539,238 
505,720 
394,599 
INCOME TAXES (Note 4)
183,604 
160,869 
138,551 
INCOME FROM CONTINUING OPERATIONS
355,634 
344,851 
256,048 
INCOME (LOSS) FROM DISCONTINUED OPERATIONS
 
 
 
Net of income tax expense (benefit) of $7,418, $16,260 and $(109,641) (Note 21)
11,306 
25,358 
(183,284)
NET INCOME
366,940 
370,209 
72,764 
Less: Net income attributable to noncontrolling interests (Note 20)
27,467 
20,156 
4,434 
Net income attributable to common shareholders
339,473 
350,053 
68,330 
WEIGHTED-AVERAGE COMMON SHARES OUTSTANDING - BASIC (in shares)
109,053 
106,573 
101,161 
WEIGHTED-AVERAGE COMMON SHARES OUTSTANDING - DILUTED (in shares)
109,864 
107,138 
101,264 
EARNINGS PER WEIGHTED - AVERAGE COMMON SHARE OUTSTANDING
 
 
 
Income from continuing operations attributable to common shareholders - basic (in dollars per share)
$ 3.01 
$ 3.05 
$ 2.34 
Net income attributable to common shareholders - basic (in dollars per share)
$ 3.11 
$ 3.28 
$ 0.68 
Income from continuing operations attributable to common shareholders - diluted (in dollars per share)
$ 2.99 
$ 3.03 
$ 2.34 
Net income attributable to common shareholders - diluted (in dollars per share)
$ 3.09 
$ 3.27 
$ 0.67 
DIVIDENDS DECLARED PER SHARE (in dollars per share)
$ 2.10 
$ 2.10 
$ 2.10 
AMOUNTS ATTRIBUTABLE TO COMMON SHAREHOLDERS:
 
 
 
Income from continuing operations, net of tax
328,110 
324,688 
236,839 
Discontinued operations, net of tax
11,363 
25,365 
(168,509)
Net income attributable to common shareholders
$ 339,473 
$ 350,053 
$ 68,330 
CONSOLIDATED STATEMENTS OF INCOME (Parenthetical) (USD $)
In Thousands, unless otherwise specified
12 Months Ended
Dec. 31, 2011
Dec. 31, 2010
Dec. 31, 2009
CONSOLIDATED STATEMENTS OF INCOME
 
 
 
Income tax expense (benefit) on discontinued operations
$ 7,418 
$ 16,260 
$ (109,641)
CONSOLIDATED BALANCE SHEETS (USD $)
In Thousands, unless otherwise specified
Dec. 31, 2011
Dec. 31, 2010
CURRENT ASSETS
 
 
Cash and cash equivalents
$ 33,583 
$ 110,188 
Customer and other receivables
284,183 
324,207 
Accrued unbilled revenues
125,239 
103,292 
Allowance for doubtful accounts
(3,748)
(7,981)
Materials and supplies (at average cost)
204,387 
181,414 
Fossil fuel (at average cost)
22,000 
21,575 
Deferred income taxes (Note 4)
130,571 
124,897 
Income tax receivable (Note 4)
6,466 
2,483 
Assets from risk management activities (Note 18)
30,264 
73,788 
Deferred fuel and purchased power regulatory asset (Note 3)
27,549 
 
Other regulatory assets (Note 3)
69,072 
62,286 
Other current assets
26,904 
28,362 
Total current assets
956,470 
1,024,511 
INVESTMENTS AND OTHER ASSETS
 
 
Assets from risk management activities (Note 18)
49,322 
39,032 
Nuclear decommissioning trust (Notes 14 and 23)
513,733 
469,886 
Other assets
64,588 
116,216 
Total investments and other assets
627,643 
625,134 
PROPERTY, PLANT AND EQUIPMENT (Notes 1, 6, 9 and 10)
 
 
Plant in service and held for future use
13,753,971 
13,201,960 
Accumulated depreciation and amortization
(4,709,991)
(4,514,204)
Net
9,043,980 
8,687,756 
Construction work in progress
496,745 
459,361 
Palo Verde sale leaseback, net of accumulated depreciation of $218,186 and $213,094 (Note 20)
132,864 
137,956 
Intangible assets, net of accumulated amortization of $373,706 and $330,584
170,571 
184,952 
Nuclear fuel, net of accumulated amortization of $113,375 and $85,270
118,098 
108,794 
Total property, plant and equipment
9,962,258 
9,578,819 
DEFERRED DEBITS
 
 
Regulatory assets (Notes 1, 3 and 4)
1,352,079 
986,370 
Income tax receivable (Note 4)
68,633 
65,103 
Other
143,935 
113,061 
Total deferred debits
1,564,647 
1,164,534 
TOTAL ASSETS
13,111,018 
12,392,998 
CURRENT LIABILITIES
 
 
Accounts payable
326,987 
236,354 
Accrued taxes
120,289 
104,711 
Accrued interest
54,872 
54,831 
Short-term borrowings (Note 5)
 
16,600 
Current maturities of long-term debt (Note 6)
477,435 
631,879 
Customer deposits
72,176 
68,322 
Liabilities from risk management activities (Note 18)
53,968 
58,976 
Deferred fuel and purchased power regulatory liability (Note 3)
 
58,442 
Other regulatory liabilities (Note 3)
88,362 
80,526 
Other current liabilities
148,616 
139,063 
Total current liabilities
1,342,705 
1,449,704 
LONG-TERM DEBT LESS CURRENT MATURITIES (Note 6)
 
 
Long-term debt less current maturities
2,953,507 
2,948,991 
Palo Verde sale leaseback lessor notes less current maturities (Note 20)
65,547 
96,803 
Total long-term debt less current maturities
3,019,054 
3,045,794 
DEFERRED CREDITS AND OTHER
 
 
Deferred income taxes (Note 4)
1,925,388 
1,863,861 
Regulatory liabilities (Notes 1 and 3)
737,332 
614,063 
Liability for asset retirements (Note 12)
279,643 
328,571 
Liabilities for pension and other postretirement benefits (Note 8)
1,268,910 
813,121 
Liabilities from risk management activities (Note 18)
82,495 
65,390 
Customer advances
116,805 
121,645 
Coal mine reclamation
117,896 
117,243 
Unrecognized tax benefits (Note 4)
72,270 
66,349 
Other
217,934 
132,031 
Total deferred credits and other
4,818,673 
4,122,274 
COMMITMENTS AND CONTINGENCIES (SEE NOTES)
   
   
EQUITY (Note 7)
 
 
Common stock, no par value; authorized 150,000,000 shares, issued 109,356,974 at end of 2011 and 108,820,067 at end of 2010
2,444,247 
2,421,372 
Treasury stock at cost; 111,161 shares at end of 2011 and 50,410 at end of 2010
(4,717)
(2,239)
Total common stock
2,439,530 
2,419,133 
Retained earnings
1,534,483 
1,423,961 
Accumulated other comprehensive loss:
 
 
Pension and other postretirement benefits (Note 8)
(65,447)
(59,420)
Derivative instruments
(86,716)
(100,347)
Total accumulated other comprehensive loss
(152,163)
(159,767)
Total shareholders' equity
3,821,850 
3,683,327 
Noncontrolling interests (Note 20)
108,736 
91,899 
Total equity
3,930,586 
3,775,226 
TOTAL LIABILITIES AND EQUITY
$ 13,111,018 
$ 12,392,998 
CONSOLIDATED BALANCE SHEETS (Parenthetical) (USD $)
In Thousands, except Share data, unless otherwise specified
Dec. 31, 2011
Dec. 31, 2010
PROPERTY, PLANT AND EQUIPMENT (Notes 1, 6, 9 and 10)
 
 
Accumulated depreciation of Palo Verde sale leaseback
$ 218,186 
$ 213,094 
Accumulated amortization on intangible assets
373,706 
330,584 
Accumulated amortization on nuclear fuel
$ 113,375 
$ 85,270 
EQUITY (Note 7)
 
 
Common stock, authorized shares
150,000,000 
150,000,000 
Common stock, issued shares
109,356,974 
108,820,067 
Treasury stock at cost, shares
111,161 
50,410 
CONSOLIDATED STATEMENTS OF CASH FLOWS (USD $)
In Thousands, unless otherwise specified
12 Months Ended
Dec. 31, 2011
Dec. 31, 2010
Dec. 31, 2009
CASH FLOWS FROM OPERATING ACTIVITIES
 
 
 
Net Income
$ 366,940 
$ 370,209 
$ 72,764 
Adjustments to reconcile net income to net cash provided by operating activities:
 
 
 
Gain on sale of energy-related products and services business
(10,404)
 
 
Gain on sale of district cooling business
 
(41,973)
 
Depreciation and amortization including nuclear fuel
493,784 
472,807 
450,864 
Deferred fuel and purchased power
69,166 
93,631 
(51,742)
Deferred fuel and purchased power amortization
(155,157)
(122,481)
147,018 
Allowance for equity funds used during construction
(23,707)
(22,066)
(14,999)
Real estate impairment charges
 
16,731 
280,188 
Gain on real estate debt restructuring
 
(16,755)
 
Deferred income taxes
176,192 
260,411 
105,492 
Change in mark-to-market valuations
4,064 
2,688 
(6,939)
Changes in current assets and liabilities:
 
 
 
Customer and other receivables
40,626 
(67,943)
12,292 
Accrued unbilled revenues
(21,947)
7,679 
(10,882)
Materials, supplies and fossil fuel
(23,398)
12,276 
(12,261)
Other current assets
(3,079)
9,375 
38,406 
Accounts payable
58,346 
9,125 
(27,328)
Accrued taxes and income tax receivable - net
12,068 
24,222 
(31,792)
Other current liabilities
20,358 
2,921 
57,280 
Change in margin and collateral accounts - assets
33,349 
(9,937)
(12,806)
Change in margin and collateral accounts - liabilities
29,731 
(88,315)
35,654 
Change in long term income tax receivable
(3,530)
 
(131,984)
Change in unrecognized tax benefits
8,410 
(73,621)
137,898 
Change in other regulatory liabilities
37,009 
56,801 
82,650 
Change in other long-term assets
(41,722)
(47,940)
(64,629)
Change in other long-term liabilities
58,484 
(97,388)
12,161 
Net cash flow provided by operating activities
1,125,583 
750,457 
1,067,305 
CASH FLOWS FROM INVESTING ACTIVITIES
 
 
 
Capital expenditures
(884,350)
(748,374)
(764,609)
Contributions in aid of construction
38,096 
32,754 
53,525 
Allowance for borrowed funds used during construction
(18,358)
(16,778)
(10,745)
Proceeds from sale of district cooling business
 
100,300 
 
Proceeds from sale of energy-related products and services business
45,111 
 
 
Proceeds from nuclear decommissioning trust sales
497,780 
560,469 
441,242 
Investment in nuclear decommissioning trust
(513,799)
(584,885)
(463,033)
Proceeds from sale of commercial real estate investments
1,375 
72,038 
43,370 
Proceeds from sale of life insurance policies
55,444 
 
 
Other
(3,306)
8,576 
(4,667)
Net cash flow used for investing activities
(782,007)
(575,900)
(704,917)
CASH FLOWS FROM FINANCING ACTIVITIES
 
 
 
Issuance of long-term debt
470,353 
 
867,469 
Repayment of long-term debt
(655,169)
(106,572)
(456,882)
Short-term borrowings and payments - net
(16,600)
(137,115)
(516,754)
Dividends paid on common stock
(221,728)
(216,979)
(205,076)
Common stock equity issuance
15,841 
255,971 
3,302 
Distributions to noncontrolling interests
(10,210)
(11,403)
(14,485)
Other
(2,668)
6,351 
171 
Net cash flow used for financing activities
(420,181)
(209,747)
(322,255)
NET INCREASE (DECREASE) IN CASH AND CASH EQUIVALENTS
(76,605)
(35,190)
40,133 
CASH AND CASH EQUIVALENTS AT BEGINNING OF YEAR
110,188 
145,378 
105,245 
CASH AND CASH EQUIVALENTS AT END OF YEAR
33,583 
110,188 
145,378 
Cash paid during the period for:
 
 
 
Income taxes, net of (refunds)
10,324 
(23,447)
(52,776)
Interest, net of amounts capitalized
$ 217,789 
$ 221,728 
$ 216,608 
CONSOLIDATED STATEMENTS OF CHANGES IN EQUITY (USD $)
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, 2008
 
$ 2,151,323 
$ (2,854)
$ 1,444,208 
$ (146,698)
$ 124,990 
 
Increase (Decrease) in Shareholders' Equity
 
 
 
 
 
 
 
Issuance of common stock
 
10,620 
 
 
 
 
 
Purchase of treasury stock
 
 
(2,156)
 
 
 
 
Reissuance of treasury stock used for stock compensation
 
 
1,198 
 
 
 
 
Net income attributable to common shareholders
68,330 
 
 
68,330 
 
 
68,330 
Common stock dividends
 
 
 
(212,386)
 
 
 
Pension and other postretirement benefits (Note 8):
 
 
 
 
 
 
 
Unrealized actuarial loss, net of tax benefit of $(6,067), $(7,738) and $(4,223)
 
 
 
 
(6,350)
 
 
Amortization to income:
 
 
 
 
 
 
 
Actuarial loss, net of tax benefit of $1,950, $1,870 and $1,705
 
 
 
 
2,615 
 
 
Prior service cost, net of tax benefit of $179, $201 and $215
 
 
 
 
329 
 
 
Transition obligation, net of tax benefit of $3, $59 and $39
 
 
 
 
61 
 
 
Derivative instruments:
 
 
 
 
 
 
 
Net unrealized loss, net of tax benefit of $(37,389), $(61,348) and $(61,329)
 
 
 
 
(93,996)
 
 
Reclassification of net realized loss to income, net of tax benefit of $46,288, $48,453 and $72,877
 
 
 
 
112,452 
 
 
Net income attributable to noncontrolling interests
(4,434)
 
 
 
 
4,434 
 
Net capital activities by noncontrolling interests
 
 
 
 
 
(17,529)
 
COMPREHENSIVE INCOME ATTRIBUTABLE TO COMMON SHAREHOLDERS
 
 
 
 
 
 
 
Other comprehensive income (loss)
15,111 
 
 
 
 
 
15,111 
Comprehensive income attributable to common shareholders
83,441 
 
 
 
 
 
83,441 
Other
 
(8,648)
 
(1,939)
 
 
 
Balance at Dec. 31, 2009
3,428,004 
2,153,295 
(3,812)
1,298,213 
(131,587)
111,895 
 
Increase (Decrease) in Shareholders' Equity
 
 
 
 
 
 
 
Issuance of common stock
 
263,297 
 
 
 
 
 
Purchase of treasury stock
 
 
(82)
 
 
 
 
Reissuance of treasury stock used for stock compensation
 
 
1,655 
 
 
 
 
Net income attributable to common shareholders
350,053 
 
 
350,053 
 
 
350,053 
Common stock dividends
 
 
 
(224,305)
 
 
 
Pension and other postretirement benefits (Note 8):
 
 
 
 
 
 
 
Unrealized actuarial loss, net of tax benefit of $(6,067), $(7,738) and $(4,223)
 
 
 
 
(11,795)
 
 
Amortization to income:
 
 
 
 
 
 
 
Actuarial loss, net of tax benefit of $1,950, $1,870 and $1,705
 
 
 
 
2,868 
 
 
Prior service cost, net of tax benefit of $179, $201 and $215
 
 
 
 
308 
 
 
Transition obligation, net of tax benefit of $3, $59 and $39
 
 
 
 
91 
 
 
Derivative instruments:
 
 
 
 
 
 
 
Net unrealized loss, net of tax benefit of $(37,389), $(61,348) and $(61,329)
 
 
 
 
(93,939)
 
 
Reclassification of net realized loss to income, net of tax benefit of $46,288, $48,453 and $72,877
 
 
 
 
74,287 
 
 
Net income attributable to noncontrolling interests
(20,156)
 
 
 
 
20,156 
 
Net capital activities by noncontrolling interests
 
 
 
 
 
(40,152)
 
COMPREHENSIVE INCOME ATTRIBUTABLE TO COMMON SHAREHOLDERS
 
 
 
 
 
 
 
Other comprehensive income (loss)
(28,180)
 
 
 
 
 
(28,180)
Comprehensive income attributable to common shareholders
321,873 
 
 
 
 
 
321,873 
Other
 
4,780 
 
 
 
 
 
Balance at Dec. 31, 2010
3,775,226 
2,421,372 
(2,239)
1,423,961 
(159,767)
91,899 
 
Increase (Decrease) in Shareholders' Equity
 
 
 
 
 
 
 
Issuance of common stock
 
11,057 
 
 
 
 
 
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
 
 
 
(228,951)
 
 
 
Pension and other postretirement benefits (Note 8):
 
 
 
 
 
 
 
Unrealized actuarial loss, net of tax benefit of $(6,067), $(7,738) and $(4,223)
 
 
 
 
(9,296)
 
 
Amortization to income:
 
 
 
 
 
 
 
Actuarial loss, net of tax benefit of $1,950, $1,870 and $1,705
 
 
 
 
2,990 
 
 
Prior service cost, net of tax benefit of $179, $201 and $215
 
 
 
 
275 
 
 
Transition obligation, net of tax benefit of $3, $59 and $39
 
 
 
 
 
 
Derivative instruments:
 
 
 
 
 
 
 
Net unrealized loss, net of tax benefit of $(37,389), $(61,348) and $(61,329)
 
 
 
 
(57,271)
 
 
Reclassification of net realized loss to income, net of tax benefit of $46,288, $48,453 and $72,877
 
 
 
 
70,901 
 
 
Net income attributable to noncontrolling interests
(27,467)
 
 
 
 
27,467 
 
Net capital activities by noncontrolling interests
 
 
 
 
 
(10,630)
 
COMPREHENSIVE INCOME ATTRIBUTABLE TO COMMON SHAREHOLDERS
 
 
 
 
 
 
 
Other comprehensive income (loss)
7,605 
 
 
 
 
 
7,605 
Comprehensive income attributable to common shareholders
347,078 
 
 
 
 
 
347,078 
Other
 
11,818 
 
 
 
 
 
Balance at Dec. 31, 2011
$ 3,930,586 
$ 2,444,247 
$ (4,717)
$ 1,534,483 
$ (152,163)
$ 108,736 
 
CONSOLIDATED STATEMENTS OF CHANGES IN EQUITY (Parenthetical) (USD $)
In Thousands, unless otherwise specified
12 Months Ended
Dec. 31, 2011
Dec. 31, 2010
Dec. 31, 2009
Pension and other postretirement benefits (Note 8):
 
 
 
Unrealized actuarial loss, net of tax benefit
$ (6,067)
$ (7,738)
$ (4,223)
Amortization to income:
 
 
 
Actuarial loss, net of tax benefit
1,950 
1,870 
1,705 
Prior service cost, tax benefit
179 
201 
215 
Transition obligation, tax benefit
59 
39 
Derivative instruments:
 
 
 
Net unrealized gain (loss), net of tax
(37,389)
(61,348)
(61,329)
Reclassification of net realized (gain) loss to income, net of tax (expense) benefit
$ 46,288 
$ 48,453 
$ 72,877 
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, SunCor, El Dorado, and formerly 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 in Arizona, New Mexico, Idaho and Utah but in 2009 and 2010, essentially all of these assets were sold.  All activities for SunCor are now reported as discontinued operations (see Note 21). 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 now reported as discontinued operations (see Note 21). El Dorado is an investment firm.

 

Pinnacle West’s Consolidated Financial Statements include the accounts of Pinnacle West and our subsidiaries: APS, SunCor, APSES, and El Dorado. 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 20).

 

In preparing the consolidated financial statements, we have evaluated the events that have occurred after December 31, 2011 through the date the financial statements were issued.

 

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.  These consolidated financial statements and notes have been prepared consistently with the exception of the reclassification of certain prior year amounts on our Consolidated Statements of Income, Consolidated Balance Sheets, and Consolidated Statements of Cash Flows in accordance with accounting requirements for reporting discontinued operations (see Note 21) and the impacts related to the reclassification of regulatory assets and liabilities for the current portion (see Note 3).

 

Certain line items are presented in more detail on the 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 net cash flow provided by operating activities.

 

The following tables show the impact of the reclassifications of prior years (previously reported) amounts (dollars in thousands):

 

Statement of Income for the Year Ended
December, 2010

 

As
previously
reported

 

Reclassifications
for discontinued
operations

 

Amount reported
after reclassification
for discontinued
operations

 

Operating Revenues

 

 

 

 

 

 

 

Other revenues

 

$

82,967

 

$

(74,446

)

$

8,521

 

Operating Expenses

 

 

 

 

 

 

 

Operations and maintenance

 

877,406

 

(7,221

)

870,185

 

Depreciation and amortization

 

414,555

 

(76

)

414,479

 

Taxes other than income taxes

 

135,334

 

(6

)

135,328

 

Other expenses

 

65,651

 

(58,142

)

7,509

 

Other

 

 

 

 

 

 

 

Other income

 

6,368

 

19

 

6,387

 

Other expense

 

(9,764

)

(157

)

(9,921

)

Interest Expense

 

 

 

 

 

 

 

Allowance for borrowed funds used during construction

 

(16,539

)

60

 

(16,479

)

Income Taxes

 

164,321

 

(3,452

)

160,869

 

Income From Continuing Operations

 

350,598

 

(5,747

)

344,851

 

Income From Discontinued Operations

 

19,611

 

5,747

 

25,358

 

 

Statement of Income for the Year Ended
December, 2009

 

As
previously
reported

 

Reclassifications
for discontinued
operations

 

Amount reported
after reclassification
for discontinued
operations

 

Operating Revenues

 

 

 

 

 

 

 

Other revenues

 

$

26,723

 

$

(22,254

)

$

4,469

 

Operating Expenses

 

 

 

 

 

 

 

Operations and maintenance

 

831,863

 

(9,563

)

822,300

 

Depreciation and amortization

 

407,463

 

(109

)

407,354

 

Taxes other than income taxes

 

123,277

 

(7

)

123,270

 

Other expenses

 

24,534

 

(18,550

)

5,984

 

Other

 

 

 

 

 

 

 

Other income

 

5,278

 

(119

)

5,159

 

Other expense

 

(14,269

)

(31

)

(14,300

)

Interest Expense

 

 

 

 

 

 

 

Interest charges

 

237,527

 

239

 

237,766

 

Allowance for borrowed funds used during construction

 

(10,430

)

51

 

(10,379

)

Income Taxes

 

136,506

 

2,045

 

138,551

 

Income From Continuing Operations

 

252,558

 

3,490

 

256,048

 

Income From Discontinued Operations

 

(179,794

)

(3,490

)

(183,284

)

 

Balance Sheets - December 31, 2010

 

As
previously
reported

 

Reclassifications for
regulatory assets and
liabilities

 

Amount reported
after reclassification
for regulatory assets
and liabilities

 

Current Assets — Other regulatory assets

 

$

 

$

62,286

 

$

62,286

 

Current Assets — Deferred income taxes

 

94,602

 

30,295

 

124,897

 

Deferred Debits — Regulatory assets

 

1,048,656

 

(62,286

)

986,370

 

Current Liabilities — Deferred fuel and purchased power regulatory liability

 

 

58,442

 

58,442

 

Current Liabilities — Other regulatory liabilities

 

 

80,526

 

80,526

 

Deferred Credits and Other — Deferred income taxes

 

1,833,566

 

30,295

 

1,863,861

 

Deferred Credits and Other — Deferred fuel and purchased power regulatory liability

 

58,442

 

(58,442

)

 

Deferred Credits and Other — Regulatory liabilities

 

694,589

 

(80,526

)

614,063

 

 

Statement of Cash Flows for the
Year Ended December 31, 2010

 

As previously
reported

 

Reclassifications for
regulatory assets and
liabilities and to
conform to current year
presentation

 

Amounts reported
after reclassification
for regulatory assets
and liabilities and to
conform to current
year presentation

 

Cash Flows from Operating Activities

 

 

 

 

 

 

 

Other current assets

 

$

5,246

 

$

4,129

 

$

9,375

 

Other current liabilities

 

5,204

 

(2,283

)

2,921

 

Change in other regulatory liabilities

 

54,518

 

2,283

 

56,801

 

Change in other long-term assets

 

(43,189

)

(4,751

)

(47,940

)

Expenditures for real estate investments

 

(622

)

622

 

 

Other changes in real estate assets

 

4,068

 

(4,068

)

 

Change in other long-term liabilities

 

(101,456

)

4,068

 

(97,388

)

 

Statement of Cash Flows for the
Year Ended December 31, 2009

 

As previously
reported

 

Reclassifications for
regulatory assets and
liabilities and to
conform to current year
presentation

 

Amounts reported after
reclassification for
regulatory assets and
liabilities and to
conform to current year
presentation

 

Cash Flows from Operating Activities

 

 

 

 

 

 

 

Other current assets

 

$

 24,647

 

$

 13,759

 

$

 38,406

 

Other current liabilities

 

29,274

 

28,006

 

57,280

 

Change in other regulatory liabilities

 

110,642

 

(27,992

)

82,650

 

Change in other long-term assets

 

(47,899

)

(16,730

)

(64,629

)

Change in other long-term liabilities

 

16,377

 

(4,216

)

12,161

 

Expenditures for real estate investments

 

(2,957

)

2,957

 

 

Other changes in real estate assets

 

(4,216

)

4,216

 

 

 

Accounting Records and Use of Estimates

 

Our accounting records are maintained in accordance with accounting principles generally accepted in the United States of America (“GAAP”).  The preparation of financial statements in accordance with GAAP requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities, disclosure of contingent assets and liabilities at the date of the financial statements and reported amounts of revenues and expenses during the reporting period.  Actual results could differ from those estimates.

 

Regulatory Accounting

 

APS is regulated by the ACC and the 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 other regulated entities in the same jurisdiction.  This determination reflects the current political and regulatory climate in the state 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 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.

 

Effective January 1, 2010, electric revenues also include proceeds for line extension payments for new or upgraded service in accordance with the 2009 retail rate case settlement agreement (see Note 3).  This revenue treatment continues through 2012, or until new rates are established in APS’s next general retail rate case, if that is before year end 2012.  Certain proceeds received under previous versions of the line extension policy, or for activities not involving an extension or upgrade of service (e.g., service relocations at the request of governmental entities or undergrounding of overhead facilities) will continue to be treated as contributions in aid of construction and will not impact electric revenues.

 

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.

 

Utility Plant and Depreciation

 

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 for the asset retirement obligations related to its regulated assets.  This regulatory liability represents 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 capitalized 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, 2011 were as follows:

 

·                                          Fossil plant — 18 years;

·                                          Nuclear plant — 29 years;

·                                          Other generation — 28 years;

·                                          Transmission — 38 years;

·                                          Distribution — 35 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 new Palo Verde Nuclear plant lives, effective January 1, 2012.

 

For the years 2009 through 2011, the depreciation rates ranged from a low of 1.30% to a high of 10.20%.  The weighted-average rate was 2.98% for 2011, 2.98% for 2010, and 3.06% for 2009.

 

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 10.25% for 2011, 9.2% for 2010, and 5.9% for 2009.  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 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 unobservable inputs, such as models and other valuation methods, 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 that may qualify as derivatives, including futures, forwards, options and swaps. As part of our overall risk management program, we use such instruments to hedge purchases and sales of electricity and fuels. The changes in market value of such contracts have a high correlation to price changes in the hedged transactions.

 

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 18 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 another postretirement benefit plan for the employees of Pinnacle West and our subsidiaries and provide 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 and Note 23 for information on nuclear decommissioning 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 liability 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.

 

Real Estate Investments

 

We did not have any real estate investments at December 31, 2011 and December 31, 2010 on our Consolidated Balance Sheets.  For the purposes of evaluating impairment, in accordance with the provisions on accounting for the impairment or disposal of long-lived assets; we classified our real estate assets, such as land under development, land held for future development, and commercial property as “held and used” in 2010 and 2009.  When events or changes in circumstances indicated that the carrying values of real estate assets considered held and used would not be recoverable, we compared the undiscounted cash flows that we estimated would be generated by each asset to its carrying amount.  If the carrying amount exceeded the undiscounted cash flows, we adjusted the asset to fair value and recognized an impairment charge.  The adjusted value became the new book value (carrying amount) for held and used assets.  Our internal models used inputs that we believe were consistent with those that would be used by market participants.

 

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.

 

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 $47 million in 2011, $45 million in 2010, and $35 million in 2009. Estimated amortization expense on existing intangible assets over the next five years is $42 million in 2012, $35 million in 2013, $28 million in 2014, $21 million in 2015, and $13 million in 2016. At December 31, 2011, the weighted average remaining amortization period for intangible assets was 7 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 23 for more information on these investments.

New Accounting Standards
New Accounting Standards

 

 

2.                                      New Accounting Standards

 

In May 2011, the FASB issued amended guidance to converge fair value measurement and disclosure requirements for GAAP and IFRS. The amended guidance clarifies how certain fair value measurement principles should be applied and requires enhanced fair value disclosures.  The guidance is effective for us on January 1, 2012.  The adoption of this new guidance will result in additional fair value disclosures, but will not impact our financial statement results.

 

In June 2011, the FASB issued amended guidance on the presentation of comprehensive income intended to increase the prominence of items reported in other comprehensive income and to facilitate convergence with IFRS.  The amended guidance requires entities to present total comprehensive income, which includes components of net income and components of other comprehensive income, in either a single continuous statement of comprehensive income or in two separate but consecutive statements.  The guidance is effective for us on January 1, 2012. The guidance will change our presentation of comprehensive income, but will not impact our financial statement results.

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 increase the average retail customer bill approximately 6.6%.  The filing is based on a test year ended December 31, 2010, adjusted as described below.  On January 6, 2012, APS and other parties to APS’s pending general retail rate case entered into an agreement (the “Settlement Agreement”) detailing the terms upon which the parties have agreed to settle the rate case.  The Settlement Agreement requires the approval of the ACC.  Evidentiary hearings on the matter were completed on February 3, 2012.  Opening briefs from parties are due February 29, 2012 and responsive briefs are due March 14, 2012.  See below for details regarding the Settlement Agreement.

 

The key financial provisions of APS’s original request included:

 

·                                          an increase in non-fuel base rates of $194.1 million, before the reclassification into base rates of $44.9 million of revenues related to solar generation projects collected through APS’s renewable energy surcharge (which will increase base rates) and $143.5 million of lower fuel and purchased power costs currently addressed through the PSA (which will decrease base rates);

 

·                                          a rate base of $5.7 billion, which approximates the ACC-jurisdictional portion of the book value of utility assets, net of accumulated depreciation and other credits, as of December 31, 2010, subject to certain adjustments, including plant additions under construction at the end of the test year that are currently in service or expected to be placed into service before the proposed rates are requested to become effective;

 

·                                          the following proposed capital structure and costs of capital:

 

 

 

Capital Structure

 

Cost of Capital

 

Long-term debt

 

46.1

%

6.38

%

Common stock equity

 

53.9

%

11.00

%

Weighted-average cost of capital

 

 

 

8.87

%

 

·                                          a Base Fuel Rate of $0.03242 per kWh based on estimated 2012 prices (a decrease from the current Base Fuel Rate of $0.03757 per kWh).

 

APS proposed that its PSA be modified to allow full pass-through of all fuel and purchased power costs, instead of the current 90/10 sharing provision.  In addition, APS proposed a decoupling mechanism, which would address recovery of APS’s fixed costs after reflecting implementation of ACC-mandated energy efficiency standards and renewable distributed generation.

 

Settlement Agreement

 

The 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 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 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 Settlement Agreement.

 

Other key provisions of the 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 proposed acquisition (should it be consummated) of additional interests in Units 4 and 5 and the related closure of Units 1-3 of the Four Corners Power Plant;

 

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

 

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

 

·                                          Modifications to the PSA, including the elimination of the current 90/10 sharing provision;

 

·                                          Allowing a negative credit that currently exists in the PSA 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.

 

If the Settlement Agreement is approved by the ACC, APS expects that its provisions will become effective on or about July 1, 2012.  As is the case with all such agreements, APS cannot predict whether the Settlement Agreement will be approved in the form filed or what changes may be ordered by the ACC and accepted by the parties.

 

2008 General Retail Rate Case Impacts

 

On December 30, 2009, the ACC issued an order approving a settlement agreement entered into by APS and twenty-one other parties in APS’s prior general retail rate case, which was originally filed in March 2008.  The settlement agreement included a net retail rate increase of $207.5 million, which represented a base rate increase of $344.7 million less a reclassification of $137.2 million of fuel and purchased power revenues from the then-existing PSA to base rates.  The new rates were effective January 1, 2010.  The settlement agreement also contained on-going requirements, commitments and authorizations, including the following:

 

·                                          Revenue accounting treatment for line extension payments received for new or upgraded service from January 1, 2010 through year end 2012 (or until new rates are established in APS’s next general rate case, if that is before the end of 2012);

 

·                                          An authorized return on common equity of 11%;

 

·                                          A capital structure comprised of 46.2% debt and 53.8% common equity;

 

·                                          A commitment from APS to reduce average annual operational expenses by at least $30 million from 2010 through 2014 (APS filed a notification with the ACC on April 29, 2011, demonstrating its compliance with this provision in 2010);

 

·                                          Authorization and requirements of equity infusions into APS of at least $700 million during the period beginning June 1, 2009 through December 31, 2014 ($253 million of which was infused into APS from proceeds of a Pinnacle West equity issuance in the second quarter of 2010); and

 

·                                          Various modifications to the existing energy efficiency, demand-side management and renewable energy programs that require APS to, among other things, expand its conservation and demand-side management programs and its use of renewable energy, as well as allow for concurrent recovery of renewable energy expenses and provide for more concurrent recovery of demand-side management costs and incentives.

 

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 1, 2011, APS filed its annual RES implementation plan, covering the 2012-2016  timeframe and requesting 2012 RES funding of $129 million to $152 million.  On December 14, 2011, the ACC voted to approve APS’s 2012 RES Plan and authorized a total 2012 RES budget of $110 million.  Within that budget, the ACC authorized APS to, among other items, (i) own an additional 100 MW under the AZ Sun Program, for a total of 200 MW; (ii) recover revenue requirements for the second 100 MW as APS did for the first 100 MW of the AZ Sun Program; (iii) expand APS’s School and Government Program by another 6.25 MW of utility owned distributed generation; and (iv) own another 25 MW of renewable generation to be described later and installed in 2014 and 2015.  In addition, the ACC ordered an initial up front incentive of $0.75 per watt for residential distributed energy and incentive level step downs throughout 2012 based upon the volume and timing of residential incentive applications.  Under the ACC’s order, residential incentives could fall to $0.20 or $0.10 per watt by the end of 2012 depending on demand.

 

Demand-Side Management Adjustor Charge (“DSMAC”).  The 2008 retail rate case settlement agreement requires APS to submit an annual Energy Efficiency Implementation Plan for review by and approval of the ACC.  In 2010, the DSMAC was modified to recover estimated amounts for use on certain demand-side management programs over the current year.  Previously, the DSMAC allowed for such recovery only on a historical or after-the-fact basis.  The surcharge allows for the recovery of energy efficiency expenses and any earned incentives.

 

The ACC previously approved recovery of all 2009 program costs plus incentives.  The change from program cost recovery on a historical basis to recovery on a concurrent basis, as authorized in the 2009 retail rate case settlement agreement, resulted in this one-time need to address two years (2009 and 2010) of cost recovery.  As requested by APS, 2009 program cost recovery is to be amortized over a three-year period.

 

On June 1, 2010, APS filed its 2011 Energy Efficiency Implementation Plan. In order to meet the energy efficiency goal for 2011 established by the settlement agreement of annual energy savings of 1.25%, expressed as a percent of total energy resources to meet retail load, APS proposed a total budget for 2011 of $79 million.  On February 17, 2011, a total budget for 2011 of $80 million was approved and, when added to the amortization of 2009 program costs discussed above less the $10 million already being recovered in general rates, the DSMAC would recover approximately $75 million over a twelve-month period beginning March 1, 2011.

 

On June 1, 2011, APS filed its 2012 Energy Efficiency Implementation Plan to meet the energy efficiency requirements of the ACC’s Energy Efficiency Rules, which became effective January 1, 2011. The 2012 requirement under such rules is for energy efficiency savings of 1.75% of APS retail sales for the prior year. This energy savings requirement is slightly higher than the goal established by the settlement agreement related to APS’s 2008 retail rate case (1.5% of total energy resources). APS proposed a budget for 2012 of $90 million. When added to the third and final year of the amortization of 2009 program costs authorized in 2009 and less the $10 million already being recovered in general rates, the proposed 2012 DSMAC would recover approximately $85 million over a twelve month period beginning March 1, 2012.  APS expects a decision from the ACC prior to March 31, 2012.

 

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;

 

·                                          under a 90/10 sharing arrangement, APS defers 90% of the difference between retail fuel and purchased power costs (excluding certain costs, such as renewable energy resources and the capacity components of long-term purchased power agreements acquired through competitive procurement) and the Base Fuel Rate; APS absorbs 10% of the retail fuel and purchased power costs above the Base Fuel Rate and retains 10% of the benefit from the retail fuel and purchased power costs that are below the Base Fuel Rate (see “Settlement Agreement” above for information regarding the elimination of this arrangement);

 

·                                          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 (liability) for 2011 and 2010 (dollars in millions):

 

 

 

Year Ended
December 31,

 

 

 

2011

 

2010

 

Beginning balance

 

$

(58

)

$

(87

)

Deferred fuel and purchased power costs-current period

 

(69

)

(93

)

Amounts refunded through revenues

 

155

 

122

 

Ending balance

 

$

28

 

$

(58

)

 

The PSA rate for the PSA year beginning February 1, 2012 is ($0.0042) per kWh as compared to ($0.0057) per kWh for the prior year.  Any uncollected (overcollected) deferrals during the 2012 PSA year will be included in the calculation of the PSA rate for the PSA year beginning February 1, 2013.

 

Transmission Rates and Transmission Cost AdjustorIn July 2008, the 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 must file an application with, and obtain approval from, the ACC to reflect changes in Retail Transmission Charges through the TCA.  If the Settlement Agreement (discussed above) is approved, 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-collected amounts.

 

Effective June 1, 2011, APS’s annual wholesale transmission rates for all users of its transmission system increased by approximately $44 million for the twelve-month period beginning June 1, 2011 in accordance with the FERC-approved formula as a result of higher costs and lower revenues reflected in the formula.  Approximately $38 million of this revenue increase relates to Retail Transmission Charges.  The ACC approved the related increase of APS’s TCA rate on June 21, 2011 and it became effective on July 1, 2011.

 

Regulatory Assets and Liabilities

 

As discussed in Note 1, as of March 31, 2011, the Company revised its presentation of regulatory assets and liabilities to separately reflect current and non-current amounts on the Consolidated Balance Sheets.  This presentation is reflected in the tables below.

 

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

 

 

 

Remaining
Amortization

 

December 31, 2011

 

December 31, 2010

 

 

 

Period

 

Current

 

Non-Current

 

Current

 

Non-Current

 

Pension and other postretirement benefits

 

(a)

 

$

 

$

1,023

 

$

 

$

669

 

Income taxes —AFUDC equity

 

2041

 

3

 

81

 

3

 

69

 

Deferred fuel and purchased power — mark-to-market (Note 18)

 

2016

 

43

 

34

 

42

 

35

 

Transmission vegetation management

 

2016

 

9

 

32

 

 

46

 

Coal reclamation

 

2026

 

2

 

35

 

2

 

36

 

Palo Verde VIE (Note 20)

 

2015

 

 

35

 

 

33

 

Deferred compensation

 

2036

 

 

33

 

 

32

 

Deferred fuel and purchased power (b)

 

2012

 

28

 

 

 

 

Income taxes — Medicare subsidy

 

2024

 

2

 

18

 

2

 

21

 

Loss on reacquired debt

 

2034

 

1

 

19

 

1

 

21

 

Income taxes — investment tax credit basis adjustment

 

2044

 

 

15

 

 

 

Pension and other postretirement benefits deferral

 

2015

 

 

12

 

 

 

Demand side management

 

2013

 

7

 

1

 

12

 

6

 

Other

 

Various

 

2

 

14

 

 

18

 

Total regulatory assets (c)

 

 

 

$

97

 

$

1,352

 

$

62

 

$

986

 

 

(a)                                  This asset represents the future recovery in earnings of under-funded pension and other postretirement benefits obligation costs 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.

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

(c)                                  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
Amortization

 

December 31, 2011

 

December 31, 2010

 

 

 

Period

 

Current

 

Non-Current

 

Current

 

Non-Current

 

Removal costs

 

(a)

 

$

22

 

$

349

 

$

22

 

$

357

 

Asset retirement obligations

 

(a)

 

 

225

 

 

184

 

Renewable energy standard (b)

 

2012

 

54

 

 

50

 

 

Income taxes — change in rates

 

2041

 

 

59

 

 

 

Spent nuclear fuel

 

2047

 

5

 

44

 

4

 

41

 

Deferred gains on utility property

 

2019

 

2

 

14

 

2

 

16

 

Income taxes-unamortized investment tax credit

 

2044

 

1

 

30

 

 

1

 

Deferred fuel and purchased power (b)(c)

 

 

 

 

 

58

 

 

Other

 

Various

 

4

 

16

 

3

 

15

 

Total regulatory liabilities

 

 

 

$

88

 

$

737

 

$

139

 

$

614

 

 

(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.

(c)                                  Subject to a carrying charge.

Income Taxes
Income Taxes

 

 

4.                                      Income Taxes

 

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 the 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 investment tax credits 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 $69 million long-term income tax receivable on the Consolidated Balance Sheets represents the anticipated refunds related to an APS tax accounting method change approved by the IRS in the third quarter of 2009.  This amount is classified as long-term, as cash refunds are not expected to be received in the next twelve months.

 

During the first quarter of 2010, the Company reached a settlement with the IRS with regard to the examination of tax returns for the years ended December 31, 2005 through 2007.  As a result of this settlement, net uncertain tax positions decreased $62 million, including approximately $3 million which decreased our effective tax rate.  Additionally, the settlement resulted in the recognition of net interest benefits of approximately $4 million through the effective tax rate.

 

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):

 

 

 

2011

 

2010

 

2009

 

Total unrecognized tax benefits, January 1

 

$

127,595

 

$

201,216

 

$

63,318

 

Additions for tax positions of the current year

 

10,915

 

7,551

 

44,094

 

Additions for tax positions of prior years

 

 

 

98,942

 

Reductions for tax positions of prior years for:

 

 

 

 

 

 

 

Changes in judgment

 

(1,555

)

(11,017

)

 

Settlements with taxing authorities

 

(124

)

(62,199

)

(4,089

)

Lapses of applicable statute of limitations

 

(826

)

(7,956

)

(1,049

)

Total unrecognized tax benefits, December 31

 

$

136,005

 

$

127,595

 

$

201,216

 

 

Included in the balances of unrecognized tax benefits at December 31, 2011, 2010 and 2009 were approximately $8 million, $7 million and $16 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, 2008 and all subsequent tax years remain subject to examination by the IRS.  With few exceptions, we are no longer subject to state income tax examinations by tax authorities for years prior to 2006.  We do not anticipate that there will be any significant increases or decreases in our unrecognized tax benefits within the next twelve months.

 

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 Statement of Income related to unrecognized tax benefits was a pre-tax expense of $3 million for 2011, a pre-tax benefit of $2 million for 2010 and a pre-tax expense of $2 million for 2009.

 

The total amount of accrued liabilities for interest recognized in the Consolidated Balance Sheets related to unrecognized tax benefits was $9 million as of December 31, 2011, $6 million as of December 31, 2010 and $8 million as of December 31, 2009.  To the extent that matters are settled favorably, this amount could reverse and decrease our effective tax rate.  Additionally, as of December 31, 2011, we have recognized $4 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,

 

 

 

2011

 

2010

 

2009

 

Current:

 

 

 

 

 

 

 

Federal

 

$

(310

)

$

(108,827

)

$

(38,502

)

State

 

15,140

 

25,545

 

(38,080

)

Total current

 

14,830

 

(83,282

)

(76,582

)

Deferred:

 

 

 

 

 

 

 

Federal

 

159,566

 

260,236

 

62,874

 

State

 

16,626

 

10,911

 

42,618

 

Discontinued operations

 

 

(10,736

)

 

Total deferred

 

176,192

 

260,411

 

105,492

 

Total income tax expense

 

191,022

 

177,129

 

28,910

 

Less: income tax expense (benefit) on discontinued operations

 

7,418

 

16,260

 

(109,641

)

Income tax expense — continuing operations

 

$

183,604

 

$

160,869

 

$

138,551

 

 

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,

 

 

 

2011

 

2010

 

2009

 

 

 

 

 

 

 

 

 

Federal income tax expense at 35% statutory rate

 

$

188,733

 

$

177,002

 

$

138,110

 

Increases (reductions) in tax expense resulting from:

 

 

 

 

 

 

 

State income tax net of federal income tax benefit

 

19,594

 

17,485

 

15,068

 

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

 

 

(17,300

)

 

Medicare Subsidy Part-D

 

823

 

1,311

 

(2,095

)

Allowance for equity funds used during construction (see Note 1)

 

(6,881

)

(6,563

)

(4,265

)

Palo Verde VIE noncontrolling interest (see Note 20)

 

(9,636

)

(7,057

)

(6,723

)

Other

 

(9,029

)

(4,009

)

(1,544

)

Income tax expense — continuing operations

 

$

183,604

 

$

160,869

 

$

138,551

 

 

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

 

 

 

December 31,

 

 

 

2011

 

2010

 

Current asset

 

$

130,571

 

$

124,897

 

Long-term liability

 

(1,925,388

)

(1,863,861

)

Deferred income taxes — net

 

$

(1,794,817

)

$

(1,738,964

)

 

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. In 2011, APS increased regulatory liabilities by a total of $62 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,

 

 

 

2011

 

2010

 

DEFERRED TAX ASSETS

 

 

 

 

 

Risk management activities

 

$

117,765

 

$

124,731

 

Regulatory liabilities:

 

 

 

 

 

Asset retirement obligation and removal costs

 

236,739

 

222,448

 

Deferred fuel and purchased power

 

 

23,089

 

Renewable energy standard

 

19,722

 

18,749

 

Unamortized investment tax credits

 

31,460

 

642

 

Other

 

33,155

 

27,718

 

Pension and other postretirement liabilities

 

501,202

 

321,182

 

Real estate investments and assets held for sale

 

 

19,855

 

Renewable energy incentives

 

57,901

 

37,327

 

Credit and loss carryforwards

 

171,915

 

42,971

 

Other

 

73,759

 

68,684

 

Total deferred tax assets

 

1,243,618

 

907,396

 

DEFERRED TAX LIABILITIES

 

 

 

 

 

Plant-related

 

(2,446,908

)

(2,210,976

)

Risk management activities

 

(30,171

)

(30,125

)

Regulatory assets:

 

 

 

 

 

Allowance for equity funds used during construction

 

(33,347

)

(28,276

)

Deferred fuel and purchased power

 

(10,884

)

 

Deferred fuel and purchased power — mark-to-market

 

(30,559

)

(30,276

)

Pension and other postretirement benefits

 

(408,716

)

(264,313

)

Other

 

(73,087

)

(77,078

)

Other

 

(4,763

)

(5,316

)

Total deferred tax liabilities

 

(3,038,435

)

(2,646,360

)

Deferred income taxes — net

 

$

(1,794,817

)

$

(1,738,964

)

 

As of December 31, 2011, the deferred tax assets for credit and loss carryforwards relate to federal general business credits ($67 million) and federal net operating losses ($92 million), both of which first begin to expire in 2029, and other federal and state loss carryforwards ($13 million) which first begin to expire in 2014.

Lines of Credit and Short-Term Borrowings
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, 2011 (dollars in millions):

 

Credit Facility

 

Expiration

 

Amount
Committed

 

Unused
Amount

 

Commitment
Fees

 

Pinnacle West Revolving Credit Facility

 

November 2016

 

$

200

 

$

200

 

0.275

%

 

 

 

 

 

 

 

 

 

 

APS Revolving Credit Facility

 

November 2016

 

500

 

500

 

0.225

%

 

 

 

 

 

 

 

 

 

 

APS Revolving Credit Facility

 

February 2015

 

500

 

500

 

0.250

%

Total

 

 

 

$

1,200

 

$

1,200

 

 

 

 

Pinnacle West and APS maintain committed revolving credit facilities in order to enhance liquidity and provide credit support for their commercial paper programs.  During the first quarter of 2011, APS refinanced an existing revolving credit facility (as discussed below) that would have otherwise matured in September 2011.   During the fourth quarter of 2011, APS and Pinnacle West refinanced the existing credit facilities (as discussed below) that would have otherwise matured in February 2013.

 

Pinnacle West

 

On November 4, 2011, Pinnacle West refinanced its $200 million revolving credit facility that would have matured in February 2013, with a new $200 million facility.  The new revolving credit facility terminates in November 2016.  Interest rates are based on Pinnacle West senior unsecured debt credit ratings.

 

At December 31, 2011, the Pinnacle West credit facility 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, 2011, Pinnacle West had no outstanding borrowings under its credit facility, no letters of credit and no commercial paper borrowings.

 

APS

 

On February 14, 2011, APS refinanced its $489 million revolving credit facility that would have matured in September 2011, and increased the size of the facility to $500 million.  The new revolving credit facility terminates in February 2015.  APS may increase the amount of the facility up to a maximum of $700 million upon the satisfaction of certain conditions and with the consent of the lenders.  APS will use the facility to refinance indebtedness and for other general corporate purposes.  Interest rates are based on APS’s senior unsecured debt credit ratings.

 

On November 4, 2011, APS refinanced its $500 million revolving credit facility that would have matured in February 2013, with a new $500 million facility.  The new revolving credit facility terminates in November 2016.  APS may increase the amount of the facility up to a maximum of $700 million upon the satisfaction of certain conditions and with the consent of the lenders.  APS will use the facility 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 its $250 million commercial paper program, for bank borrowings or for issuances of letters of credit.  At December 31, 2011, APS had no borrowings outstanding under any of its credit facilities and no outstanding commercial paper.

 

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

 

The table below presents the consolidated credit facilities and amounts available and outstanding and other short-term borrowings as of December 31, 2010 (dollars in millions):

 

Credit
Facility

 

Expiration

 

Amount
Committed

 

Letters
of
Credit
Used

 

Short-Term
Borrowings

 

Unused
Amount

 

Weighted
Average
Interest
Rate

 

Commitment
Fees

 

Pinnacle West Revolving Credit Facility

 

February 2013

 

$

200

 

$

 

$

 

$

183

 

 

0.625

%

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Pinnacle West Commercial Paper

 

January 2011

 

 

 

17

 

 

0.840

%

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

APS Revolving Credit Facility

 

February  2013

 

500

 

 

 

500

 

 

0.500

%

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

APS Revolving Credit Facility

 

September 2011

 

489

 

20

 

 

469

 

 

0.100

%

Total

 

 

 

$

1,189

 

$

20

 

$

17

 

$

1,152

 

 

 

 

 

 

Pinnacle West

 

On February 12, 2010, Pinnacle West refinanced its $283 million revolving credit facility that would have matured in December 2010, and decreased the size of the facility to $200 million.  This facility was refinanced on November 4, 2011.

 

APS

 

On February 12, 2010, APS refinanced its $377 million credit facility that would have matured in December 2010, and increased the size of the facility to $500 million.  This facility was refinanced on November 4, 2011.

 

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 October 30, 2007, the ACC issued a financing order in which it approved APS’s request, subject to specified parameters and procedures, to increase (a) APS’s short-term debt authorization from 7% of APS’s capitalization to (i) 7% of APS’s capitalization plus (ii) $500 million (which is required to be used for purchases of natural gas and power) and (b) APS’s long-term debt authorization from approximately $3.2 billion to $4.2 billion in light of the projected growth of APS and its customer base and the resulting projected financing needs. This financing order expires December 31, 2012; however, all debt previously authorized and outstanding on December 31, 2012 will remain authorized and valid obligations of APS.

 

On November 22, 2011, APS filed a financing application with the ACC requesting an increase in APS’s long-term debt authorization (approximately $4.2 billion) to approximately $5.5 billion in light of the projected financing needed to fund APS’s capital expenditure and maintenance program and other cash requirements.  In addition, APS requested authorization to (i) allow for other types of securities providing long-term capital financing, including preferred stock, trust preferred securities or other forms of hybrid securities, and (ii) manage interest rate risks and exposure associated with any long-term or short-term indebtedness authorized by the ACC.

 

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, 2011 and 2010 (dollars in thousands):

 

 

 

Maturity

 

Interest

 

December 31,

 

 

 

Dates (a)

 

Rates

 

2011

 

2010

 

APS

 

 

 

 

 

 

 

 

 

Pollution Control Bonds:

 

 

 

 

 

 

 

 

 

Variable

 

2024-2038

 

(b)

 

$

43,580

 

$

43,580

 

Fixed

 

2029-2034

 

2.875%-6.000%

 

522,275

 

522,275

 

Pollution control bonds with senior notes

 

2029

 

5.050%

 

90,000

 

90,000

 

Total Pollution Control Bonds

 

 

 

 

 

655,855

 

655,855

 

 

 

 

 

 

 

 

 

 

 

Senior unsecured notes

 

2012-2041

 

4.650%-8.750%

 

2,625,000

 

2,725,000

 

Palo Verde sale leaseback lessor notes

 

2015

 

8.00%

 

96,803

 

126,000

 

Capitalized lease obligations

 

2012

 

(c)

 

1,029

 

2,001

 

Unamortized discount

 

 

 

 

 

(7,198

)

(6,183

)

Total APS Long-term debt

 

 

 

 

 

3,371,489

 

3,502,673

 

Less current maturities

 

 

 

 

 

477,435

 

456,879

 

Total APS Long-term debt less current maturities

 

 

 

 

 

2,894,054

 

3,045,794

 

Pinnacle West

 

 

 

 

 

 

 

 

 

Senior notes

 

2011

 

5.91%

 

 

175,000

 

Term loan

 

2015

 

(d)

 

125,000

 

 

Total Pinnacle West Long-term debt

 

 

 

 

 

125,000

 

175,000

 

Less current maturities

 

 

 

 

 

 

175,000

 

Total Pinnacle West long-term debt less current maturities

 

 

 

 

 

125,000

 

 

TOTAL LONG-TERM DEBT LESS CURRENT MATURITIES

 

 

 

 

 

$

3,019,054

 

$

3,045,794

 

 

(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 0.09% at December 31, 2011 and 0.32% at December 31, 2010.

(c)           The weighted-average interest rate was 5.27% at December 31, 2011 and 5.29% at December 31, 2010.

(d)           The weighted-average interest rate was 1.794% at December 31, 2011.

 

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

 

Year

 

Consolidated
Pinnacle West

 

Consolidated
APS

 

2012

 

$

477

 

$

477

 

2013

 

123

 

123

 

2014

 

502

 

502

 

2015

 

438

 

313

 

2016

 

358

 

358

 

Thereafter

 

1,606

 

1,606

 

Total

 

$

3,504

 

$

3,379

 

 

Debt Fair Value

 

Our long-term debt fair value estimates are based on quoted market prices of the same or similar issues. 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
December 31, 2011

 

As of
December 31, 2010

 

 

 

Carrying
Amount

 

Fair Value

 

Carrying
Amount

 

Fair Value

 

 

 

 

 

 

 

 

 

 

 

Pinnacle West

 

$

125

 

$

123

 

$

175

 

$

176

 

APS

 

3,371

 

3,803

 

3,503

 

3,737

 

Total

 

$

3,496

 

$

3,926

 

$

3,678

 

$

3,913

 

 

Credit Facilities and Debt Issuances

 

Pinnacle West

 

On February 23, 2011, Pinnacle West entered into a $175 million term loan facility that matures February 20, 2015.  Pinnacle West used the proceeds of the loan to repay its 5.91% $175 million Senior Notes.  Interest rates are based on Pinnacle West’s senior unsecured debt credit ratings or, if unavailable, its long-term issuer ratings.  As of December 31, 2011, $50 million of the $175 million term loan facility had been repaid.

 

APS

 

On August 25, 2011, APS issued $300 million of 5.05% unsecured senior notes that mature on September 1, 2041. The net proceeds from the sale of the notes were used along with cash on hand to repay at maturity APS’s $400 million aggregate principal amount of 6.375% senior notes due October 15, 2011.

 

On September 7, 2011, APS entered into a new letter of credit agreement supporting its approximately $27 million aggregate principal amount of Coconino County, Arizona Pollution Control Corporation Pollution Control Revenue Refunding Bonds (Arizona Public Service Company Navajo Project), 2009 Series B. The agreement expires September 22, 2016.

 

On December 8, 2011, APS extended a letter of credit agreement supporting its approximately $17 million aggregate principal amount of Coconino County, Arizona Pollution Control Corporation Pollution Control Revenue Bonds (Arizona Public Service Company Project), 1998.  The agreement expires December 8, 2016.

 

On January 10, 2012, APS issued $325 million of 4.50% unsecured senior notes that mature on April 1, 2042.  The net proceeds from the sale will be used along with other funds to repay at maturity APS’s $375 million aggregate principal amount of 6.50% senior notes due March 1, 2012.

 

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, 2011, the ratio was approximately 47% for Pinnacle West and 46% 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, 2011, APS was in compliance with this common equity ratio requirement.  Its total shareholder equity was approximately $3.9 billion, and total capitalization was approximately $7.2 billion. APS would be prohibited from paying dividends if the payment would reduce its total shareholder equity below approximately $2.9 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 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 2011, 2010 and 2009 is as follows (dollars in thousands):

 

 

 

Common Stock

 

Treasury Stock

 

 

 

Shares

 

Amount

 

Shares

 

Amount

 

Balance at December 31, 2008

 

100,948,436

 

$

2,151,323

 

(59,827

)

$

(2,854

)

Common stock issuance

 

354,995

 

10,620

 

 

 

Purchase of treasury stock (a)

 

 

 

(66,173

)

(2,156

)

Reissuance of treasury stock for stock compensation

 

 

 

32,761

 

1,198

 

Other

 

224,506

 

(8,648

)

 

 

Balance at December 31, 2009

 

101,527,937

 

2,153,295

 

(93,239

)

(3,812

)

 

 

 

 

 

 

 

 

 

 

Common stock issuance (b)

 

7,172,405

 

263,297

 

 

 

Purchase of treasury stock (a)

 

 

 

(1,994

)

(82

)

Reissuance of treasury stock for stock compensation

 

 

 

44,823

 

1,655

 

Other

 

119,725

 

4,780

 

 

 

Balance at December 31, 2010

 

108,820,067

 

2,421,372

 

(50,410

)

(2,239

)

 

 

 

 

 

 

 

 

 

 

Common stock issuance

 

249,602

 

11,057

 

 

 

Purchase of treasury stock (a)

 

 

 

(88,440

)

(3,720

)

Reissuance of treasury stock for stock compensation

 

 

 

27,689

 

1,242

 

Other

 

287,305

 

11,818

 

 

 

Balance at December 31, 2011

 

109,356,974

 

$

2,444,247

 

(111,161

)

$

(4,717

)

 

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

(b)           In April 2010, Pinnacle West issued 6,900,000 shares of common stock at an offering price of $38.00 per share, resulting in net proceeds of approximately $253 million.  Pinnacle West contributed all of the net proceeds from this offering into APS in the form of equity infusions.  APS has used these contributions to repay short-term indebtedness, to finance capital expenditures and for other general corporate purposes.

 

At December 31, 2011, 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 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 another 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 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.  During 2011, we deferred pension and other postretirement benefit costs of approximately $12 million.

 

On March 23, 2010, the President signed into law comprehensive health care reform legislation under the Patient Protection and Affordable Care Act (the “Act”).  One feature of the Act is the elimination of the tax deduction for prescription drug costs that are reimbursed as part of the Medicare Part D subsidy.  Although this tax increase does not take effect until 2013, we are required to recognize the full accounting impact in our financial statements in the period in which the Act is signed.  In accordance with accounting for regulated companies, the loss of this deduction is substantially offset by a regulatory asset that will be recovered through future electric revenues.  In the first quarter of 2010, Pinnacle West charged regulatory assets for a total of $42 million, with a corresponding increase in accumulated deferred income tax liabilities, to reflect the impact of this change in tax law.

 

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

 

 

 

2011

 

2010

 

2009

 

2011

 

2010

 

2009

 

Service cost-benefits earned during the period

 

$

57,605

 

$

59,064

 

$

54,288

 

$

21,856

 

$

19,236

 

$

18,285

 

Interest cost on benefit obligation

 

124,727

 

122,724

 

118,282

 

46,807

 

42,428

 

39,180

 

Expected return on plan assets

 

(133,678

)

(124,161

)

(116,535

)

(41,536

)

(39,257

)

(34,428

)

Amortization of:

 

 

 

 

 

 

 

 

 

 

 

 

 

Transition obligation

 

 

 

 

452

 

452

 

3,005

 

Prior service cost (credit)

 

1,400

 

1,705

 

2,080

 

(179

)

(539

)

(125

)

Net actuarial loss

 

25,956

 

18,833

 

14,216

 

15,015

 

10,317

 

10,320

 

Net periodic benefit cost

 

$

76,010

 

$

78,165

 

$

72,331

 

$

42,415

 

$

32,637

 

$

36,237

 

Portion of cost charged to expense

 

$

29,312

 

$

37,933

 

$

36,484

 

$

15,208

 

$

15,839

 

$

18,278

 

 

The following table shows the plans’ changes in the benefit obligations and funded status for the years 2011 and 2010 (dollars in thousands):

 

 

 

Pension

 

Other Benefits

 

 

 

2011

 

2010

 

2011

 

2010

 

Change in Benefit Obligation

 

 

 

 

 

 

 

 

 

 

 

 

 

Benefit obligation at January 1

 

$

2,345,060

 

$

2,074,131

 

$

827,897

 

$

700,535

 

Service cost

 

57,605

 

59,064

 

21,856

 

19,236

 

Interest cost

 

124,727

 

122,724

 

46,807

 

42,428

 

Benefit payments

 

(104,257

)

(93,776

)

(24,877

)

(20,421

)

Actuarial loss

 

275,991

 

183,365

 

171,674

 

98,094

 

Plan amendments

 

 

(448

)

3,737

 

(11,975

)

Benefit obligation at December 31

 

2,699,126

 

2,345,060

 

1,047,094

 

827,897

 

 

 

 

 

 

 

 

 

 

 

Change in Plan Assets

 

 

 

 

 

 

 

 

 

Fair value of plan assets at January 1

 

1,775,596

 

1,461,808

 

567,410

 

490,455

 

Actual return on plan assets

 

162,042

 

190,380

 

58,367

 

60,255

 

Employer contributions

 

 

200,000

 

18,769

 

16,700

 

Benefit payments

 

(87,088

)

(76,592

)

(35,883

)

 

Fair value of plan assets at December 31

 

1,850,550

 

1,775,596

 

608,663

 

567,410

 

Funded Status at December 31

 

$

(848,576

)

$

(569,464

)

$

(438,431

)

$

(260,487

)

 

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, 2011 and 2010 (dollars in thousands):

 

 

 

2011

 

2010

 

Projected benefit obligation

 

$

2,699,126

 

$

2,345,060

 

Accumulated benefit obligation

 

2,396,575

 

2,065,091

 

Fair value of plan assets

 

1,850,550

 

1,775,596

 

 

The following table shows the amounts recognized on the Consolidated Balance Sheets as of December 31, 2011 and 2010 (dollars in thousands):

 

 

 

Pension

 

Other Benefits

 

 

 

2011

 

2010

 

2011

 

2010

 

Current liability

 

$

(18,097

)

$

(16,830

)

$

 

$

 

Noncurrent liability

 

(830,479

)

(552,634

)

(438,431

)

(260,487

)

Net amount recognized

 

$

(848,576

)

$

(569,464

)

$

(438,431

)

$

(260,487

)

 

The following table shows the details related to accumulated other comprehensive loss as of December 31, 2011 and 2010 (dollars in thousands):

 

 

 

Pension

 

Other Benefits

 

 

 

2011

 

2010

 

2011

 

2010

 

Net actuarial loss

 

$

724,605

 

$

502,938

 

$

400,892

 

$

261,071

 

Prior service cost (credit)

 

4,312

 

5,712

 

(655

)

(4,571

)

Transition obligation

 

 

 

452

 

903

 

APS’s portion recorded as a regulatory asset

 

(632,099

)

(419,774

)

(390,521

)

(249,255

)

Income tax benefit

 

(38,243

)

(35,106

)

(3,296

)

(2,498

)

Accumulated other comprehensive loss

 

$

58,575

 

$

53,770

 

$

6,872

 

$

5,650

 

 

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 2012 (dollars in thousands):

 

 

 

Pension

 

Other
Benefits

 

Net actuarial loss

 

$

43,070

 

$

23,638

 

Prior service cost (credit)

 

1,143

 

(179

)

Transition obligation

 

 

452

 

Total amounts estimated to be amortized from accumulated other comprehensive loss and regulatory assets in 2012

 

$

44,213

 

$

23,911

 

 

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
As of December 31,

 

Benefit Costs
For the Years Ended December 31,

 

 

 

2011

 

2010

 

2011

 

2010

 

2009

 

Discount rate-pension

 

4.42

%

5.31

%

5.31

%

5.90

%

6.11

%

Discount rate-other benefits

 

4.59

%

5.49

%

5.49

%

6.00

%

6.13

%

Rate of compensation increase

 

4.00

%

4.00

%

4.00

%

4.00

%

4.00

%

Expected long-term return on plan assets

 

N/A

 

N/A

 

7.75

%

8.25

%

8.25

%

Initial health care cost trend rate

 

7.50

%

8.00

%

8.00

%

8.00

%

8.00

%

Ultimate health care cost trend rate

 

5.00

%

5.00

%

5.00

%

5.00

%

5.00

%

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 the year 2012, we are assuming a 7.75% long-term rate of return on plan assets, which we believe is reasonable given our asset allocation in relation to historical and expected performance.

 

Assumed health care cost trend rates above have a significant effect on the amounts reported for the health care plans.  In selecting our health care trend rates, we consider past performance and forecasts of health care costs.  A one percentage point change in the assumed initial and ultimate health care 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

 

$

11

 

$

(9

)

Effect on service and interest cost components of net periodic other postretirement benefit costs

 

14

 

(11

)

Effect on the accumulated other postretirement benefit obligation

 

187

 

(148

)

 

Plan Assets

 

The Board of Directors has delegated oversight of the plans’ assets to an Investment Management Committee, which has adopted an investment policy.  The investment policy’s overall strategy is to achieve an adequate level of trust assets relative to the benefit obligations.  To achieve this objective, the plans’ investment policies provide for mixes of investments including long-term fixed income assets and return-generating assets.  Long-term fixed income assets are designed to offset changes in benefit obligations due to changes in discount rates and inflation.  Return-generating assets are intended to provide a reasonable long-term rate of investment return with a prudent level of volatility.  The determination of total allocation between return-generating and long-term fixed income assets is reviewed on at least an annual basis.  Other investment strategies include the external management of the plans’ assets, and the prohibition of investments in Pinnacle West securities.

 

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.  The investment policy does not provide for a specific mix of long-term fixed income assets, but does require the average credit rating of such assets to be considered upper medium grade or above.  The 2011 year-end long-term fixed income asset strategy focused on investments in corporate bonds of primarily investment-grade U.S. issuers and long-term treasuries, with total long-term fixed income assets representing 46% of total pension plan assets and 46% of other benefit plans assets.

 

Return-generating assets in the pension plan and other benefit plans target a mix of approximately 64% U.S. equities, 27% international equities, and 9% alternative investments.  The 2011 year-end U.S. equity holdings were invested primarily in large-cap companies in diverse industries.  International equities include investments in emerging and developing markets.  Return-generating assets also include investments in securities through commingled funds in common and collective trusts.  Alternative investments primarily include investments in real estate.  The 2011 year-end return-generating assets represented 54% of total pension plan assets and 54% of other benefit plans’ assets.

 

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 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 and interest rate curves.  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).  The common and collective equity trusts are valued using net asset value (“NAV”), which is 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, 2011 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 assess these valuations and verify that pricing can be supported by actual recent market transactions. Additionally, we obtain and review 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, 2011, by asset category, are as follows (dollars in thousands):

 

 

 

Quoted Prices
in Active
Markets for
Identical
Assets
(Level 1)

 

Significant
Other
Observable
Inputs
(Level 2)

 

Other (a)

 

Balance at
December 31,
2011

 

Pension Plan:

 

 

 

 

 

 

 

 

 

Assets:

 

 

 

 

 

 

 

 

 

Cash and cash equivalents

 

$

1,441

 

$

 

$

 

$

1,441

 

Fixed Income Securities:

 

 

 

 

 

 

 

 

 

Corporate

 

 

584,619

 

 

584,619

 

U.S. Treasury

 

207,862

 

 

 

207,862

 

Other (b)

 

 

62,906

 

 

62,906

 

Equities:

 

 

 

 

 

 

 

 

 

U.S. Companies

 

436,393

 

 

 

436,393

 

International Companies

 

118,263

 

 

 

118,263

 

Common and collective trusts:

 

 

 

 

 

 

 

 

 

U.S. Equities

 

 

139,321

 

 

139,321

 

International Equities

 

 

156,407

 

 

156,407

 

Real estate

 

 

106,147

 

 

106,147

 

Short-term investments and other

 

 

29,913

 

7,278

 

37,191

 

 

 

 

 

 

 

 

 

 

 

Total Pension Plan

 

$

763,959

 

$

1,079,313

 

$

7,278

 

$

1,850,550

 

Other Benefits:

 

 

 

 

 

 

 

 

 

Assets:

 

 

 

 

 

 

 

 

 

Cash and cash equivalents

 

$

160

 

$

 

$

 

$

160

 

Fixed Income Securities:

 

 

 

 

 

 

 

 

 

Corporate

 

 

148,417

 

 

148,417

 

U.S. Treasury

 

103,321

 

 

 

103,321

 

Other (b)

 

 

30,105

 

 

30,105

 

Equities:

 

 

 

 

 

 

 

 

 

U.S. Companies

 

179,235

 

 

 

179,235

 

International Companies

 

22,486

 

 

 

22,486

 

Common and collective trusts:

 

 

 

 

 

 

 

 

 

U.S. Equities

 

 

52,507

 

 

52,507

 

International Equities

 

 

53,504

 

 

53,504

 

Real Estate

 

 

8,446

 

 

8,446

 

Short-term investments and other

 

 

8,516

 

1,966

 

10,482

 

 

 

 

 

 

 

 

 

 

 

Total Other Benefits

 

$

305,202

 

$

301,495

 

$

1,966

 

$

608,663

 

 

(a)                                  Represents plan receivables and payables.

 

(b)                                 This category consists primarily of debt securities issued by municipalities.

 

The fair value of Pinnacle West’s pension plan and other postretirement benefit plan assets at December 31, 2010, by asset category, are as follows (dollars in thousands):

 

 

 

Quoted Prices
in Active
Markets for
Identical
Assets
(Level 1)

 

Significant
Other
Observable
Inputs
(Level 2)

 

Other (a)

 

Balance at
December 31,
2010

 

Pension Plan:

 

 

 

 

 

 

 

 

 

Assets:

 

 

 

 

 

 

 

 

 

Cash and cash equivalents

 

$

2,375

 

$

 

$

 

$

2,375

 

Fixed Income Securities:

 

 

 

 

 

 

 

 

 

Corporate

 

 

508,946

 

 

508,946

 

U.S. Treasury

 

163,313

 

 

 

163,313

 

Other (b)

 

 

53,358

 

 

53,358

 

Equities:

 

 

 

 

 

 

 

 

 

U.S. Companies

 

462,973

 

 

 

462,973

 

International Companies

 

129,094

 

 

 

129,094

 

Other investments

 

 

5,549

 

8,071

 

13,620

 

Common and collective trusts:

 

 

 

 

 

 

 

 

 

U.S. Equities

 

 

146,705

 

 

146,705

 

International Equities

 

 

177,114

 

 

177,114

 

Real estate

 

 

92,454

 

 

92,454

 

Short-term investments

 

 

25,644

 

 

25,644

 

 

 

 

 

 

 

 

 

 

 

Total Pension Plan

 

$

757,755

 

$

1,009,770

 

$

8,071

 

$

1,775,596

 

Other Benefits:

 

 

 

 

 

 

 

 

 

Assets:

 

 

 

 

 

 

 

 

 

Cash and cash equivalents

 

$

243

 

$

 

$

 

$

243

 

Fixed Income Securities:

 

 

 

 

 

 

 

 

 

Corporate

 

 

118,660

 

 

118,660

 

U.S. Treasury

 

74,049

 

 

 

74,049

 

Other (b)

 

 

24,456

 

 

24,456

 

Equities:

 

 

 

 

 

 

 

 

 

U.S. Companies

 

179,655

 

 

 

179,655

 

International Companies

 

25,121

 

 

 

25,121

 

Other investments

 

 

365

 

2,034

 

2,399

 

Common and collective trusts:

 

 

 

 

 

 

 

 

 

U.S. Equities

 

 

54,144

 

 

54,144

 

International Equities

 

 

61,455

 

 

61,455

 

Real Estate

 

 

7,357

 

 

7,357

 

Short-term investments

 

 

19,871

 

 

19,871

 

 

 

 

 

 

 

 

 

 

 

Total Other Benefits

 

$

279,068

 

$

286,308

 

$

2,034

 

$

567,410

 

 

(a)                                  Represents plan receivables and payables.

(b)                                 This category consists primarily of municipal debt securities issued by municipalities.

 

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, 2010 (dollars in thousands):

 

 

 

Year Ended
December 31, 2010

 

Common and Collective Trusts — Real Estate

 

Pension

 

Other
Benefits

 

 

 

 

 

 

 

Beginning balance at January 1

 

$

64,212

 

$

6,504

 

Actual return on assets still held (a)

 

(204

)

(23

)

Purchases, sales, and settlements

 

18,003

 

45

 

Transfers in and/or out of Level 3 (b)

 

(82,011

)

(6,526

)

Ending balance at December 31

 

$

 

$

 

 

(a)                                  The return for December 31, 2010 represents the return on assets held as of March 31, 2010, the beginning of the period in which all the assets were transferred out of Level 3.

 

(b)                                 Transfers into and out of Level 3 are measured at the beginning of the period in which the transfer occurs.  Transfers out of Level 3 during 2010 relate to our Real Estate Common and Collective Trust being transferred to a Level 2 investment.  During 2009 the Real Estate Common and Collective Trust had special redemption restrictions in place, which limited our ability to transact at the trust’s NAV.  During 2010 these special redemption restrictions were lifted, and in 2010 and 2011 we were able to transact at the NAV according to the trust’s contractual redemption policy.

 

The plans had no investments valued using significant unobservable inputs (Level 3) for the year ended December 31, 2011.

 

Contributions

 

The required minimum contribution to our pension plan is approximately $65 million in 2012, approximately $160 million in 2013 and approximately $160 million in 2014.  In 2011, we did not make a contribution to our pension plan.  The contribution to our other postretirement benefit plans in 2011 was approximately $19 million.  The contributions to our other postretirement benefit plans for 2012, 2013 and 2014 are expected to be approximately $20 million each year.  APS and other subsidiaries fund their share of the contributions.  APS’s share of the pension plan contribution was $195 million in 2010.  APS’s share of the contributions to the other postretirement benefit plan were $19 million in 2011, $16 million in 2010, and $15 million in 2009.

 

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 (a)

 

2012

 

$

113,075

 

$

27,610

 

2013

 

122,750

 

30,562

 

2014

 

132,302

 

33,451

 

2015

 

141,516

 

36,489

 

2016

 

154,379

 

39,525

 

Years 2017-2021

 

941,377

 

246,091

 

 

(a)                                  The estimated future other benefit payments take into account the Medicare Part D subsidy.

 

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 2011, 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 $8 million for 2011, $9 million for 2010 and $9 million for 2009.

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 $21 million in 2011, $23 million in 2010 and $28 million in 2009.  APS’s lease expense was $18 million in 2011, $19 million in 2010 and $19 million in 2009.

 

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
Consolidated

 

APS

 

2012

 

$

21

 

$

18

 

2013

 

18

 

15

 

2014

 

15

 

12

 

2015

 

13

 

10

 

2016

 

2

 

2

 

Thereafter

 

23

 

22

 

Total future lease commitments

 

$

92

 

$

79

 

 

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 variable interest entities 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 20 for a discussion of VIEs.

 

Jointly-Owned Facilities
Jointly-Owned Facilities

 

 

10.                               Jointly-Owned Facilities

 

APS shares ownership of some of its generating and transmission facilities with other companies.  Our share of operations and maintenance expense 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, 2011 (dollars in thousands):

 

 

 

Percent
Owned

 

Plant in
Service

 

Accumulated
Depreciation

 

Construction
Work in
Progress

 

Generating facilities:

 

 

 

 

 

 

 

 

 

Palo Verde Units 1 and 3

 

29.1

%

$

2,061,894

 

$

1,154,141

 

$

66,558

 

Palo Verde Unit 2 (a)

 

17.0

%

661,006

 

365,704

 

33,032

 

Palo Verde Sale Leaseback

 

 

(a)

351,050

 

218,186

 

 

Four Corners Units 4 and 5

 

15.0

%

165,139

 

104,910

 

2,357

 

Four Corners common

 

38.44

%

16,413

 

5,997

 

750

 

Navajo Generating Station Units 1, 2 and 3

 

14.0

%

264,227

 

170,777

 

10,327

 

Cholla common facilities (b)

 

63.3

%(c)

146,642

 

51,985

 

1,661

 

Transmission facilities:

 

 

 

 

 

 

 

 

 

ANPP 500kV System

 

33.0

%(c)

88,451

 

30,123

 

10,161

 

Navajo Southern System

 

25.9

%(c)

51,174

 

15,161

 

920

 

Palo Verde — Yuma 500kV System

 

44.1

%(c)

8,816

 

4,331

 

 

Four Corners Switchyards

 

39.6

%(c)

19,630

 

5,696

 

1,004

 

Phoenix — Mead System

 

17.5

%(c)

39,374

 

10,731

 

 

Palo Verde — Estrella 500kV System

 

50.0

%(c)

85,643

 

11,769

 

3,445

 

North Valley System

 

69.3

%(c)

95,057

 

1,757

 

3,821

 

Round Valley System

 

50.0

%(c)

570

 

320

 

 

 

(a)                                  See Note 20.

 

(b)                                 PacifiCorp owns Cholla Unit 4 and APS operates the unit for PacifiCorp.  The common facilities at Cholla are jointly-owned.

 

(c)                                  Weighted average of interests.

Commitments and Contingencies
Commitments and Contingencies

 

 

11.                               Commitments and Contingencies

 

Palo Verde Nuclear Generating Station

 

Spent Nuclear Fuel and Waste Disposal

 

APS currently estimates it will incur $122 million (in 2011 dollars) 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, 2011, APS had a regulatory liability of $49 million that represents amounts recovered in retail rates in excess of amounts spent for on-site interim spent fuel storage.

 

Nuclear Insurance

 

The Palo Verde participants are insured against public liability for a nuclear incident up to $12.6 billion per occurrence.  As required by the Price Anderson Nuclear Industries Indemnity Act, 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 $12.2 billion 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 $118 million, subject to an annual limit of $18 million per incident, to be periodically adjusted for inflation.  Based on APS’s interest in the three Palo Verde units, APS’s maximum potential assessment per incident for all three units is approximately $103 million, with an annual payment limitation of approximately $15 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”).  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 $46 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 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 2012 and 2042 that include required purchase provisions.  APS estimates the contract requirements to be approximately $580 million in 2012; $528 million in 2013; $556 million in 2014; $535 million in 2015; $503 million in 2016; and $6.8 billion thereafter.  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 have take-or-pay provisions.  The contracts APS has for its coal supply include take-or-pay provisions.  The current take-or-pay coal contracts have terms that expire in 2024.

 

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

 

 

 

Actual

 

Estimated (a)

 

 

2009

 

2010

 

2011

 

2012

 

2013

 

2014

 

2015

 

2016

 

Thereafter

 

Coal take-or-pay commitments

 

$

93

 

$

66

 

$

68

 

$

79

 

$

82

 

$

86

 

$

88

 

$

58

 

$

148

 

 

(a)                                  Total take-or-pay commitments are approximately $541 million.  The total net present value of these commitments is approximately $401 million.

 

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 $58 million in 2012; $32 million in 2013; $33 million in 2014; $32 million in 2015; $32 million in 2016; and $388 million thereafter.

 

Coal Mine Reclamation Obligations

 

APS must reimburse certain coal providers for amounts incurred for coal mine reclamation.  APS’s coal mine reclamation obligation was approximately $118 million at December 31, 2011 and $117 million at December 31, 2010.

 

FERC Market Issues

 

On July 25, 2001, the FERC ordered an evidentiary proceeding to discuss and evaluate possible refunds for wholesale sales in the Pacific Northwest.  The FERC affirmed the administrative law judge’s conclusion that the prices in the Pacific Northwest were not unreasonable or unjust and refunds should not be ordered in this proceeding.  This decision was appealed to the U.S. Court of Appeals for the Ninth Circuit and ultimately remanded to the FERC for further consideration.  On October 3, 2011, the FERC ordered an evidentiary, trial-type hearing before an administrative law judge to address possible activity that may have influenced prices in the Pacific Northwest spot market during the period from December 25, 2000 through June 20, 2001.  FERC rejected a market-wide remedy approach and instead directed that buyers seeking refunds must demonstrate that a particular seller engaged in unlawful market activity in the spot market and that such unlawful activity directly affected the particular contract or contracts to which the seller was a party.

 

This hearing has been held in abeyance to provide an opportunity for the parties to engage in settlement negotiations.  Although the FERC has not yet determined whether any refunds will ultimately be required, we do not expect that the resolution of these issues will have a material adverse impact on our financial position, results of operations or cash flows.

 

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, the EPA advised APS that the EPA considers APS to be a PRP in the Motorola 52nd Street Superfund Site, OU3 in Phoenix, Arizona.  APS has facilities that are within this Superfund site.  APS and Pinnacle West have agreed with the EPA to perform certain investigative activities of the APS facilities within OU3.  In addition, on September 23, 2009, APS agreed with the 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 $1 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 we cannot accurately estimate our total expenditures.

 

Climate Change Lawsuit

 

In February 2008, the Native Village of Kivalina and the City of Kivalina, Alaska filed a lawsuit in federal court in the Northern District of California against nine oil companies, fourteen power companies (including Pinnacle West), and a coal company, alleging that the defendants’ emissions of carbon dioxide contribute to global warming and constitute a public and private nuisance under both federal and state law.  The plaintiffs also allege that the effects of global warming will require the relocation of the village, and they are seeking an unspecified amount of monetary damages.  In June 2008, the defendants filed motions to dismiss the action, which were granted.  The plaintiffs filed an appeal with the Ninth Circuit Court of Appeals in November 2009, and Pinnacle West filed its reply on June 30, 2010.  On January 24, 2011, the defendants filed a motion, which was later granted, to defer calendaring of oral argument until after the United States Supreme Court ruled in a similar nuisance lawsuit, American Electric Power Co., Inc. v. Connecticut.

 

On June 20, 2011, the Supreme Court issued its opinion in Connecticut holding, among other things, that the Clean Air Act and the EPA actions authorized by the act, which are aimed at controlling greenhouse gas emissions, displace any federal common law right to seek abatement of greenhouse gas emissions from fossil fuel-fired power plants.  However, the Court left open the issue of whether such claims may be available under state law.  Oral argument in the Kivalina case was heard on November 28, 2011; the parties await the court’s decision.  We believe the action in Kivalina is without merit and will continue to defend against both the federal and state claims.

 

Southwest Power Outage

 

Regulatory Inquiry.  On September 8, 2011 at approximately 3:30PM, a 500 kV transmission line running between the Hassayampa and North Gila substations in southwestern Arizona tripped out of service due to a fault that occurred at a switchyard operated by APS.  At the time, an APS employee at the North Gila substation was performing a procedure to remove from service a capacitor bank that was believed not to be operating properly.  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 2.8 million customers (1.6 million in the United States and 1.2 million in northern Mexico) were reported to have been affected.  Service to all affected APS customers was restored by 9:15PM on September 8.  Service to customers affected by the wider regional outages was restored by approximately 3:25AM on September 9.

 

APS has an internal review of the September 8 events underway.  In addition:

 

·                                          the FERC and the North American Electric Reliability Corporation (“NERC”) are conducting a joint inquiry into the outages; and

 

·                                          the Western Electricity Coordinating Council (“WECC”) initiated a Detailed Disturbance Analysis process to identify and understand the cause of the events that occurred, and identify and ensure timely implementation of corrective actions.

 

APS cannot predict the timing, results or potential impacts of any of the inquiries into the September 8 events, or any other claims that may be made as a result of the outages. If violations of NERC 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 the violation is found to have been in existence.

 

Lawsuit.  On September 12, 2011, two purported consumer class action complaints were filed in Federal District Court in San Diego, California, naming APS, Pinnacle West and San Diego Gas & Electric Company as defendants and seeking damages for loss of perishable inventory as a result of interruption of electrical service.  On December 22, 2011, the plaintiffs voluntarily dismissed both lawsuits.  In January 2012, one of the cases was refiled in California Superior Court in San Diego, California.  APS and Pinnacle West have numerous defenses against any such complaints, and do not believe that any potential impact will be material.

 

New Source Review

 

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 PSD 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 plaintiffs seek to have the court enjoin operations at Four Corners until APS applies for and obtains any required PSD permits and complies with the NSPS.  The plaintiffs further request the court to order the payment of civil penalties, including a beneficial mitigation project.  APS believes the claims in this matter are without merit and will vigorously defend against them.  We are unable to determine a range of potential losses that are reasonably possible of occurring.

 

Financial Assurances

 

APS has entered into various agreements that require letters of credit for financial assurance purposes.  At December 31, 2011, approximately $44 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.  These letters of credit 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 20 for further details on the Palo Verde sale leaseback transactions).  These letters of credit will expire at December 31, 2015, totaling approximately $52 million.  Additionally, APS has issued two letters of credit to support the collateral obligations under a certain natural gas tolling contracts entered into with third parties.  At December 31, 2011, $30 million of letters of credit were outstanding to support these tolling contract obligations.  These letters of credit will expire in 2015 and 2016.

 

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 sold its investment in APSES on August 19, 2011.  Upon the closing of the sale, Pinnacle West was released from its parental guarantee and surety bond obligations related to the APSES business.  Pinnacle West has also issued parental guarantees and surety bonds for APS which were not material at December 31, 2011.

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.  In the first quarter of 2011, a new decommissioning study with updated cash flow estimates was completed for Palo Verde.  This study reflects the twenty-year license extension approved by the NRC on April 21, 2011, which extends the commencement of decommissioning to 2045.  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.

 

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 2011 and 2010 (dollars in millions):

 

 

 

2011

 

2010

 

Asset retirement obligations at the beginning of year

 

$

329

 

$

302

 

Changes attributable to:

 

 

 

 

 

Accretion expense

 

19

 

22

 

Estimated cash flow revisions

 

(68

)

5

 

Asset retirement obligations at the end of year

 

$

280

 

$

329

 

 

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 Data (Unaudited)
Selected Quarterly Financial Data (Unaudited)

 

 

13.          Selected Quarterly Financial Data (Unaudited)

 

Consolidated quarterly financial information for 2011 and 2010 is as follows (dollars in thousands, except per share amounts):

 

 

 

2011 Quarter Ended

 

2011

 

 

 

March 31,(a)

 

June 30,

 

Sept. 30,

 

Dec. 31,

 

Total

 

 

 

 

 

 

 

 

 

 

 

 

 

Operating revenues

 

$

648,847

 

$

799,799

 

$

1,124,841

 

$

667,892

 

$

3,241,379

 

Operations and maintenance

 

255,029

 

210,590

 

210,035

 

228,632

 

904,286

 

Operating income

 

35,784

 

196,992

 

435,017

 

78,715

 

746,508

 

Income taxes

 

(6,005

)

50,818

 

131,416

 

7,375

 

183,604

 

Income (loss) from continuing operations

 

(10,368

)

93,185

 

253,273

 

19,544

 

355,634

 

Net income (loss) attributable to common shareholders

 

(15,135

)

86,685

 

255,359

 

12,564

 

339,473

 

 

 

 

 

 

 

 

 

 

 

 

 

Earnings Per Share:

 

 

 

 

 

 

 

 

 

 

 

Income (loss) from continuing operations attributable to common shareholders - Basic

 

$

(0.15

)

$

0.79

 

$

2.25

 

$

0.11

 

$

3.01

 

Net income (loss) attributable to common shareholders - Basic

 

(0.14

)

0.80

 

2.34

 

0.12

 

3.11

 

Income (loss) from continuing operations attributable to common shareholders - Diluted

 

(0.15

)

0.78

 

2.24

 

0.11

 

2.99

 

Net income (loss) attributable to common shareholders - Diluted

 

(0.14

)

0.79

 

2.32

 

0.11

 

3.09

 

 

(a)                                  The March 31, 2011 results were adjusted for the effect of reclassifications for discontinued operations (see Note 21).  The adjustments resulted in a reduction in operating revenues of $10,728, a reduction in operations and maintenance of $1,457, a reduction in operating income of $1,357, a decrease in income taxes of $356, and a decrease in income from continuing operations of $1,043.

 

 

 

2010 Quarter Ended

 

2010

 

 

 

March 31,

 

June 30,

 

Sept. 30,

 

Dec. 31,

 

Total

 

 

 

 

 

 

 

 

 

 

 

 

 

As originally reported in the 2010 10-K:

 

 

 

 

 

 

 

 

 

 

 

Operating revenues

 

$

620,355

 

$

820,594

 

$

1,139,085

 

$

683,611

 

$

3,263,645

 

Operations and maintenance

 

207,842

 

215,104

 

221,469

 

232,991

 

877,406

 

Operating income

 

57,668

 

203,273

 

403,625

 

59,318

 

723,884

 

Income taxes

 

(7,172

)

51,829

 

123,486

 

(3,822

)

164,321

 

Income from continuing operations

 

11,983

 

94,584

 

231,828

 

12,203

 

350,598

 

Net income (loss) attributable to common shareholders

 

(6,014

)

114,797

 

233,920

 

7,350

 

350,053

 

 

 

 

 

 

 

 

 

 

 

 

 

Reclassification of discontinued operations (Note 21):

 

 

 

 

 

 

 

 

 

 

 

Operating revenues

 

$

(8,093

)

$

(17,799

)

$

(22,375

)

$

(26,179

)

$

(74,446

)

Operations and maintenance

 

(1,529

)

(1,495

)

(1,811

)

(2,386

)

(7,221

)

Operating income

 

(694

)

(1,889

)

(3,351

)

(3,067

)

(9,001

)

Income taxes

 

(481

)

(641

)

(1,139

)

(1,191

)

(3,452

)

Income (loss) from continuing operations

 

(292

)

(1,270

)

(2,266

)

(1,919

)

(5,747

)

 

 

 

 

 

 

 

 

 

 

 

 

After reclassifications:

 

 

 

 

 

 

 

 

 

 

 

Operating revenues

 

$

612,262

 

$

802,795

 

$

1,116,710

 

$

657,432

 

$

3,189,199

 

Operations and maintenance

 

206,313

 

213,609

 

219,658

 

230,605

 

870,185

 

Operating income

 

56,974

 

201,384

 

400,274

 

56,251

 

714,883

 

Income taxes

 

(7,653

)

51,188

 

122,347

 

(5,013

)

160,869

 

Income from continuing operations

 

11,691

 

93,314

 

229,562

 

10,284

 

344,851

 

Net income (loss) attributable to common shareholders

 

(6,014

)

114,797

 

233,920

 

7,350

 

350,053

 

 

 

 

 

 

 

 

 

 

 

 

 

Earnings Per Share:

 

 

 

 

 

 

 

 

 

 

 

As originally reported in the 2010 10-K

 

 

 

 

 

 

 

 

 

 

 

Income from continuing operations attributable to common shareholders - Basic

 

$

0.07

 

$

0.84

 

$

2.09

 

$

0.07

 

$

3.10

 

Net income (loss) attributable to common shareholders - Basic

 

(0.06

)

1.07

 

2.15

 

0.07

 

3.28

 

Income from continuing operations attributable to common shareholders - Diluted

 

0.07

 

0.83

 

2.08

 

0.06

 

3.08

 

Net income (loss) attributable to common shareholders - Diluted

 

(0.06

)

1.07

 

2.14

 

0.07

 

3.27

 

 

 

 

 

 

 

 

 

 

 

 

 

Earnings Per Share:

 

 

 

 

 

 

 

 

 

 

 

After reclassifications:

 

 

 

 

 

 

 

 

 

 

 

Income from continuing operations attributable to common shareholders - Basic

 

$

0.06

 

$

0.82

 

$

2.07

 

$

0.05

 

$

3.05

 

Net income (loss) attributable to common shareholders - Basic

 

(0.06

)

1.07

 

2.15

 

0.07

 

3.28

 

Income from continuing operations attributable to common shareholders - Diluted

 

0.06

 

0.82

 

2.06

 

0.05

 

3.03

 

Net income (loss) attributable to common shareholders - Diluted

 

(0.06

)

1.07

 

2.14

 

0.07

 

3.27

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 models are required 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.  The primary valuation technique we use to calculate the fair value of contracts where price quotes are not available is based on the extrapolation of forward pricing curves using observable market data for more liquid delivery points in the same region and actual transactions at the more illiquid delivery points.  Option contracts are valued using a Black-Scholes option pricing model that incorporates commodity prices, volatilities, and correlation factors.

 

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 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 transactions, 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 transactions, 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 market 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 based on the financial condition of counterparties.  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.  Certain option contracts are valued using option valuation models which utilize both observable and unobservable inputs such as volatility rates and correlation factors.  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.

 

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 NAV, which is 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 and interest rate 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 assess these valuations and verify that pricing can be supported by actual recent market transactions.  Additionally, we obtain and review independent audit reports on the trustee’s operating controls and valuation processes.  See Note 23 for additional discussion about our nuclear decommissioning trust.

 

Fair Value Tables

 

The following table presents the fair value at December 31, 2011 of our assets and liabilities that are measured at fair value on a recurring basis (dollars in millions):

 

 

 

Quoted Prices
in Active
Markets for
Identical
Assets

(Level 1)

 

Significant
Other
Observable
Inputs

(Level 2)

 

Significant
Unobservable
Inputs (a)
(Level 3)

 

Other

 

Balance at
December 31,
2011

 

 

 

 

 

 

 

 

 

 

 

 

 

Assets

 

 

 

 

 

 

 

 

 

 

 

Risk management activities-derivative instruments:

 

 

 

 

 

 

 

 

 

 

 

Commodity contracts

 

$

 

$

70

 

$

74

 

$

(64

)(b)

$

80

 

Nuclear decommissioning trust:

 

 

 

 

 

 

 

 

 

 

 

U.S. commingled equity funds

 

 

175

 

 

 

175

 

Fixed income securities:

 

 

 

 

 

 

 

 

 

 

 

U.S. Treasury

 

69

 

 

 

 

69

 

Cash and cash equivalent funds

 

 

9

 

 

(1

)(c)

8

 

Corporate debt

 

 

73

 

 

 

73

 

Mortgage-backed securities

 

 

78

 

 

 

78

 

Municipality bonds

 

 

90

 

 

 

90

 

Other

 

 

21

 

 

 

21

 

Subtotal nuclear decommissioning trust

 

69

 

446

 

 

(1

)

514

 

Total

 

$

69

 

$

516

 

$

74

 

$

(65

)

$

594

 

 

 

 

 

 

 

 

 

 

 

 

 

Liabilities

 

 

 

 

 

 

 

 

 

 

 

Risk management activities - derivative instruments:

 

 

 

 

 

 

 

 

 

 

 

Commodity contracts

 

$

 

$

(241

)

$

(125

)

$

229

(b)

$

(137

)

 

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

(b)         Represents counterparty netting, margin and collateral.  See Note 18.

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

 

The following table presents the fair value at December 31, 2010 of our assets and liabilities that are measured at fair value on a recurring basis (dollars in millions):

 

 

 

Quoted Prices
in Active
Markets for
Identical
Assets

(Level 1)

 

Significant
Other
Observable
Inputs

(Level 2)

 

Significant
Unobservable
Inputs (a)
(Level 3)

 

Other

 

Balance at
December 31,
2010

 

Assets

 

 

 

 

 

 

 

 

 

 

 

Cash equivalents

 

$

35

 

$

 

$

 

$

 

$

35

 

Risk management activities-derivative instruments:

 

 

 

 

 

 

 

 

 

 

 

Commodity contracts

 

 

80

 

61

 

(28

)(b)

113

 

Nuclear decommissioning trust:

 

 

 

 

 

 

 

 

 

 

 

U.S. commingled equity funds

 

 

168

 

 

 

168

 

Fixed income securities:

 

 

 

 

 

 

 

 

 

 

 

U.S. Treasury

 

50

 

 

 

 

50

 

Cash and cash equivalent funds

 

 

22

 

 

 

22

 

Corporate debt

 

 

60

 

 

 

60

 

Mortgage-backed securities

 

 

81

 

 

 

81

 

Municipality bonds

 

 

79

 

 

 

79

 

Other

 

 

20

 

 

(10)

(c)

10

 

Subtotal nuclear decommissioning trust

 

50

 

430

 

 

(10

)

470

 

Total

 

$

85

 

$

510

 

$

61

 

$

(38

)

$

618

 

 

 

 

 

 

 

 

 

 

 

 

 

Liabilities

 

 

 

 

 

 

 

 

 

 

 

Risk management activities - derivative instruments:

 

 

 

 

 

 

 

 

 

 

 

Commodity contracts

 

$

(1

)

$

(280

)

$

(99

)

$

256

(b)

$

(124

)

 

(a)                                  Primarily consists of long-dated electricity contracts.

(b)                                 Represents counterparty netting, margin and collateral.  See Note 18.

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

 

The following table shows the changes in fair value for assets and liabilities that are measured at fair value on a recurring basis using Level 3 inputs for the years ended December 31, 2011 and 2010 (dollars in millions):

 

 

 

Year Ended
December 31,

 

 

 

2011

 

2010

 

Net risk management activities at beginning of period

 

$

(38

)

$

(10

)

Total net gains (losses) realized/unrealized:

 

 

 

 

 

Included in earnings

 

2

 

(1

)

Included in OCI

 

(5

)

(14

)

Deferred as a regulatory asset or liability

 

(10

)

(38

)

Settlements

 

11

 

19

 

Transfers into Level 3 from Level 2

 

(4

)

5

 

Transfers from Level 3 into Level 2

 

(7

)

1

 

Net risk management activities at end of period

 

$

(51

)

$

(38

)

 

 

 

 

 

 

Net unrealized gains (losses) included in earnings related to instruments still held at end of period

 

$

1

 

$

(1

)

 

Amounts included in earnings are recorded in either regulated electricity segment revenue or regulated electricity segment 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 generally related to changes in the significance of reserves applied to derivative instruments.  Transfers out of Level 3 may also be related to our long-dated energy transactions as they move closer to delivery and quoted prices become available.

 

Nonrecurring Fair Value Measurements

 

For the periods ended December 31, 2011 and 2010, we had no assets or liabilities measured at fair value on a nonrecurring basis.

 

Financial Instruments Not Carried at Fair Value

 

The carrying value of our net accounts receivable, accounts payable and short-term borrowings approximate fair value.  For our long-term debt fair values see Note 6.

Earnings Per Share
Earnings Per Share

 

 

15.          Earnings Per Share

 

The following table presents earnings per weighted-average common share outstanding for the years ended December 31, 2011, 2010 and 2009:

 

 

 

2011

 

2010

 

2009

 

Basic earnings per share:

 

 

 

 

 

 

 

Income from continuing operations attributable to common shareholders

 

$

3.01

 

$

3.05

 

$

2.34

 

Income (loss) from discontinued operations

 

0.10

 

0.23

 

(1.66

)

Earnings per share — basic

 

$

3.11

 

$

3.28

 

$

0.68

 

Diluted earnings per share:

 

 

 

 

 

 

 

Income from continuing operations attributable to common shareholders

 

$

2.99

 

$

3.03

 

$

2.34

 

Income (loss) from discontinued operations

 

0.10

 

0.24

 

(1.67

)

Earnings per share — diluted

 

$

3.09

 

$

3.27

 

$

0.67

 

 

Dilutive stock options and performance shares (which are contingently issuable) increased average common shares outstanding by approximately 811,000 shares in 2011, 565,000 shares in 2010 and 103,000 shares in 2009.  Total average common shares outstanding for the purposes of calculating diluted earnings per share were 109,864,243 shares in 2011, 107,137,785 shares in 2010 and 101,263,795 shares in 2009.

 

For the year ended 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.  Options to purchase shares of common stock that were not included in the computation of diluted earnings per share were 192,542 during 2010 and 572,301 during 2009.

Stock-Based Compensation
Stock-Based Compensation

 

 

16.                               Stock-Based Compensation

 

Pinnacle West grants long-term incentive awards under the 2007 long-term incentive plan (“2007 Plan”) in the form of Stock Grants, Restricted Stock Units, Restricted Stock and Performance Shares and may grant incentive and stock options, stock appreciation rights, dividend equivalents and stock.  The 2007 Plan, effective May 23, 2007, provides a maximum of 8 million common shares to be available for grant to eligible employees and members of the Board of Directors.

 

Restricted Stock Unit Awards and Stock Grants

 

Stock grants issued to non-officer members of the Board of Directors in 2009 under the 2007 Plan were paid in fully transferable shares of stock.  The 2011 and 2010 grants issued under the 2007 Plan provided 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.  Directors who elect to defer may elect to receive payment in either (1) stock, or (2) 50% in cash and 50% in stock.  The Director may elect to receive payments either (1) as of the last business day of the month following the month in which the Director separates from services on the Board, or (2) as of a date specified by the Director, which date 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 Director would have received if the Director had directly owned one share of common stock for each restricted stock unit held plus interest compounded quarterly.  The dividends and interest are paid, based on the Director’s election, in either (1) stock, or (2) 50% stock and 50% cash.

 

Restricted stock units have been granted to officers and key employees under the 2007 Plan 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.  For 2010 and 2011, participants elected to receive payment in either stock, or 50% cash and 50% stock.

 

Restricted stock unit awards vest and settle over a four-year period.  In addition, officers and key employees accrue dividend rights on the 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 and 2011 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 Pinnacle West’s closing stock price, and remeasured at each balance sheet date.  Compensation expense for retirement eligible participants is recognized immediately.

 

An additional 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 will vest 50% on February 15, 2013, 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 an officer would have received if the officer had directly owned one share of Pinnacle West common stock for each restricted stock unit held by the officer 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 years ended 2011, 2010 and 2009:

 

 

 

2011

 

2010

 

2009

 

Units granted

 

292,242

 

202,341

 

261,006

 

Grant date fair value (a) 

 

$

41.98

 

$

37.47

 

$

30.25

 

 

(a) weighted average fair value

 

The following table is a summary of the status of restricted stock units and stock grants, as of December 31, 2011 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
Grant-Date Fair Value

 

Nonvested at January 1, 2011

 

223,681

 

$

35.69

 

Granted

 

293,242

 

41.98

 

Vested

 

98,362

 

37.84

 

Forfeited

 

2,330

 

37.93

 

Nonvested at December 31, 2011

 

416,231

 

39.61

 

 

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

 

Year

 

2011

 

2010

 

2009

 

2007 Grant

 

$

1.0

 

$

0.9

 

$

0.8

 

2008 Grant

 

1.6

 

1.5

 

1.3

 

2009 Grant

 

1.5

 

1.4

 

 

2010 Grant

 

0.6

 

 

 

 

Performance Share Awards

 

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

 

The 2009 performance share grant criteria is based 50% upon the percentile ranking of Pinnacle West’s earnings per share growth rate at the end of the three-year period as compared with the earnings per share growth of relevant companies in a specified utilities index, and the other 50% based upon six non-financial separate performance metrics.  The exact number of shares issued will vary from 0% to 150% of the target award.  Shares received include dividend rights paid in cash 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.

 

The 2011 and 2010 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 utilities index and the other 50% 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 a liability awards, with compensation cost initially calculated on the date of grant using Pinnacle West’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 the 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 years ended 2011, 2010 and 2009:

 

 

 

2011

 

2010

 

2009

 

Units granted

 

175,072

 

178,722

 

240,624

 

Grant date fair value (a)

 

$

41.71

 

$

37.57

 

$

30.19

 

 

(a)          weighted average grant date fair value

 

The following table is a summary of the status of performance shares, as of December 31, 2011 and changes during the year:

 

Nonvested shares

 

Shares

 

Weighted-Average
Grant-Date Fair Value

 

Nonvested at January 1, 2011

 

395,312

 

$

33.44

 

Granted

 

175,072

 

41.71

 

Vested

 

218,310

 

30.14

 

Forfeited

 

4,128

 

36.09

 

Nonvested at December 31, 2011

 

347,946

 

39.64

 

 

Retention Units

 

The retention unit awards have fully vested and settled on January 4, 2010; for any employee that was eligible to retire before that date, the employee’s retention units vested by retirement date and the compensation expense was recognized by retirement eligibility.  Retention unit awards were granted to key employees in 2006 and 2007.  Each retention unit award represented the right to receive a cash payment equal to the fair market value of one share of Pinnacle West’s common stock, determined on pre-established valuation dates.  Each retention unit award vested and settled in equal annual installments over a four-year period.  In addition, the employee received a cash payment equal to the amount of dividends that the employee would have received if the employee had owned the stock from the date of grant to the date of payment plus interest.  As this award was accounted for as a liability award, compensation costs, initially measured based on Pinnacle West’s stock price on the grant date, were remeasured at each balance sheet date, using Pinnacle West’s closing stock price.

 

The amount of cash to settle the payment on the first business day of 2010 was $1.3 million, and 2009 was $1.1 million.

 

Incentive Shares

 

On January 21, 2009, the Human Resources Committee approved under the 2007 Plan payment of 2008 incentive awards to officers in the form of a Pinnacle West common stock grant.  A total of 138,756 shares were issued for this stock grant with a grant date fair value of $32.58 per share.  The stock grant was included in stock compensation expense in 2008.

 

Stock Options

 

Pinnacle West has not granted stock options since 2004.  Currently outstanding stock option grant terms cannot be longer than 10 years and options cannot be repriced during their terms.

 

The following table summarizes the option activity under prior equity incentive plans for the year ended December 31, 2011:

 

Options

 

Shares

 

Weighted-
Average
Exercise Price

 

Weighted-
Average
Remaining
Contractual
Term (Months)

 

Aggregate
Intrinsic
Value (dollars
in thousands)

 

Outstanding at January 1, 2011

 

82,224

 

$

39.37

 

 

 

 

 

Exercised

 

44,766

 

40.70

 

 

 

 

 

Forfeited or expired

 

14,500

 

42.55

 

 

 

 

 

Outstanding at December 31, 2011

 

22,958

 

34.75

 

11

 

$

308

 

Exercisable at December 31, 2011

 

22,958

 

34.75

 

11

 

$

308

 

 

Cash received from options exercised under our share-based payment arrangements was $1.8 million for 2011, $4.6 million for 2010, and $3 million for 2009.  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, 2011, there was $20.5 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 2.2 years.  The total fair value of shares vested during 2011 was $14.4 million, 2010 was $11 million, and 2009 was $10 million.

 

The compensation cost that has been charged against Pinnacle West’s income for share-based compensation plans was $23 million in 2011, $15 million in 2010, and $5 million in 2009.  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 $9 million in 2011, $6 million in 2010, and $2 million in 2009.  APS’s share of compensation cost that has been charged against income was $22 million in 2011, $15 million in 2010, and $4 million in 2009.

 

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 during 2011.

Business Segments
Business Segments

 

 

17.          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.

 

Financial data for 2011, 2010 and 2009 is provided as follows (dollars in millions):

 

 

 

Business Segments for the Year Ended
December 31, 2011

 

 

 

Regulated
Electricity
Segment

 

All other (a)

 

Total

 

Operating revenues

 

$

3,237

 

$

4

 

$

3,241

 

Fuel and purchased power costs

 

1,009

 

 

1,009

 

Other operating expenses

 

1,055

 

3

 

1,058

 

Operating margin

 

1,173

 

1

 

1,174

 

Depreciation and amortization

 

427

 

 

427

 

Interest expense

 

224

 

 

224

 

Other expense (income)

 

(19

)

3

 

(16

)

Income from continuing operations before income taxes

 

541

 

(2

)

539

 

Income taxes

 

184

 

(1

)

183

 

Income from continuing operations

 

357

 

(1

)

356

 

Income from discontinued operations — net of income tax expense of $7 million (see Note 21)

 

 

11

 

11

 

Net income

 

357

 

10

 

367

 

Less: Net income attributable to noncontrolling interests

 

28

 

 

28

 

Net income attributable to common shareholders

 

$

329

 

$

10

 

$

339

 

Total assets

 

$

13,068

 

$

43

 

$

13,111

 

Capital expenditures

 

$

885

 

$

 

$

885

 

 

 

 

Business Segments for the Year Ended
December 31, 2010

 

 

 

Regulated
Electricity
Segment

 

All other (a)

 

Total

 

Operating revenues

 

$

3,181

 

$

8

 

$

3,189

 

Fuel and purchased power costs

 

1,047

 

 

1,047

 

Other operating expenses

 

1,009

 

4

 

1,013

 

Operating margin

 

1,125

 

4

 

1,129

 

Depreciation and amortization

 

415

 

 

415

 

Interest expense

 

226

 

2

 

228

 

Other expense (income)

 

(22

)

2

 

(20

)

Income from continuing operations before income taxes

 

506

 

 

506

 

Income taxes

 

161

 

 

161

 

Income from continuing operations

 

345

 

 

345

 

Income from discontinued operations — net of income tax expense of $16 million (see Note 21)

 

 

25

 

25

 

Net income

 

345

 

25

 

370

 

Less: Net income attributable to noncontrolling interests

 

20

 

 

20

 

Net income attributable to common shareholders

 

$

325

 

$

25

 

$

350

 

Total assets

 

$

12,285

 

$

108

 

$

12,393

 

Capital expenditures

 

$

666

 

$

4

 

$

670

 

 

 

 

Business Segments for the Year Ended
December 31, 2009

 

 

 

Regulated
Electricity
Segment

 

All other (a)

 

Total

 

Operating revenues

 

$

3,149

 

$

5

 

$

3,154

 

Fuel and purchased power costs

 

1,179

 

 

1,179

 

Other operating expenses

 

948

 

4

 

952

 

Operating margin

 

1,022

 

1

 

1,023

 

Depreciation and amortization

 

407

 

 

407

 

Interest expense

 

226

 

1

 

227

 

Other expense (income)

 

(16

)

10

 

(6

)

Income (loss) from continuing operations before income taxes

 

405

 

(10

)

395

 

Income taxes

 

143

 

(4

)

139

 

Income (loss) from continuing operations

 

262

 

(6

)

256

 

Loss from discontinued operations — net of income tax benefit of $110 million (see Note 21)

 

 

(183

)

(183

)

Net income (loss)

 

262

 

(189

)

73

 

Less: Net income (loss) attributable to noncontrolling interests

 

19

 

(14

)

5

 

Net income (loss) attributable to common shareholders

 

$

243

 

$

(175

)

$

68

 

Total assets

 

$

11,740

 

$

295

 

$

12,035

 

Capital expenditures

 

$

732

 

$

13

 

$

745

 

 

(a)                                  All other activities relate to SunCor, APSES and El Dorado.  Income from discontinued operations for 2011 is primarily related to the sale of our investment in APSES.  Income from discontinued operations for 2010 is primarily related to the APSES sale of its district cooling business. Loss from discontinued operations for 2009 is primarily related to real estate impairment charges at SunCor (see Note 22).  None of these segments is a reportable business segment.

Derivative Accounting
Derivative Accounting

 

 

18.          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 are 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, some of these instruments may not meet the specific hedge accounting requirements and are not designated as accounting hedges. Contracts that have the same terms (quantities and delivery points) 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.

 

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 purchase 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 accumulated other comprehensive income (“AOCI”) 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 of December 31, 2011, we hedged the majority of certain exposures to the price variability of commodities for a maximum of 39 months.

 

APS defers 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.  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, 2011, we had the following outstanding gross notional volume of derivatives, which represent both purchases and sales (does not reflect net position):

 

Commodity

 

Quantity

Power

 

11,882

 

GWh

Gas

 

118,199

 

Billion Btu

 

Gains and Losses from Derivative Instruments

 

The following table provides information about gains and losses from derivative instruments in designated cash flow accounting hedges during the year ended December 31, 2011 and December 31, 2010 (dollars in thousands):

 

Commodity Contracts

 

Financial Statement
Location

 

Year Ended
December 31, 2011

 

Year Ended
December 31, 2010

 

 

 

 

 

 

 

 

 

Loss Recognized in AOCI (Effective Portion)

 

Accumulated other comprehensive loss-derivative instruments

 

$

(94,660

)

$

(155,287

)

 

 

 

 

 

 

 

 

Loss Reclassified from AOCI into Income (Effective Portion Realized)

 

Regulated electricity fuel and purchased power

 

(117,189

)

(122,740

)

 

 

 

 

 

 

 

 

Gain (Loss) Recognized in Income (Ineffective Portion and Amount Excluded from Effectiveness Testing) (a) 

 

Regulated electricity fuel and purchased power

 

(211

)

3,680

 

 

(a)                                  During the year ended December 31, 2011 and 2010, we had no amounts reclassified from AOCI to earnings related to discontinued cash flow hedges.

 

During the next twelve months, we estimate that a net loss of $80 million before income taxes will be reclassified from AOCI as an offset to the effect of market price changes for the related hedged transactions.  In accordance with the PSA, certain of these amounts will be recorded as either a regulatory asset or liability and have no effect on earnings.

 

The following table provides information about gains and losses from derivative instruments not designated as accounting hedges during the year ended December 31, 2011 and December 31, 2010 (dollars in thousands):

 

Commodity Contracts

 

Financial Statement
Location

 

Year Ended
December 31, 2011

 

Year Ended
December 31, 2010

 

 

 

 

 

 

 

 

 

Net Gain (Loss) Recognized in Income

 

Regulated electricity revenue

 

$

(27

)

$

1,436

 

 

 

 

 

 

 

 

 

Net Loss Recognized in Income

 

Regulated electricity fuel and purchased power expense

 

(52,113

)

(107,690

)

Total

 

 

 

$

(52,140

)

$

(106,254

)

 

Fair Values of Derivative Instruments in the Consolidated Balance Sheets

 

The following table provides information about the fair value of our risk management activities reported on a gross basis.  Transactions with counterparties that have master netting arrangements are reported net on the balance sheet.  These amounts are located in the assets and liabilities from risk management activities lines of our Consolidated Balance Sheets.  Amounts are as of December 31, 2011 (dollars in thousands):

 

Commodity Contracts

 

Designated
as Hedging
Instruments

 

Not
Designated
as Hedging
Instruments

 

Margin and
Collateral
Provided to
Counterparties

 

Collateral
Provided from
Counterparties
(a)

 

Other (b)

 

Total

 

Current Assets

 

$

7,287

 

$

76,162

 

$

1,630

 

$

 

$

(54,815

)

$

30,264

 

Investments and Other Assets

 

3,804

 

58,273

 

 

 

(12,755

)

49,322

 

Total Assets

 

11,091

 

134,435

 

1,630

 

 

(67,570

)

79,586

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Current Liabilities

 

(82,195

)

(124,028

)

107,228

 

(11,145

)

56,172

 

(53,968

)

Deferred Credits and Other

 

(68,137

)

(92,880

)

65,768

 

 

12,754

 

(82,495

)

Total Liabilities

 

(150,332

)

(216,908

)

172,996

 

(11,145

)

68,926

 

(136,463

)

Total Derivative Instruments

 

$

(139,241

)

$

(82,473

)

$

174,626

 

$

(11,145

)

$

1,356

 

$

(56,877

)

 

(a)                                  Collateral relates to non-derivative instruments or derivative instruments that qualify for a scope exception.

(b)                                 Other represents counterparty netting, options, and other risk management contracts.

 

The following table provides information about the fair value of our risk management activities reported on a gross basis at December 31, 2010 (dollars in thousands):

 

Commodity Contracts

 

Designated
as Hedging
Instruments

 

Not
Designated
as Hedging
Instruments

 

Margin and
Collateral
Provided to
Counterparties
(a)

 

Collateral
Provided from
Counterparties
(b)

 

Other (c)

 

Total

 

Current Assets

 

$

10,295

 

$

64,153

 

$

36,135

 

$

(1,750

)

$

(35,045

)

$

73,788

 

Investments and Other Assets

 

5,056

 

60,813

 

 

 

(26,837

)

39,032

 

Total Assets

 

15,351

 

124,966

 

36,135

 

(1,750

)

(61,882

)

112,820

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Current Liabilities

 

(108,387

)

(112,847

)

126,364

 

(1,250

)

37,144

 

(58,976

)

Deferred Credits and Other

 

(73,041

)

(85,506

)

66,393

 

 

26,764

 

(65,390

)

Total Liabilities

 

(181,428

)

(198,353

)

192,757

 

(1,250

)

63,908

 

(124,366

)

Total Derivative Instruments

 

$

(166,077

)

$

(73,387

)

$

228,892

 

$

(3,000

)

$

2,026

 

$

(11,546

)

 

(a)                                  Includes $11 million of collateral relating to non-derivative instruments or derivative instruments that qualify for a scope exception.

(b)                                 Includes $1 million of collateral relating to non-derivative instruments or derivative instruments that qualify for a scope exception.

(c)                                  Other represents counterparty netting, options, and other risk management contracts.

 

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 80% of Pinnacle West’s $80 million of risk management assets as of December 31, 2011.  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, 2011 (dollars in millions):

 

 

 

December 31,
2011

 

Aggregate Fair Value of Derivative Instruments in a Liability Position

 

$

330

 

Cash Collateral Posted

 

147

 

Additional Cash Collateral in the Event Credit-Risk Related Contingent Features were Fully Triggered (a)

 

151

 

 

(a)                                  This amount is after counterparty netting and includes those contracts which qualify for scope exceptions, which are excluded from the derivative details in the footnote 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 $194 million if our debt credit ratings were to fall below investment grade.

Other Income and Other Expense
Other Income and Other Expense

 

 

19.          Other Income and Other Expense

 

The following table provides detail of other income and other expense for 2011, 2010 and 2009 (dollars in thousands):

 

 

 

2011

 

2010

 

2009

 

Other income:

 

 

 

 

 

 

 

Interest income

 

$

1,850

 

$

3,255

 

$

1,503

 

Investment gains — net

 

1,165

 

2,797

 

2,512

 

Miscellaneous

 

96

 

335

 

1,144

 

Total other income

 

$

3,111

 

$

6,387

 

$

5,159

 

 

 

 

 

 

 

 

 

Other expense:

 

 

 

 

 

 

 

Non-operating costs

 

$

(7,037

)

$

(6,831

)

$

(6,675

)

Miscellaneous

 

(3,414

)

(3,090

)

(7,625

)

Total other expense

 

$

(10,451

)

$

(9,921

)

$

(14,300

)

Palo Verde Sale Leaseback Variable Interest Entities
Palo Verde Sale Leaseback Variable Interest Entities

 

 

20.          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 for the years 2011 to 2015 related to these leases. The leases do not contain fixed price purchase options or residual value guarantees.  However, the lease agreements include fixed rate renewal periods which may have a significant impact on the VIEs’ economic performance.  We have concluded that these fixed rate renewal periods may 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.  In addition to the fixed rate renewal periods, our primary beneficiary analysis also considered that APS is the operating agent for Palo Verde, has fair value purchase options, and is obligated to decommission the leased assets.

 

As a result of consolidation we eliminate rent expense and recognize depreciation and interest expense, resulting in an increase in net income for 2011, 2010 and 2009 of $28 million, $20 million and $19 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, 2011 and December 31, 2010 include the following amounts relating to the VIEs (in millions):

 

 

 

December 31,
2011

 

December 31,
2010

 

Palo Verde sale leaseback property plant and equipment, net of accumulated depreciation

 

$

133

 

$

138

 

Current maturities of long term-debt

 

31

 

29

 

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

 

66

 

97

 

Equity-Noncontrolling interests

 

108

 

91

 

 

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 to be 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 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, 2011, APS would have been required to pay the noncontrolling equity participants approximately $141 million and assume $97 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.

Discontinued Operations
Discontinued Operations

 

 

21.          Discontinued Operations

 

SunCor In 2009, our real estate subsidiary, SunCor, began disposing of its homebuilding operations, master-planned communities, land parcels, commercial assets and golf courses in order to eliminate its outstanding debt.  All activity for the income statement and prior comparative period income statement amounts are included in discontinued operations.  In 2010 and 2009, SunCor recorded real estate impairment charges (see Note 22).  SunCor’s asset sales resulted in no gain for 2010 and 2009 due to the impairment charges discussed above.  At December 31, 2011, SunCor had approximately $9 million of assets on its balance sheet, including $7 million of intercompany receivables, and $2 million of other assets.  In February 2012, SunCor filed for protection under the United States Bankruptcy Code to complete an orderly liquidation of its business.  We do not expect SunCor’s bankruptcy to have a material impact on Pinnacle West’s financial position, results of operations, or cash flows.

 

APSES — On August 19, 2011, Pinnacle West sold its investment in APSES.  The sale resulted in an after-tax gain from discontinued operations of approximately $10 million.  In June 2010, APSES sold its district cooling business.  As a result of that sale, we recorded an after-tax gain from discontinued operations of approximately $25 million.  Prior period income statement amounts related to these sales and the associated revenues and costs are reflected in discontinued operations.

 

The following table provides revenue, income (loss) before income taxes and income (loss) after taxes classified as discontinued operations in Pinnacle West’s Consolidated Statements of Income for the years ended December 31, 2011, 2010 and 2009 (dollars in millions):

 

 

 

2011

 

2010

 

2009

 

Revenue:

 

 

 

 

 

 

 

SunCor

 

$

1

 

$

30

 

$

114

 

APSES

 

36

 

127

 

40

 

Total revenue

 

$

37

 

$

157

 

$

154

 

 

 

 

 

 

 

 

 

Income (loss) before taxes:

 

 

 

 

 

 

 

SunCor

 

$

(2

)

$

(10

)

$

(276

)

APSES

 

21

 

51

 

(3

)

Total income (loss) before taxes

 

$

19

 

$

41

 

$

(279

)

 

 

 

 

 

 

 

 

Income (loss) after taxes:

 

 

 

 

 

 

 

SunCor (a)

 

$

(1

)

$

(6

)

$

(167

)

APSES

 

12

 

31

 

(2

)

Total income (loss) after taxes

 

$

11

 

$

25

 

$

(169

)

 

(a)                                  Includes a tax benefit recognized by the parent company in accordance with an intercompany tax sharing agreement of $1 million for the year ended December 31, 2011, $4 million for the year ended December 31, 2010, and $113 million for the year ended December 31, 2009.

Real Estate Impairment Charge
Real Estate Impairment Charge

 

 

22.                               Real Estate Impairment Charge

 

In 2009, SunCor undertook and completed a review of its assets and strategies within its various markets as a result of the distressed conditions in real estate and credit markets.  Based on the results of the review, on March 27, 2009, SunCor’s Board of Directors authorized a series of strategic transactions to dispose of SunCor’s homebuilding operations, master-planned communities, land parcels, commercial assets and golf courses in order to reduce SunCor’s outstanding debt.  As a result, SunCor took impairment charges in 2009 and 2010.  There have been no additional impairments in 2011.  All SunCor’s operations are reflected in discontinued operations (see Note 21).  The detail of the impairment charge is as follows (dollars in millions, and before income taxes):

 

 

 

2010

 

2009

 

Discontinued Operations:

 

 

 

 

 

Homebuilding and master-planned communities

 

$

1

 

$

170

 

Land parcels and commercial assets

 

11

 

87

 

Golf courses

 

1

 

23

 

Other

 

4

 

 

Subtotal

 

17

 

280

 

Less noncontrolling interests

 

 

(14

)

Total

 

$

17

 

$

266

 

Nuclear Decommissioning Trust
Nuclear Decommissioning Trust

 

 

23.          Nuclear Decommissioning Trust

 

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 their 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 liabilitiesThe 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, 2011 and December 31, 2010 (dollars in millions):

 

 

 

Fair Value

 

Total
Unrealized
Gains

 

Total
Unrealized
Losses

 

2011

 

 

 

 

 

 

 

Equity securities

 

$

175

 

$

44

 

$

(1

)

Fixed income securities

 

340

 

23

 

(1

)

Net payables (a)

 

(1

)

 

 

Total

 

$

514

 

$

67

 

$

(2

)

 

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

 

 

 

Fair Value

 

Total
Unrealized
Gains

 

Total
Unrealized
Losses

 

2010

 

 

 

 

 

 

 

Equity securities

 

$

168

 

$

43

 

$

(1

)

Fixed income securities

 

312

 

12

 

(2

)

Net payables (a)

 

(10

)

 

 

Total

 

$

470

 

$

55

 

$

(3

)

 

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

 

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,

 

 

 

2011

 

2010

 

2009

 

 

 

 

 

 

 

 

 

Realized gains

 

$

8

 

$

17

 

$

10

 

Realized losses

 

(5

)

(4

)

(7

)

Proceeds from the sale of securities (a)

 

498

 

560

 

441

 

 

(a)           Proceeds are reinvested in the trust.

 

The fair value of fixed income securities, summarized by contractual maturities, at December 31, 2011 is as follows (dollars in millions):

 

 

 

Fair Value

 

Less than one year

 

$

13

 

1 year - 5 years

 

83

 

5 years - 10 years

 

114

 

Greater than 10 years

 

130

 

Total

 

$

340

 

 

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 INCOME

(in thousands)

 

 

 

Year Ended December 31,

 

 

 

2011

 

2010

 

2009

 

 

 

 

 

 

 

 

 

Operating revenues

 

$

1,034

 

$

2,810

 

$

1,157

 

 

 

 

 

 

 

 

 

Operating expenses

 

8,811

 

9,880

 

10,420

 

 

 

 

 

 

 

 

 

Operating loss

 

(7,777

)

(7,070

)

(9,263

)

 

 

 

 

 

 

 

 

Other

 

 

 

 

 

 

 

Equity in earnings (losses) of subsidiaries

 

335,859

 

358,527

 

(37,214

)

Other income (expense)

 

(1,481

)

(588

)

2,102

 

Total

 

334,378

 

357,939

 

(35,112

)

 

 

 

 

 

 

 

 

Interest expense

 

8,053

 

14,346

 

14,129

 

 

 

 

 

 

 

 

 

Income (loss) from continuing operations

 

318,548

 

336,523

 

(58,504

)

 

 

 

 

 

 

 

 

Income tax benefit

 

(8,938

)

(9,596

)

(14,060

)

 

 

 

 

 

 

 

 

Income (loss) from continuing operations — net of income taxes

 

327,486

 

346,119

 

(44,444

)

Income from discontinued operations — net of income taxes

 

11,987

 

3,934

 

112,774

 

 

 

 

 

 

 

 

 

Net income attributable to common shareholders

 

$

339,473

 

$

350,053

 

$

68,330

 

 

See Notes to Pinnacle West’s Consolidated Financial Statements.

 

<END XBRL NOTE>

 

<START  XBRL NOTE>

 

PINNACLE WEST CAPITAL CORPORATION HOLDING COMPANY

SCHEDULE I — CONDENSED FINANCIAL INFORMATION OF REGISTRANT

CONDENSED BALANCE SHEETS

(in thousands)

 

 

 

Balance at December 31,

 

 

 

2011

 

2010

 

ASSETS

 

 

 

 

 

 

 

 

 

 

 

Current assets

 

 

 

 

 

Cash and cash equivalents

 

$

12,710

 

$

7,725

 

Customer and other receivables

 

62,418

 

75,745

 

Current deferred income taxes

 

19,068

 

19,855

 

Income tax receivable

 

1,804

 

3,736

 

Other current assets

 

55

 

61

 

Total current assets

 

96,055

 

107,122

 

 

 

 

 

 

 

Investments and other assets

 

 

 

 

 

Investments in subsidiaries

 

4,026,289

 

3,901,935

 

Deferred income taxes

 

27,220

 

 

Other assets

 

16,898

 

58,071

 

Total investments and other assets

 

4,070,407

 

3,960,006

 

 

 

 

 

 

 

Total Assets

 

$

4,166,462

 

$

4,067,128

 

 

 

 

 

 

 

LIABILITIES AND EQUITY

 

 

 

 

 

 

 

 

 

 

 

Current liabilities

 

 

 

 

 

Accounts payable

 

$

4,811

 

$

4,981

 

Accrued taxes

 

9,795

 

4,216

 

Short-term borrowings

 

 

16,600

 

Current maturities of long-term debt

 

 

175,000

 

Other current liabilities

 

28,295

 

28,101

 

Total current liabilities

 

42,901

 

228,898

 

 

 

 

 

 

 

Long-term debt less current maturities

 

125,000

 

 

 

 

 

 

 

 

Deferred credits and other

 

 

 

 

 

Pension and other postretirement liabilities

 

32,513

 

28,607

 

Other

 

35,462

 

34,397

 

Total deferred credits and other

 

67,975

 

63,004

 

 

 

 

 

 

 

Common stock equity

 

 

 

 

 

Common stock

 

2,439,530

 

2,419,133

 

Accumulated other comprehensive loss

 

(152,163

)

(159,767

)

Retained earnings

 

1,534,483

 

1,423,961

 

Total Pinnacle West Shareholders’ equity

 

3,821,850

 

3,683,327

 

Noncontrolling interests

 

108,736

 

91,899

 

Total Equity

 

3,930,586

 

3,775,226

 

Total Liabilities and Equity

 

$

4,166,462

 

$

4,067,128

 

 

See Notes to Pinnacle West’s Consolidated Financial Statements.

 

<END XBRL NOTE>

 

<START  XBRL NOTE>

 

PINNACLE WEST CAPITAL CORPORATION HOLDING COMPANY

SCHEDULE I — CONDENSED FINANCIAL INFORMATION OF REGISTRANT

CONDENSED STATEMENTS OF CASH FLOWS

(in thousands)

 

 

 

Year Ended December 31,

 

 

 

2011

 

2010

 

2009

 

 

 

 

 

 

 

 

 

Cash flows from operating activities

 

 

 

 

 

 

 

Net income

 

$

339,473

 

$

350,053

 

$

68,330

 

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

 

 

 

 

 

 

 

Equity in earnings of subsidiaries — net

 

(335,859

)

(358,527

)

37,214

 

Depreciation and amortization

 

97

 

143

 

127

 

Gain on sale of energy-related business

 

(10,404

)

 

 

Deferred income taxes

 

7,387

 

40,342

 

(106,536

)

Customer and other receivables

 

(24,201

)

(18,175

)

(2,303

)

Accounts payable

 

(2,677

)

7,468

 

466

 

Accrued taxes and income tax receivables — net

 

7,512

 

59,640

 

44,625

 

Dividends received from subsidiaries

 

228,900

 

207,000

 

170,000

 

Other net

 

19,270

 

423

 

(2,379

)

Net cash flow provided by operating activities

 

229,498

 

288,367

 

209,544

 

 

 

 

 

 

 

 

 

Cash flows from investing activities

 

 

 

 

 

 

 

Investments in subsidiaries

 

 

(183,544

)

(4,967

)

Repayments of loans from subsidiaries

 

61,143

 

98,406

 

25,240

 

Proceeds from sale of energy-related products and services business

 

45,111

 

 

 

Advances of loans to subsidiaries

 

(64,970

)

(119,293

)

(21,587

)

Proceeds from sale of life insurance policies

 

9,357

 

 

 

Net cash flow provided by (used for) investing activities

 

50,641

 

(204,431

)

(1,314

)

 

 

 

 

 

 

 

 

Cash flows from financing activities

 

 

 

 

 

 

 

Issuance of long-term debt

 

175,000

 

 

 

Short-term borrowings and payments — net

 

(16,600

)

(132,487

)

4,566

 

Dividends paid on common stock

 

(221,728

)

(216,979

)

(205,076

)

Repayment of long-term debt

 

(225,000

)

 

 

Common stock equity issuance

 

15,841

 

255,971

 

3,302

 

Other

 

(2,667

)

 

 

Net cash flow used for financing activities

 

(275,154

)

(93,495

)

(197,208

)

 

 

 

 

 

 

 

 

Net increase (decrease) in cash and cash equivalents

 

4,985

 

(9,559

)

11,022

 

 

 

 

 

 

 

 

 

Cash and cash equivalents at beginning of year

 

7,725

 

17,284

 

6,262

 

 

 

 

 

 

 

 

 

Cash and cash equivalents at end of year

 

$

12,710

 

$

7,725

 

$

17,284

 

 

See Notes to Pinnacle West’s Consolidated Financial Statements.

 

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
beginning
of period

 

Charged to
cost and
expenses

 

Charged
to other
accounts

 

Deductions

 

Balance
at end of
period

 

 

 

 

 

 

 

 

 

 

 

 

 

Reserve for uncollectibles:

 

 

 

 

 

 

 

 

 

 

 

2011

 

$

4,709

 

$

5,672

 

$

 

$

6,633

 

$

3,748

 

2010

 

4,573

 

6,905

 

 

6,769

 

4,709

 

2009

 

3,383

 

7,617

 

 

6,427

 

4,573

 

 

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
beginning
of period

 

Charged to
cost and
expenses

 

Charged
to other
accounts

 

Deductions

 

Balance
at end of
period

 

 

 

 

 

 

 

 

 

 

 

 

 

Reserve for uncollectibles:

 

 

 

 

 

 

 

 

 

 

 

2011

 

$

4,376

 

$

5,751

 

$

 

$

6,379

 

$

3,748

 

2010

 

4,483

 

6,756

 

 

6,863

 

4,376

 

2009

 

3,155

 

7,062

 

 

5,734

 

4,483

 

Summary of Significant Accounting Policies (Policies)

 

 

Our accounting records are maintained in accordance with accounting principles generally accepted in the United States of America (“GAAP”).  The preparation of financial statements in accordance with GAAP requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities, disclosure of contingent assets and liabilities at the date of the financial statements and reported amounts of revenues and expenses during the reporting period.  Actual results could differ from those estimates.

 

 

APS is regulated by the ACC and the 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 other regulated entities in the same jurisdiction.  This determination reflects the current political and regulatory climate in the state 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.

 

 

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 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.

 

Effective January 1, 2010, electric revenues also include proceeds for line extension payments for new or upgraded service in accordance with the 2009 retail rate case settlement agreement (see Note 3).  This revenue treatment continues through 2012, or until new rates are established in APS’s next general retail rate case, if that is before year end 2012.  Certain proceeds received under previous versions of the line extension policy, or for activities not involving an extension or upgrade of service (e.g., service relocations at the request of governmental entities or undergrounding of overhead facilities) will continue to be treated as contributions in aid of construction and will not impact electric revenues.

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.

 

 

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 for the asset retirement obligations related to its regulated assets.  This regulatory liability represents 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 capitalized 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, 2011 were as follows:

 

·                                          Fossil plant — 18 years;

·                                          Nuclear plant — 29 years;

·                                          Other generation — 28 years;

·                                          Transmission — 38 years;

·                                          Distribution — 35 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 new Palo Verde Nuclear plant lives, effective January 1, 2012.

 

 

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 10.25% for 2011, 9.2% for 2010, and 5.9% for 2009.  APS compounds AFUDC semi-annually and ceases to accrue AFUDC when construction work is completed and the property is placed in service.

 

 

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.

 

 

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 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 unobservable inputs, such as models and other valuation methods, 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.

 

 

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 that may qualify as derivatives, including futures, forwards, options and swaps. As part of our overall risk management program, we use such instruments to hedge purchases and sales of electricity and fuels. The changes in market value of such contracts have a high correlation to price changes in the hedged transactions.

 

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 18 for additional information about our derivative instruments.

 

 

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.

 

 

Pinnacle West sponsors a qualified defined benefit and account balance pension plan for the employees of Pinnacle West and its subsidiaries.  We also sponsor another postretirement benefit plan for the employees of Pinnacle West and our subsidiaries and provide 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.

 

 

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. 

 

 

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 liability 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.

 

 

We did not have any real estate investments at December 31, 2011 and December 31, 2010 on our Consolidated Balance Sheets.  For the purposes of evaluating impairment, in accordance with the provisions on accounting for the impairment or disposal of long-lived assets; we classified our real estate assets, such as land under development, land held for future development, and commercial property as “held and used” in 2010 and 2009.  When events or changes in circumstances indicated that the carrying values of real estate assets considered held and used would not be recoverable, we compared the undiscounted cash flows that we estimated would be generated by each asset to its carrying amount.  If the carrying amount exceeded the undiscounted cash flows, we adjusted the asset to fair value and recognized an impairment charge.  The adjusted value became the new book value (carrying amount) for held and used assets.  Our internal models used inputs that we believe were consistent with those that would be used by market participants.

 

 

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

 

 

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. 

 

 

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.

Summary of Significant Accounting Policies (Tables)
Impact of the reclassifications to prior year (previously reported) amounts

 

 

Statement of Income for the Year Ended
December, 2010

 

As
previously
reported

 

Reclassifications
for discontinued
operations

 

Amount reported
after reclassification
for discontinued
operations

 

Operating Revenues

 

 

 

 

 

 

 

Other revenues

 

$

82,967

 

$

(74,446

)

$

8,521

 

Operating Expenses

 

 

 

 

 

 

 

Operations and maintenance

 

877,406

 

(7,221

)

870,185

 

Depreciation and amortization

 

414,555

 

(76

)

414,479

 

Taxes other than income taxes

 

135,334

 

(6

)

135,328

 

Other expenses

 

65,651

 

(58,142

)

7,509

 

Other

 

 

 

 

 

 

 

Other income

 

6,368

 

19

 

6,387

 

Other expense

 

(9,764

)

(157

)

(9,921

)

Interest Expense

 

 

 

 

 

 

 

Allowance for borrowed funds used during construction

 

(16,539

)

60

 

(16,479

)

Income Taxes

 

164,321

 

(3,452

)

160,869

 

Income From Continuing Operations

 

350,598

 

(5,747

)

344,851

 

Income From Discontinued Operations

 

19,611

 

5,747

 

25,358

 

 

Statement of Income for the Year Ended
December, 2009

 

As
previously
reported

 

Reclassifications
for discontinued
operations

 

Amount reported
after reclassification
for discontinued
operations

 

Operating Revenues

 

 

 

 

 

 

 

Other revenues

 

$

26,723

 

$

(22,254

)

$

4,469

 

Operating Expenses

 

 

 

 

 

 

 

Operations and maintenance

 

831,863

 

(9,563

)

822,300

 

Depreciation and amortization

 

407,463

 

(109

)

407,354

 

Taxes other than income taxes

 

123,277

 

(7

)

123,270

 

Other expenses

 

24,534

 

(18,550

)

5,984

 

Other

 

 

 

 

 

 

 

Other income

 

5,278

 

(119

)

5,159

 

Other expense

 

(14,269

)

(31

)

(14,300

)

Interest Expense

 

 

 

 

 

 

 

Interest charges

 

237,527

 

239

 

237,766

 

Allowance for borrowed funds used during construction

 

(10,430

)

51

 

(10,379

)

Income Taxes

 

136,506

 

2,045

 

138,551

 

Income From Continuing Operations

 

252,558

 

3,490

 

256,048

 

Income From Discontinued Operations

 

(179,794

)

(3,490

)

(183,284

)

 

Balance Sheets - December 31, 2010

 

As
previously
reported

 

Reclassifications for
regulatory assets and
liabilities

 

Amount reported
after reclassification
for regulatory assets
and liabilities

 

Current Assets — Other regulatory assets

 

$

 

$

62,286

 

$

62,286

 

Current Assets — Deferred income taxes

 

94,602

 

30,295

 

124,897

 

Deferred Debits — Regulatory assets

 

1,048,656

 

(62,286

)

986,370

 

Current Liabilities — Deferred fuel and purchased power regulatory liability

 

 

58,442

 

58,442

 

Current Liabilities — Other regulatory liabilities

 

 

80,526

 

80,526

 

Deferred Credits and Other — Deferred income taxes

 

1,833,566

 

30,295

 

1,863,861

 

Deferred Credits and Other — Deferred fuel and purchased power regulatory liability

 

58,442

 

(58,442

)

 

Deferred Credits and Other — Regulatory liabilities

 

694,589

 

(80,526

)

614,063

 

 

Statement of Cash Flows for the
Year Ended December 31, 2010

 

As previously
reported

 

Reclassifications for
regulatory assets and
liabilities and to
conform to current year
presentation

 

Amounts reported
after reclassification
for regulatory assets
and liabilities and to
conform to current
year presentation

 

Cash Flows from Operating Activities

 

 

 

 

 

 

 

Other current assets

 

$

5,246

 

$

4,129

 

$

9,375

 

Other current liabilities

 

5,204

 

(2,283

)

2,921

 

Change in other regulatory liabilities

 

54,518

 

2,283

 

56,801

 

Change in other long-term assets

 

(43,189

)

(4,751

)

(47,940

)

Expenditures for real estate investments

 

(622

)

622

 

 

Other changes in real estate assets

 

4,068

 

(4,068

)

 

Change in other long-term liabilities

 

(101,456

)

4,068

 

(97,388

)

 

Statement of Cash Flows for the
Year Ended December 31, 2009

 

As previously
reported

 

Reclassifications for
regulatory assets and
liabilities and to
conform to current year
presentation

 

Amounts reported after
reclassification for
regulatory assets and
liabilities and to
conform to current year
presentation

 

Cash Flows from Operating Activities

 

 

 

 

 

 

 

Other current assets

 

$

 24,647

 

$

 13,759

 

$

 38,406

 

Other current liabilities

 

29,274

 

28,006

 

57,280

 

Change in other regulatory liabilities

 

110,642

 

(27,992

)

82,650

 

Change in other long-term assets

 

(47,899

)

(16,730

)

(64,629

)

Change in other long-term liabilities

 

16,377

 

(4,216

)

12,161

 

Expenditures for real estate investments

 

(2,957

)

2,957

 

 

Other changes in real estate assets

 

(4,216

)

4,216

 

 

Regulatory Matters (Tables)

 

 

 

 

Capital Structure

 

Cost of Capital

 

Long-term debt

 

46.1

%

6.38

%

Common stock equity

 

53.9

%

11.00

%

Weighted-average cost of capital

 

 

 

8.87

%

 

 

 

 

Year Ended
December 31,

 

 

 

2011

 

2010

 

Beginning balance

 

$

(58

)

$

(87

)

Deferred fuel and purchased power costs-current period

 

(69

)

(93

)

Amounts refunded through revenues

 

155

 

122

 

Ending balance

 

$

28

 

$

(58

)

 

 

 

 

Remaining
Amortization

 

December 31, 2011

 

December 31, 2010

 

 

 

Period

 

Current

 

Non-Current

 

Current

 

Non-Current

 

Pension and other postretirement benefits

 

(a)

 

$

 

$

1,023

 

$

 

$

669

 

Income taxes —AFUDC equity

 

2041

 

3

 

81

 

3

 

69

 

Deferred fuel and purchased power — mark-to-market (Note 18)

 

2016

 

43

 

34

 

42

 

35

 

Transmission vegetation management

 

2016

 

9

 

32

 

 

46

 

Coal reclamation

 

2026

 

2

 

35

 

2

 

36

 

Palo Verde VIE (Note 20)

 

2015

 

 

35

 

 

33

 

Deferred compensation

 

2036

 

 

33

 

 

32

 

Deferred fuel and purchased power (b)

 

2012

 

28

 

 

 

 

Income taxes — Medicare subsidy

 

2024

 

2

 

18

 

2

 

21

 

Loss on reacquired debt

 

2034

 

1

 

19

 

1

 

21

 

Income taxes — investment tax credit basis adjustment

 

2044

 

 

15

 

 

 

Pension and other postretirement benefits deferral

 

2015

 

 

12

 

 

 

Demand side management

 

2013

 

7

 

1

 

12

 

6

 

Other

 

Various

 

2

 

14

 

 

18

 

Total regulatory assets (c)

 

 

 

$

97

 

$

1,352

 

$

62

 

$

986

 

 

(a)                                  This asset represents the future recovery in earnings of under-funded pension and other postretirement benefits obligation costs 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.

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

(c)                                  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.”

 

 

 

 

Remaining
Amortization

 

December 31, 2011

 

December 31, 2010

 

 

 

Period

 

Current

 

Non-Current

 

Current

 

Non-Current

 

Removal costs

 

(a)

 

$

22

 

$

349

 

$

22

 

$

357

 

Asset retirement obligations

 

(a)

 

 

225

 

 

184

 

Renewable energy standard (b)

 

2012

 

54

 

 

50

 

 

Income taxes — change in rates

 

2041

 

 

59

 

 

 

Spent nuclear fuel

 

2047

 

5

 

44

 

4

 

41

 

Deferred gains on utility property

 

2019

 

2

 

14

 

2

 

16

 

Income taxes-unamortized investment tax credit

 

2044

 

1

 

30

 

 

1

 

Deferred fuel and purchased power (b)(c)

 

 

 

 

 

58

 

 

Other

 

Various

 

4

 

16

 

3

 

15

 

Total regulatory liabilities

 

 

 

$

88

 

$

737

 

$

139

 

$

614

 

 

(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.

(c)                                  Subject to a carrying charge.

Income Taxes (Tables)

 

 

 

 

2011

 

2010

 

2009

 

Total unrecognized tax benefits, January 1

 

$

127,595

 

$

201,216

 

$

63,318

 

Additions for tax positions of the current year

 

10,915

 

7,551

 

44,094

 

Additions for tax positions of prior years

 

 

 

98,942

 

Reductions for tax positions of prior years for:

 

 

 

 

 

 

 

Changes in judgment

 

(1,555

)

(11,017

)

 

Settlements with taxing authorities

 

(124

)

(62,199

)

(4,089

)

Lapses of applicable statute of limitations

 

(826

)

(7,956

)

(1,049

)

Total unrecognized tax benefits, December 31

 

$

136,005

 

$

127,595

 

$

201,216

 

 

 

 

 

Year Ended December 31,

 

 

 

2011

 

2010

 

2009

 

Current:

 

 

 

 

 

 

 

Federal

 

$

(310

)

$

(108,827

)

$

(38,502

)

State

 

15,140

 

25,545

 

(38,080

)

Total current

 

14,830

 

(83,282

)

(76,582

)

Deferred:

 

 

 

 

 

 

 

Federal

 

159,566

 

260,236

 

62,874

 

State

 

16,626

 

10,911

 

42,618

 

Discontinued operations

 

 

(10,736

)

 

Total deferred

 

176,192

 

260,411

 

105,492

 

Total income tax expense

 

191,022

 

177,129

 

28,910

 

Less: income tax expense (benefit) on discontinued operations

 

7,418

 

16,260

 

(109,641

)

Income tax expense — continuing operations

 

$

183,604

 

$

160,869

 

$

138,551

 

 

 

 

 

Year Ended December 31,

 

 

 

2011

 

2010

 

2009

 

 

 

 

 

 

 

 

 

Federal income tax expense at 35% statutory rate

 

$

188,733

 

$

177,002

 

$

138,110

 

Increases (reductions) in tax expense resulting from:

 

 

 

 

 

 

 

State income tax net of federal income tax benefit

 

19,594

 

17,485

 

15,068

 

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

 

 

(17,300

)

 

Medicare Subsidy Part-D

 

823

 

1,311

 

(2,095

)

Allowance for equity funds used during construction (see Note 1)

 

(6,881

)

(6,563

)

(4,265

)

Palo Verde VIE noncontrolling interest (see Note 20)

 

(9,636

)

(7,057

)

(6,723

)

Other

 

(9,029

)

(4,009

)

(1,544

)

Income tax expense — continuing operations

 

$

183,604

 

$

160,869

 

$

138,551

 

 

 

 

December 31,

 

 

 

2011

 

2010

 

Current asset

 

$

130,571

 

$

124,897

 

Long-term liability

 

(1,925,388

)

(1,863,861

)

Deferred income taxes — net

 

$

(1,794,817

)

$

(1,738,964

)

 

 

 

 

December 31,

 

 

 

2011

 

2010

 

DEFERRED TAX ASSETS

 

 

 

 

 

Risk management activities

 

$

117,765

 

$

124,731

 

Regulatory liabilities:

 

 

 

 

 

Asset retirement obligation and removal costs

 

236,739

 

222,448

 

Deferred fuel and purchased power

 

 

23,089

 

Renewable energy standard

 

19,722

 

18,749

 

Unamortized investment tax credits

 

31,460

 

642

 

Other

 

33,155

 

27,718

 

Pension and other postretirement liabilities

 

501,202

 

321,182

 

Real estate investments and assets held for sale

 

 

19,855

 

Renewable energy incentives

 

57,901

 

37,327

 

Credit and loss carryforwards

 

171,915

 

42,971

 

Other

 

73,759

 

68,684

 

Total deferred tax assets

 

1,243,618

 

907,396

 

DEFERRED TAX LIABILITIES

 

 

 

 

 

Plant-related

 

(2,446,908

)

(2,210,976

)

Risk management activities

 

(30,171

)

(30,125

)

Regulatory assets:

 

 

 

 

 

Allowance for equity funds used during construction

 

(33,347

)

(28,276

)

Deferred fuel and purchased power

 

(10,884

)

 

Deferred fuel and purchased power — mark-to-market

 

(30,559

)

(30,276

)

Pension and other postretirement benefits

 

(408,716

)

(264,313

)

Other

 

(73,087

)

(77,078

)

Other

 

(4,763

)

(5,316

)

Total deferred tax liabilities

 

(3,038,435

)

(2,646,360

)

Deferred income taxes — net

 

$

(1,794,817

)

$

(1,738,964

)

Lines of Credit and Short-Term Borrowings (Tables)
Schedule of 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, 2011 (dollars in millions):

 

Credit Facility

 

Expiration

 

Amount
Committed

 

Unused
Amount

 

Commitment
Fees

 

Pinnacle West Revolving Credit Facility

 

November 2016

 

$

200

 

$

200

 

0.275

%

 

 

 

 

 

 

 

 

 

 

APS Revolving Credit Facility

 

November 2016

 

500

 

500

 

0.225

%

 

 

 

 

 

 

 

 

 

 

APS Revolving Credit Facility

 

February 2015

 

500

 

500

 

0.250

%

Total

 

 

 

$

1,200

 

$

1,200

 

 

 

 

The table below presents the consolidated credit facilities and amounts available and outstanding and other short-term borrowings as of December 31, 2010 (dollars in millions):

 

Credit
Facility

 

Expiration

 

Amount
Committed

 

Letters
of
Credit
Used

 

Short-Term
Borrowings

 

Unused
Amount

 

Weighted
Average
Interest
Rate

 

Commitment
Fees

 

Pinnacle West Revolving Credit Facility

 

February 2013

 

$

200

 

$

 

$

 

$

183

 

 

0.625

%

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Pinnacle West Commercial Paper

 

January 2011

 

 

 

17

 

 

0.840

%

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

APS Revolving Credit Facility

 

February  2013

 

500

 

 

 

500

 

 

0.500

%

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

APS Revolving Credit Facility

 

September 2011

 

489

 

20

 

 

469

 

 

0.100

%

Total

 

 

 

$

1,189

 

$

20

 

$

17

 

$

1,152

 

 

 

 

 

Long-Term Debt and Liquidity Matters (Tables)

 

 

 

 

Maturity

 

Interest

 

December 31,

 

 

 

Dates (a)

 

Rates

 

2011

 

2010

 

APS

 

 

 

 

 

 

 

 

 

Pollution Control Bonds:

 

 

 

 

 

 

 

 

 

Variable

 

2024-2038

 

(b)

 

$

43,580

 

$

43,580

 

Fixed

 

2029-2034

 

2.875%-6.000%

 

522,275

 

522,275

 

Pollution control bonds with senior notes

 

2029

 

5.050%

 

90,000

 

90,000

 

Total Pollution Control Bonds

 

 

 

 

 

655,855

 

655,855

 

 

 

 

 

 

 

 

 

 

 

Senior unsecured notes

 

2012-2041

 

4.650%-8.750%

 

2,625,000

 

2,725,000

 

Palo Verde sale leaseback lessor notes

 

2015

 

8.00%

 

96,803

 

126,000

 

Capitalized lease obligations

 

2012

 

(c)

 

1,029

 

2,001

 

Unamortized discount

 

 

 

 

 

(7,198

)

(6,183

)

Total APS Long-term debt

 

 

 

 

 

3,371,489

 

3,502,673

 

Less current maturities

 

 

 

 

 

477,435

 

456,879

 

Total APS Long-term debt less current maturities

 

 

 

 

 

2,894,054

 

3,045,794

 

Pinnacle West

 

 

 

 

 

 

 

 

 

Senior notes

 

2011

 

5.91%

 

 

175,000

 

Term loan

 

2015

 

(d)

 

125,000

 

 

Total Pinnacle West Long-term debt

 

 

 

 

 

125,000

 

175,000

 

Less current maturities

 

 

 

 

 

 

175,000

 

Total Pinnacle West long-term debt less current maturities

 

 

 

 

 

125,000

 

 

TOTAL LONG-TERM DEBT LESS CURRENT MATURITIES

 

 

 

 

 

$

3,019,054

 

$

3,045,794

 

 

(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 0.09% at December 31, 2011 and 0.32% at December 31, 2010.

(c)           The weighted-average interest rate was 5.27% at December 31, 2011 and 5.29% at December 31, 2010.

(d)           The weighted-average interest rate was 1.794% at December 31, 2011.

 

 

Year

 

Consolidated
Pinnacle West

 

Consolidated
APS

 

2012

 

$

477

 

$

477

 

2013

 

123

 

123

 

2014

 

502

 

502

 

2015

 

438

 

313

 

2016

 

358

 

358

 

Thereafter

 

1,606

 

1,606

 

Total

 

$

3,504

 

$

3,379

 

 

 

 

 

As of
December 31, 2011

 

As of
December 31, 2010

 

 

 

Carrying
Amount

 

Fair Value

 

Carrying
Amount

 

Fair Value

 

 

 

 

 

 

 

 

 

 

 

Pinnacle West

 

$

125

 

$

123

 

$

175

 

$

176

 

APS

 

3,371

 

3,803

 

3,503

 

3,737

 

Total

 

$

3,496

 

$

3,926

 

$

3,678

 

$

3,913

 

 

Common Stock and Treasury Stock (Tables)
Schedule of common stock and treasury stock activity

 

 

 

 

Common Stock

 

Treasury Stock

 

 

 

Shares

 

Amount

 

Shares

 

Amount

 

Balance at December 31, 2008

 

100,948,436

 

$

2,151,323

 

(59,827

)

$

(2,854

)

Common stock issuance

 

354,995

 

10,620

 

 

 

Purchase of treasury stock (a)

 

 

 

(66,173

)

(2,156

)

Reissuance of treasury stock for stock compensation

 

 

 

32,761

 

1,198

 

Other

 

224,506

 

(8,648

)

 

 

Balance at December 31, 2009

 

101,527,937

 

2,153,295

 

(93,239

)

(3,812

)

 

 

 

 

 

 

 

 

 

 

Common stock issuance (b)

 

7,172,405

 

263,297

 

 

 

Purchase of treasury stock (a)

 

 

 

(1,994

)

(82

)

Reissuance of treasury stock for stock compensation

 

 

 

44,823

 

1,655

 

Other

 

119,725

 

4,780

 

 

 

Balance at December 31, 2010

 

108,820,067

 

2,421,372

 

(50,410

)

(2,239

)

 

 

 

 

 

 

 

 

 

 

Common stock issuance

 

249,602

 

11,057

 

 

 

Purchase of treasury stock (a)

 

 

 

(88,440

)

(3,720

)

Reissuance of treasury stock for stock compensation

 

 

 

27,689

 

1,242

 

Other

 

287,305

 

11,818

 

 

 

Balance at December 31, 2011

 

109,356,974

 

$

2,444,247

 

(111,161

)

$

(4,717

)

 

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

(b)           In April 2010, Pinnacle West issued 6,900,000 shares of common stock at an offering price of $38.00 per share, resulting in net proceeds of approximately $253 million.  Pinnacle West contributed all of the net proceeds from this offering into APS in the form of equity infusions.  APS has used these contributions to repay short-term indebtedness, to finance capital expenditures and for other general corporate purposes.

Retirement Plans and Other Benefits (Tables)

 

 

 

 

Pension

 

Other Benefits

 

 

 

2011

 

2010

 

2009

 

2011

 

2010

 

2009

 

Service cost-benefits earned during the period

 

$

57,605

 

$

59,064

 

$

54,288

 

$

21,856

 

$

19,236

 

$

18,285

 

Interest cost on benefit obligation

 

124,727

 

122,724

 

118,282

 

46,807

 

42,428

 

39,180

 

Expected return on plan assets

 

(133,678

)

(124,161

)

(116,535

)

(41,536

)

(39,257

)

(34,428

)

Amortization of:

 

 

 

 

 

 

 

 

 

 

 

 

 

Transition obligation

 

 

 

 

452

 

452

 

3,005

 

Prior service cost (credit)

 

1,400

 

1,705

 

2,080

 

(179

)

(539

)

(125

)

Net actuarial loss

 

25,956

 

18,833

 

14,216

 

15,015

 

10,317

 

10,320

 

Net periodic benefit cost

 

$

76,010

 

$

78,165

 

$

72,331

 

$

42,415

 

$

32,637

 

$

36,237

 

Portion of cost charged to expense

 

$

29,312

 

$

37,933

 

$

36,484

 

$

15,208

 

$

15,839

 

$

18,278

 

 

 

 

 

Pension

 

Other Benefits

 

 

 

2011

 

2010

 

2011

 

2010

 

Change in Benefit Obligation

 

 

 

 

 

 

 

 

 

 

 

 

 

Benefit obligation at January 1

 

$

2,345,060

 

$

2,074,131

 

$

827,897

 

$

700,535

 

Service cost

 

57,605

 

59,064

 

21,856

 

19,236

 

Interest cost

 

124,727

 

122,724

 

46,807

 

42,428

 

Benefit payments

 

(104,257

)

(93,776

)

(24,877

)

(20,421

)

Actuarial loss

 

275,991

 

183,365

 

171,674

 

98,094

 

Plan amendments

 

 

(448

)

3,737

 

(11,975

)

Benefit obligation at December 31

 

2,699,126

 

2,345,060

 

1,047,094

 

827,897

 

 

 

 

 

 

 

 

 

 

 

Change in Plan Assets

 

 

 

 

 

 

 

 

 

Fair value of plan assets at January 1

 

1,775,596

 

1,461,808

 

567,410

 

490,455

 

Actual return on plan assets

 

162,042

 

190,380

 

58,367

 

60,255

 

Employer contributions

 

 

200,000

 

18,769

 

16,700

 

Benefit payments

 

(87,088

)

(76,592

)

(35,883

)

 

Fair value of plan assets at December 31

 

1,850,550

 

1,775,596

 

608,663

 

567,410

 

Funded Status at December 31

 

$

(848,576

)

$

(569,464

)

$

(438,431

)

$

(260,487

)

 

 

 

 

2011

 

2010

 

Projected benefit obligation

 

$

2,699,126

 

$

2,345,060

 

Accumulated benefit obligation

 

2,396,575

 

2,065,091

 

Fair value of plan assets

 

1,850,550

 

1,775,596

 

 

 

 

Pension

 

Other Benefits

 

 

 

2011

 

2010

 

2011

 

2010

 

Current liability

 

$

(18,097

)

$

(16,830

)

$

 

$

 

Noncurrent liability

 

(830,479

)

(552,634

)

(438,431

)

(260,487

)

Net amount recognized

 

$

(848,576

)

$

(569,464

)

$

(438,431

)

$

(260,487

)

 

 

 

 

Pension

 

Other Benefits

 

 

 

2011

 

2010

 

2011

 

2010

 

Net actuarial loss

 

$

724,605

 

$

502,938

 

$

400,892

 

$

261,071

 

Prior service cost (credit)

 

4,312

 

5,712

 

(655

)

(4,571

)

Transition obligation

 

 

 

452

 

903

 

APS’s portion recorded as a regulatory asset

 

(632,099

)

(419,774

)

(390,521

)

(249,255

)

Income tax benefit

 

(38,243

)

(35,106

)

(3,296

)

(2,498

)

Accumulated other comprehensive loss

 

$

58,575

 

$

53,770

 

$

6,872

 

$

5,650

 

 

 

 

Pension

 

Other
Benefits

 

Net actuarial loss

 

$

43,070

 

$

23,638

 

Prior service cost (credit)

 

1,143

 

(179

)

Transition obligation

 

 

452

 

Total amounts estimated to be amortized from accumulated other comprehensive loss and regulatory assets in 2012

 

$

44,213

 

$

23,911

 

 

 

 

Benefit Obligations
As of December 31,

 

Benefit Costs
For the Years Ended December 31,

 

 

 

2011

 

2010

 

2011

 

2010

 

2009

 

Discount rate-pension

 

4.42

%

5.31

%

5.31

%

5.90

%

6.11

%

Discount rate-other benefits

 

4.59

%

5.49

%

5.49

%

6.00

%

6.13

%

Rate of compensation increase

 

4.00

%

4.00

%

4.00

%

4.00

%

4.00

%

Expected long-term return on plan assets

 

N/A

 

N/A

 

7.75

%

8.25

%

8.25

%

Initial health care cost trend rate

 

7.50

%

8.00

%

8.00

%

8.00

%

8.00

%

Ultimate health care cost trend rate

 

5.00

%

5.00

%

5.00

%

5.00

%

5.00

%

Number of years to ultimate trend rate

 

4

 

4

 

4

 

4

 

4

 

 

 

 

1% Increase

 

1% Decrease

 

Effect on other postretirement benefits expense, after consideration of amounts capitalized or billed to electric plant participants

 

$

11

 

$

(9

)

Effect on service and interest cost components of net periodic other postretirement benefit costs

 

14

 

(11

)

Effect on the accumulated other postretirement benefit obligation

 

187

 

(148

)

 

 

The fair value of Pinnacle West’s pension plan and other postretirement benefit plan assets at December 31, 2011, by asset category, are as follows (dollars in thousands):

 

 

 

Quoted Prices
in Active
Markets for
Identical
Assets
(Level 1)

 

Significant
Other
Observable
Inputs
(Level 2)

 

Other (a)

 

Balance at
December 31,
2011

 

Pension Plan:

 

 

 

 

 

 

 

 

 

Assets:

 

 

 

 

 

 

 

 

 

Cash and cash equivalents

 

$

1,441

 

$

 

$

 

$

1,441

 

Fixed Income Securities:

 

 

 

 

 

 

 

 

 

Corporate

 

 

584,619

 

 

584,619

 

U.S. Treasury

 

207,862

 

 

 

207,862

 

Other (b)

 

 

62,906

 

 

62,906

 

Equities:

 

 

 

 

 

 

 

 

 

U.S. Companies

 

436,393

 

 

 

436,393

 

International Companies

 

118,263

 

 

 

118,263

 

Common and collective trusts:

 

 

 

 

 

 

 

 

 

U.S. Equities

 

 

139,321

 

 

139,321

 

International Equities

 

 

156,407

 

 

156,407

 

Real estate

 

 

106,147

 

 

106,147

 

Short-term investments and other

 

 

29,913

 

7,278

 

37,191

 

 

 

 

 

 

 

 

 

 

 

Total Pension Plan

 

$

763,959

 

$

1,079,313

 

$

7,278

 

$

1,850,550

 

Other Benefits:

 

 

 

 

 

 

 

 

 

Assets:

 

 

 

 

 

 

 

 

 

Cash and cash equivalents

 

$

160

 

$

 

$

 

$

160

 

Fixed Income Securities:

 

 

 

 

 

 

 

 

 

Corporate

 

 

148,417

 

 

148,417

 

U.S. Treasury

 

103,321

 

 

 

103,321

 

Other (b)

 

 

30,105

 

 

30,105

 

Equities:

 

 

 

 

 

 

 

 

 

U.S. Companies

 

179,235

 

 

 

179,235

 

International Companies

 

22,486

 

 

 

22,486

 

Common and collective trusts:

 

 

 

 

 

 

 

 

 

U.S. Equities

 

 

52,507

 

 

52,507

 

International Equities

 

 

53,504

 

 

53,504

 

Real Estate

 

 

8,446

 

 

8,446

 

Short-term investments and other

 

 

8,516

 

1,966

 

10,482

 

 

 

 

 

 

 

 

 

 

 

Total Other Benefits

 

$

305,202

 

$

301,495

 

$

1,966

 

$

608,663

 

 

(a)                                  Represents plan receivables and payables.

 

(b)                                 This category consists primarily of debt securities issued by municipalities.

 

The fair value of Pinnacle West’s pension plan and other postretirement benefit plan assets at December 31, 2010, by asset category, are as follows (dollars in thousands):

 

 

 

Quoted Prices
in Active
Markets for
Identical
Assets
(Level 1)

 

Significant
Other
Observable
Inputs
(Level 2)

 

Other (a)

 

Balance at
December 31,
2010

 

Pension Plan:

 

 

 

 

 

 

 

 

 

Assets:

 

 

 

 

 

 

 

 

 

Cash and cash equivalents

 

$

2,375

 

$

 

$

 

$

2,375

 

Fixed Income Securities:

 

 

 

 

 

 

 

 

 

Corporate

 

 

508,946

 

 

508,946

 

U.S. Treasury

 

163,313

 

 

 

163,313

 

Other (b)

 

 

53,358

 

 

53,358

 

Equities:

 

 

 

 

 

 

 

 

 

U.S. Companies

 

462,973

 

 

 

462,973

 

International Companies

 

129,094

 

 

 

129,094

 

Other investments

 

 

5,549

 

8,071

 

13,620

 

Common and collective trusts:

 

 

 

 

 

 

 

 

 

U.S. Equities

 

 

146,705

 

 

146,705

 

International Equities

 

 

177,114

 

 

177,114

 

Real estate

 

 

92,454

 

 

92,454

 

Short-term investments

 

 

25,644

 

 

25,644

 

 

 

 

 

 

 

 

 

 

 

Total Pension Plan

 

$

757,755

 

$

1,009,770

 

$

8,071

 

$

1,775,596

 

Other Benefits:

 

 

 

 

 

 

 

 

 

Assets:

 

 

 

 

 

 

 

 

 

Cash and cash equivalents

 

$

243

 

$

 

$

 

$

243

 

Fixed Income Securities:

 

 

 

 

 

 

 

 

 

Corporate

 

 

118,660

 

 

118,660

 

U.S. Treasury

 

74,049

 

 

 

74,049

 

Other (b)

 

 

24,456

 

 

24,456

 

Equities:

 

 

 

 

 

 

 

 

 

U.S. Companies

 

179,655

 

 

 

179,655

 

International Companies

 

25,121

 

 

 

25,121

 

Other investments

 

 

365

 

2,034

 

2,399

 

Common and collective trusts:

 

 

 

 

 

 

 

 

 

U.S. Equities

 

 

54,144

 

 

54,144

 

International Equities

 

 

61,455

 

 

61,455

 

Real Estate

 

 

7,357

 

 

7,357

 

Short-term investments

 

 

19,871

 

 

19,871

 

 

 

 

 

 

 

 

 

 

 

Total Other Benefits

 

$

279,068

 

$

286,308

 

$

2,034

 

$

567,410

 

 

(a)                                  Represents plan receivables and payables.

(b)                                 This category consists primarily of municipal debt securities issued by municipalities.

 

 

 

 

Year Ended
December 31, 2010

 

Common and Collective Trusts — Real Estate

 

Pension

 

Other
Benefits

 

 

 

 

 

 

 

Beginning balance at January 1

 

$

64,212

 

$

6,504

 

Actual return on assets still held (a)

 

(204

)

(23

)

Purchases, sales, and settlements

 

18,003

 

45

 

Transfers in and/or out of Level 3 (b)

 

(82,011

)

(6,526

)

Ending balance at December 31

 

$

 

$

 

 

(a)                                  The return for December 31, 2010 represents the return on assets held as of March 31, 2010, the beginning of the period in which all the assets were transferred out of Level 3.

 

(b)                                 Transfers into and out of Level 3 are measured at the beginning of the period in which the transfer occurs.  Transfers out of Level 3 during 2010 relate to our Real Estate Common and Collective Trust being transferred to a Level 2 investment.  During 2009 the Real Estate Common and Collective Trust had special redemption restrictions in place, which limited our ability to transact at the trust’s NAV.  During 2010 these special redemption restrictions were lifted, and in 2010 and 2011 we were able to transact at the NAV according to the trust’s contractual redemption policy.

 

 

Year

 

Pension

 

Other Benefits (a)

 

2012

 

$

113,075

 

$

27,610

 

2013

 

122,750

 

30,562

 

2014

 

132,302

 

33,451

 

2015

 

141,516

 

36,489

 

2016

 

154,379

 

39,525

 

Years 2017-2021

 

941,377

 

246,091

 

 

(a)                                  The estimated future other benefit payments take into account the Medicare Part D subsidy.

Leases (Tables)
Estimated future minimum lease payments for Pinnacle West's and APS's operating leases, excluding purchased power agreements

 

 

Year

 

Pinnacle West
Consolidated

 

APS

 

2012

 

$

21

 

$

18

 

2013

 

18

 

15

 

2014

 

15

 

12

 

2015

 

13

 

10

 

2016

 

2

 

2

 

Thereafter

 

23

 

22

 

Total future lease commitments

 

$

92

 

$

79

 

Jointly-Owned Facilities (Tables)
APS's interests in jointly-owned facilities recorded on the Consolidated Balance Sheets

 

 

 

 

Percent
Owned

 

Plant in
Service

 

Accumulated
Depreciation

 

Construction
Work in
Progress

 

Generating facilities:

 

 

 

 

 

 

 

 

 

Palo Verde Units 1 and 3

 

29.1

%

$

2,061,894

 

$

1,154,141

 

$

66,558

 

Palo Verde Unit 2 (a)

 

17.0

%

661,006

 

365,704

 

33,032

 

Palo Verde Sale Leaseback

 

 

(a)

351,050

 

218,186

 

 

Four Corners Units 4 and 5

 

15.0

%

165,139

 

104,910

 

2,357

 

Four Corners common

 

38.44

%

16,413

 

5,997

 

750

 

Navajo Generating Station Units 1, 2 and 3

 

14.0

%

264,227

 

170,777

 

10,327

 

Cholla common facilities (b)

 

63.3

%(c)

146,642

 

51,985

 

1,661

 

Transmission facilities:

 

 

 

 

 

 

 

 

 

ANPP 500kV System

 

33.0

%(c)

88,451

 

30,123

 

10,161

 

Navajo Southern System

 

25.9

%(c)

51,174

 

15,161

 

920

 

Palo Verde — Yuma 500kV System

 

44.1

%(c)

8,816

 

4,331

 

 

Four Corners Switchyards

 

39.6

%(c)

19,630

 

5,696

 

1,004

 

Phoenix — Mead System

 

17.5

%(c)

39,374

 

10,731

 

 

Palo Verde — Estrella 500kV System

 

50.0

%(c)

85,643

 

11,769

 

3,445

 

North Valley System

 

69.3

%(c)

95,057

 

1,757

 

3,821

 

Round Valley System

 

50.0

%(c)

570

 

320

 

 

 

(a)                                  See Note 20.

 

(b)                                 PacifiCorp owns Cholla Unit 4 and APS operates the unit for PacifiCorp.  The common facilities at Cholla are jointly-owned.

 

(c)                                  Weighted average of interests.

Commitments and Contingencies (Tables)
Summary of actual and estimated take-or-pay commitments

 

 

 

 

Actual

 

Estimated (a)

 

 

2009

 

2010

 

2011

 

2012

 

2013

 

2014

 

2015

 

2016

 

Thereafter

 

Coal take-or-pay commitments

 

$

93

 

$

66

 

$

68

 

$

79

 

$

82

 

$

86

 

$

88

 

$

58

 

$

148

 

 

(a)                                  Total take-or-pay commitments are approximately $541 million.  The total net present value of these commitments is approximately $401 million.

Asset Retirement Obligations (Tables)
Change in asset retirement obligations

 

 

 

 

2011

 

2010

 

Asset retirement obligations at the beginning of year

 

$

329

 

$

302

 

Changes attributable to:

 

 

 

 

 

Accretion expense

 

19

 

22

 

Estimated cash flow revisions

 

(68

)

5

 

Asset retirement obligations at the end of year

 

$

280

 

$

329

Selected Quarterly Financial Data (Unaudited) (Tables)

 

 

 

 

2011 Quarter Ended

 

2011

 

 

 

March 31,(a)

 

June 30,

 

Sept. 30,

 

Dec. 31,

 

Total

 

 

 

 

 

 

 

 

 

 

 

 

 

Operating revenues

 

$

648,847

 

$

799,799

 

$

1,124,841

 

$

667,892

 

$

3,241,379

 

Operations and maintenance

 

255,029

 

210,590

 

210,035

 

228,632

 

904,286

 

Operating income

 

35,784

 

196,992

 

435,017

 

78,715

 

746,508

 

Income taxes

 

(6,005

)

50,818

 

131,416

 

7,375

 

183,604

 

Income (loss) from continuing operations

 

(10,368

)

93,185

 

253,273

 

19,544

 

355,634

 

Net income (loss) attributable to common shareholders

 

(15,135

)

86,685

 

255,359

 

12,564

 

339,473

 

 

 

 

 

 

 

 

 

 

 

 

 

Earnings Per Share:

 

 

 

 

 

 

 

 

 

 

 

Income (loss) from continuing operations attributable to common shareholders - Basic

 

$

(0.15

)

$

0.79

 

$

2.25

 

$

0.11

 

$

3.01

 

Net income (loss) attributable to common shareholders - Basic

 

(0.14

)

0.80

 

2.34

 

0.12

 

3.11

 

Income (loss) from continuing operations attributable to common shareholders - Diluted

 

(0.15

)

0.78

 

2.24

 

0.11

 

2.99

 

Net income (loss) attributable to common shareholders - Diluted

 

(0.14

)

0.79

 

2.32

 

0.11

 

3.09

 

 

(a)                                  The March 31, 2011 results were adjusted for the effect of reclassifications for discontinued operations (see Note 21).  The adjustments resulted in a reduction in operating revenues of $10,728, a reduction in operations and maintenance of $1,457, a reduction in operating income of $1,357, a decrease in income taxes of $356, and a decrease in income from continuing operations of $1,043.

 

 

 

 

2010 Quarter Ended

 

2010

 

 

 

March 31,

 

June 30,

 

Sept. 30,

 

Dec. 31,

 

Total

 

 

 

 

 

 

 

 

 

 

 

 

 

As originally reported in the 2010 10-K:

 

 

 

 

 

 

 

 

 

 

 

Operating revenues

 

$

620,355

 

$

820,594

 

$

1,139,085

 

$

683,611

 

$

3,263,645

 

Operations and maintenance

 

207,842

 

215,104

 

221,469

 

232,991

 

877,406

 

Operating income

 

57,668

 

203,273

 

403,625

 

59,318

 

723,884

 

Income taxes

 

(7,172

)

51,829

 

123,486

 

(3,822

)

164,321

 

Income from continuing operations

 

11,983

 

94,584

 

231,828

 

12,203

 

350,598

 

Net income (loss) attributable to common shareholders

 

(6,014

)

114,797

 

233,920

 

7,350

 

350,053

 

 

 

 

 

 

 

 

 

 

 

 

 

Reclassification of discontinued operations (Note 21):

 

 

 

 

 

 

 

 

 

 

 

Operating revenues

 

$

(8,093

)

$

(17,799

)

$

(22,375

)

$

(26,179

)

$

(74,446

)

Operations and maintenance

 

(1,529

)

(1,495

)

(1,811

)

(2,386

)

(7,221

)

Operating income

 

(694

)

(1,889

)

(3,351

)

(3,067

)

(9,001

)

Income taxes

 

(481

)

(641

)

(1,139

)

(1,191

)

(3,452

)

Income (loss) from continuing operations

 

(292

)

(1,270

)

(2,266

)

(1,919

)

(5,747

)

 

 

 

 

 

 

 

 

 

 

 

 

After reclassifications:

 

 

 

 

 

 

 

 

 

 

 

Operating revenues

 

$

612,262

 

$

802,795

 

$

1,116,710

 

$

657,432

 

$

3,189,199

 

Operations and maintenance

 

206,313

 

213,609

 

219,658

 

230,605

 

870,185

 

Operating income

 

56,974

 

201,384

 

400,274

 

56,251

 

714,883

 

Income taxes

 

(7,653

)

51,188

 

122,347

 

(5,013

)

160,869

 

Income from continuing operations

 

11,691

 

93,314

 

229,562

 

10,284

 

344,851

 

Net income (loss) attributable to common shareholders

 

(6,014

)

114,797

 

233,920

 

7,350

 

350,053

 

 

 

 

 

 

 

 

 

 

 

 

 

Earnings Per Share:

 

 

 

 

 

 

 

 

 

 

 

As originally reported in the 2010 10-K

 

 

 

 

 

 

 

 

 

 

 

Income from continuing operations attributable to common shareholders - Basic

 

$

0.07

 

$

0.84

 

$

2.09

 

$

0.07

 

$

3.10

 

Net income (loss) attributable to common shareholders - Basic

 

(0.06

)

1.07

 

2.15

 

0.07

 

3.28

 

Income from continuing operations attributable to common shareholders - Diluted

 

0.07

 

0.83

 

2.08

 

0.06

 

3.08

 

Net income (loss) attributable to common shareholders - Diluted

 

(0.06

)

1.07

 

2.14

 

0.07

 

3.27

 

 

 

 

 

 

 

 

 

 

 

 

 

Earnings Per Share:

 

 

 

 

 

 

 

 

 

 

 

After reclassifications:

 

 

 

 

 

 

 

 

 

 

 

Income from continuing operations attributable to common shareholders - Basic

 

$

0.06

 

$

0.82

 

$

2.07

 

$

0.05

 

$

3.05

 

Net income (loss) attributable to common shareholders - Basic

 

(0.06

)

1.07

 

2.15

 

0.07

 

3.28

 

Income from continuing operations attributable to common shareholders - Diluted

 

0.06

 

0.82

 

2.06

 

0.05

 

3.03

 

Net income (loss) attributable to common shareholders - Diluted

 

(0.06

)

1.07

 

2.14

 

0.07

 

3.27

Fair Value Measurements (Tables)

 

 

The following table presents the fair value at December 31, 2011 of our assets and liabilities that are measured at fair value on a recurring basis (dollars in millions):

 

 

 

Quoted Prices
in Active
Markets for
Identical
Assets

(Level 1)

 

Significant
Other
Observable
Inputs

(Level 2)

 

Significant
Unobservable
Inputs (a)
(Level 3)

 

Other

 

Balance at
December 31,
2011

 

 

 

 

 

 

 

 

 

 

 

 

 

Assets

 

 

 

 

 

 

 

 

 

 

 

Risk management activities-derivative instruments:

 

 

 

 

 

 

 

 

 

 

 

Commodity contracts

 

$

 

$

70

 

$

74

 

$

(64

)(b)

$

80

 

Nuclear decommissioning trust:

 

 

 

 

 

 

 

 

 

 

 

U.S. commingled equity funds

 

 

175

 

 

 

175

 

Fixed income securities:

 

 

 

 

 

 

 

 

 

 

 

U.S. Treasury

 

69

 

 

 

 

69

 

Cash and cash equivalent funds

 

 

9

 

 

(1

)(c)

8

 

Corporate debt

 

 

73

 

 

 

73

 

Mortgage-backed securities

 

 

78

 

 

 

78

 

Municipality bonds

 

 

90

 

 

 

90

 

Other

 

 

21

 

 

 

21

 

Subtotal nuclear decommissioning trust

 

69

 

446

 

 

(1

)

514

 

Total

 

$

69

 

$

516

 

$

74

 

$

(65

)

$

594

 

 

 

 

 

 

 

 

 

 

 

 

 

Liabilities

 

 

 

 

 

 

 

 

 

 

 

Risk management activities - derivative instruments:

 

 

 

 

 

 

 

 

 

 

 

Commodity contracts

 

$

 

$

(241

)

$

(125

)

$

229

(b)

$

(137

)

 

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

(b)         Represents counterparty netting, margin and collateral.  See Note 18.

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

 

The following table presents the fair value at December 31, 2010 of our assets and liabilities that are measured at fair value on a recurring basis (dollars in millions):

 

 

 

Quoted Prices
in Active
Markets for
Identical
Assets

(Level 1)

 

Significant
Other
Observable
Inputs

(Level 2)

 

Significant
Unobservable
Inputs (a)
(Level 3)

 

Other

 

Balance at
December 31,
2010

 

Assets

 

 

 

 

 

 

 

 

 

 

 

Cash equivalents

 

$

35

 

$

 

$

 

$

 

$

35

 

Risk management activities-derivative instruments:

 

 

 

 

 

 

 

 

 

 

 

Commodity contracts

 

 

80

 

61

 

(28

)(b)

113

 

Nuclear decommissioning trust:

 

 

 

 

 

 

 

 

 

 

 

U.S. commingled equity funds

 

 

168

 

 

 

168

 

Fixed income securities:

 

 

 

 

 

 

 

 

 

 

 

U.S. Treasury

 

50

 

 

 

 

50

 

Cash and cash equivalent funds

 

 

22

 

 

 

22

 

Corporate debt

 

 

60

 

 

 

60

 

Mortgage-backed securities

 

 

81

 

 

 

81

 

Municipality bonds

 

 

79

 

 

 

79

 

Other

 

 

20

 

 

(10)

(c)

10

 

Subtotal nuclear decommissioning trust

 

50

 

430

 

 

(10

)

470

 

Total

 

$

85

 

$

510

 

$

61

 

$

(38

)

$

618

 

 

 

 

 

 

 

 

 

 

 

 

 

Liabilities

 

 

 

 

 

 

 

 

 

 

 

Risk management activities - derivative instruments:

 

 

 

 

 

 

 

 

 

 

 

Commodity contracts

 

$

(1

)

$

(280

)

$

(99

)

$

256

(b)

$

(124

)

 

(a)                                  Primarily consists of long-dated electricity contracts.

(b)                                 Represents counterparty netting, margin and collateral.  See Note 18.

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

 

 

 

 

Year Ended
December 31,

 

 

 

2011

 

2010

 

Net risk management activities at beginning of period

 

$

(38

)

$

(10

)

Total net gains (losses) realized/unrealized:

 

 

 

 

 

Included in earnings

 

2

 

(1

)

Included in OCI

 

(5

)

(14

)

Deferred as a regulatory asset or liability

 

(10

)

(38

)

Settlements

 

11

 

19

 

Transfers into Level 3 from Level 2

 

(4

)

5

 

Transfers from Level 3 into Level 2

 

(7

)

1

 

Net risk management activities at end of period

 

$

(51

)

$

(38

)

 

 

 

 

 

 

Net unrealized gains (losses) included in earnings related to instruments still held at end of period

 

$

1

 

$

(1

)

Earnings Per Share (Tables)
Schedule of earnings per weighted average common share outstanding

 

 

 

 

2011

 

2010

 

2009

 

Basic earnings per share:

 

 

 

 

 

 

 

Income from continuing operations attributable to common shareholders

 

$

3.01

 

$

3.05

 

$

2.34

 

Income (loss) from discontinued operations

 

0.10

 

0.23

 

(1.66

)

Earnings per share — basic

 

$

3.11

 

$

3.28

 

$

0.68

 

Diluted earnings per share:

 

 

 

 

 

 

 

Income from continuing operations attributable to common shareholders

 

$

2.99

 

$

3.03

 

$

2.34

 

Income (loss) from discontinued operations

 

0.10

 

0.24

 

(1.67

)

Earnings per share — diluted

 

$

3.09

 

$

3.27

 

$

0.67

Stock-Based Compensation (Tables)

 

 

 

 

2011

 

2010

 

2009

 

Units granted

 

292,242

 

202,341

 

261,006

 

Grant date fair value (a) 

 

$

41.98

 

$

37.47

 

$

30.25

 

 

(a) weighted average fair value

 

 

Nonvested shares

 

Shares

 

Weighted-Average
Grant-Date Fair Value

 

Nonvested at January 1, 2011

 

223,681

 

$

35.69

 

Granted

 

293,242

 

41.98

 

Vested

 

98,362

 

37.84

 

Forfeited

 

2,330

 

37.93

 

Nonvested at December 31, 2011

 

416,231

 

39.61

 

 

 

Year

 

2011

 

2010

 

2009

 

2007 Grant

 

$

1.0

 

$

0.9

 

$

0.8

 

2008 Grant

 

1.6

 

1.5

 

1.3

 

2009 Grant

 

1.5

 

1.4

 

 

2010 Grant

 

0.6

 

 

 

 

 

 

 

2011

 

2010

 

2009

 

Units granted

 

175,072

 

178,722

 

240,624

 

Grant date fair value (a)

 

$

41.71

 

$

37.57

 

$

30.19

 

 

(a)          weighted average grant date fair value

 

 

 

Nonvested shares

 

Shares

 

Weighted-Average
Grant-Date Fair Value

 

Nonvested at January 1, 2011

 

395,312

 

$

33.44

 

Granted

 

175,072

 

41.71

 

Vested

 

218,310

 

30.14

 

Forfeited

 

4,128

 

36.09

 

Nonvested at December 31, 2011

 

347,946

 

39.64

 

 

 

Options

 

Shares

 

Weighted-
Average
Exercise Price

 

Weighted-
Average
Remaining
Contractual
Term (Months)

 

Aggregate
Intrinsic
Value (dollars
in thousands)

 

Outstanding at January 1, 2011

 

82,224

 

$

39.37

 

 

 

 

 

Exercised

 

44,766

 

40.70

 

 

 

 

 

Forfeited or expired

 

14,500

 

42.55

 

 

 

 

 

Outstanding at December 31, 2011

 

22,958

 

34.75

 

11

 

$

308

 

Exercisable at December 31, 2011

 

22,958

 

34.75

 

11

 

$

308

 

Business Segments (Tables)
Financial data by business segment

 

 

 

 

Business Segments for the Year Ended
December 31, 2011

 

 

 

Regulated
Electricity
Segment

 

All other (a)

 

Total

 

Operating revenues

 

$

3,237

 

$

4

 

$

3,241

 

Fuel and purchased power costs

 

1,009

 

 

1,009

 

Other operating expenses

 

1,055

 

3

 

1,058

 

Operating margin

 

1,173

 

1

 

1,174

 

Depreciation and amortization

 

427

 

 

427

 

Interest expense

 

224

 

 

224

 

Other expense (income)

 

(19

)

3

 

(16

)

Income from continuing operations before income taxes

 

541

 

(2

)

539

 

Income taxes

 

184

 

(1

)

183

 

Income from continuing operations

 

357

 

(1

)

356

 

Income from discontinued operations — net of income tax expense of $7 million (see Note 21)

 

 

11

 

11

 

Net income

 

357

 

10

 

367

 

Less: Net income attributable to noncontrolling interests

 

28

 

 

28

 

Net income attributable to common shareholders

 

$

329

 

$

10

 

$

339

 

Total assets

 

$

13,068

 

$

43

 

$

13,111

 

Capital expenditures

 

$

885

 

$

 

$

885

 

 

 

 

Business Segments for the Year Ended
December 31, 2010

 

 

 

Regulated
Electricity
Segment

 

All other (a)

 

Total

 

Operating revenues

 

$

3,181

 

$

8

 

$

3,189

 

Fuel and purchased power costs

 

1,047

 

 

1,047

 

Other operating expenses

 

1,009

 

4

 

1,013

 

Operating margin

 

1,125

 

4

 

1,129

 

Depreciation and amortization

 

415

 

 

415

 

Interest expense

 

226

 

2

 

228

 

Other expense (income)

 

(22

)

2

 

(20

)

Income from continuing operations before income taxes

 

506

 

 

506

 

Income taxes

 

161

 

 

161

 

Income from continuing operations

 

345

 

 

345

 

Income from discontinued operations — net of income tax expense of $16 million (see Note 21)

 

 

25

 

25

 

Net income

 

345

 

25

 

370

 

Less: Net income attributable to noncontrolling interests

 

20

 

 

20

 

Net income attributable to common shareholders

 

$

325

 

$

25

 

$

350

 

Total assets

 

$

12,285

 

$

108

 

$

12,393

 

Capital expenditures

 

$

666

 

$

4

 

$

670

 

 

 

 

Business Segments for the Year Ended
December 31, 2009

 

 

 

Regulated
Electricity
Segment

 

All other (a)

 

Total

 

Operating revenues

 

$

3,149

 

$

5

 

$

3,154

 

Fuel and purchased power costs

 

1,179

 

 

1,179

 

Other operating expenses

 

948

 

4

 

952

 

Operating margin

 

1,022

 

1

 

1,023

 

Depreciation and amortization

 

407

 

 

407

 

Interest expense

 

226

 

1

 

227

 

Other expense (income)

 

(16

)

10

 

(6

)

Income (loss) from continuing operations before income taxes

 

405

 

(10

)

395

 

Income taxes

 

143

 

(4

)

139

 

Income (loss) from continuing operations

 

262

 

(6

)

256

 

Loss from discontinued operations — net of income tax benefit of $110 million (see Note 21)

 

 

(183

)

(183

)

Net income (loss)

 

262

 

(189

)

73

 

Less: Net income (loss) attributable to noncontrolling interests

 

19

 

(14

)

5

 

Net income (loss) attributable to common shareholders

 

$

243

 

$

(175

)

$

68

 

Total assets

 

$

11,740

 

$

295

 

$

12,035

 

Capital expenditures

 

$

732

 

$

13

 

$

745

 

 

(a)                                  All other activities relate to SunCor, APSES and El Dorado.  Income from discontinued operations for 2011 is primarily related to the sale of our investment in APSES.  Income from discontinued operations for 2010 is primarily related to the APSES sale of its district cooling business. Loss from discontinued operations for 2009 is primarily related to real estate impairment charges at SunCor (see Note 22).  None of these segments is a reportable business segment.

Derivative Accounting (Tables)

 

 

Commodity

 

Quantity

Power

 

11,882

 

GWh

Gas

 

118,199

 

Billion Btu

 

 

Commodity Contracts

 

Financial Statement
Location

 

Year Ended
December 31, 2011

 

Year Ended
December 31, 2010

 

 

 

 

 

 

 

 

 

Loss Recognized in AOCI (Effective Portion)

 

Accumulated other comprehensive loss-derivative instruments

 

$

(94,660

)

$

(155,287

)

 

 

 

 

 

 

 

 

Loss Reclassified from AOCI into Income (Effective Portion Realized)

 

Regulated electricity fuel and purchased power

 

(117,189

)

(122,740

)

 

 

 

 

 

 

 

 

Gain (Loss) Recognized in Income (Ineffective Portion and Amount Excluded from Effectiveness Testing) (a) 

 

Regulated electricity fuel and purchased power

 

(211

)

3,680

 

 

(a)                                  During the year ended December 31, 2011 and 2010, we had no amounts reclassified from AOCI to earnings related to discontinued cash flow hedges.

 

 

Commodity Contracts

 

Financial Statement
Location

 

Year Ended
December 31, 2011

 

Year Ended
December 31, 2010

 

 

 

 

 

 

 

 

 

Net Gain (Loss) Recognized in Income

 

Regulated electricity revenue

 

$

(27

)

$

1,436

 

 

 

 

 

 

 

 

 

Net Loss Recognized in Income

 

Regulated electricity fuel and purchased power expense

 

(52,113

)

(107,690

)

Total

 

 

 

$

(52,140

)

$

(106,254

)

 

 

The following table provides information about the fair value of our risk management activities reported on a gross basis.  Transactions with counterparties that have master netting arrangements are reported net on the balance sheet.  These amounts are located in the assets and liabilities from risk management activities lines of our Consolidated Balance Sheets.  Amounts are as of December 31, 2011 (dollars in thousands):

 

Commodity Contracts

 

Designated
as Hedging
Instruments

 

Not
Designated
as Hedging
Instruments

 

Margin and
Collateral
Provided to
Counterparties

 

Collateral
Provided from
Counterparties
(a)

 

Other (b)

 

Total

 

Current Assets

 

$

7,287

 

$

76,162

 

$

1,630

 

$

 

$

(54,815

)

$

30,264

 

Investments and Other Assets

 

3,804

 

58,273

 

 

 

(12,755

)

49,322

 

Total Assets

 

11,091

 

134,435

 

1,630

 

 

(67,570

)

79,586

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Current Liabilities

 

(82,195

)

(124,028

)

107,228

 

(11,145

)

56,172

 

(53,968

)

Deferred Credits and Other

 

(68,137

)

(92,880

)

65,768

 

 

12,754

 

(82,495

)

Total Liabilities

 

(150,332

)

(216,908

)

172,996

 

(11,145

)

68,926

 

(136,463

)

Total Derivative Instruments

 

$

(139,241

)

$

(82,473

)

$

174,626

 

$

(11,145

)

$

1,356

 

$

(56,877

)

 

(a)                                  Collateral relates to non-derivative instruments or derivative instruments that qualify for a scope exception.

(b)                                 Other represents counterparty netting, options, and other risk management contracts.

 

The following table provides information about the fair value of our risk management activities reported on a gross basis at December 31, 2010 (dollars in thousands):

 

Commodity Contracts

 

Designated
as Hedging
Instruments

 

Not
Designated
as Hedging
Instruments

 

Margin and
Collateral
Provided to
Counterparties
(a)

 

Collateral
Provided from
Counterparties
(b)

 

Other (c)

 

Total

 

Current Assets

 

$

10,295

 

$

64,153

 

$

36,135

 

$

(1,750

)

$

(35,045

)

$

73,788

 

Investments and Other Assets

 

5,056

 

60,813

 

 

 

(26,837

)

39,032

 

Total Assets

 

15,351

 

124,966

 

36,135

 

(1,750

)

(61,882

)

112,820

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Current Liabilities

 

(108,387

)

(112,847

)

126,364

 

(1,250

)

37,144

 

(58,976

)

Deferred Credits and Other

 

(73,041

)

(85,506

)

66,393

 

 

26,764

 

(65,390

)

Total Liabilities

 

(181,428

)

(198,353

)

192,757

 

(1,250

)

63,908

 

(124,366

)

Total Derivative Instruments

 

$

(166,077

)

$

(73,387

)

$

228,892

 

$

(3,000

)

$

2,026

 

$

(11,546

)

 

(a)                                  Includes $11 million of collateral relating to non-derivative instruments or derivative instruments that qualify for a scope exception.

(b)                                 Includes $1 million of collateral relating to non-derivative instruments or derivative instruments that qualify for a scope exception.

(c)                                  Other represents counterparty netting, options, and other risk management contracts.

 

 

 

 

December 31,
2011

 

Aggregate Fair Value of Derivative Instruments in a Liability Position

 

$

330

 

Cash Collateral Posted

 

147

 

Additional Cash Collateral in the Event Credit-Risk Related Contingent Features were Fully Triggered (a)

 

151

 

 

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

Other Income and Other Expense (Tables)
Detail of other income and other expense

 

 

 

 

2011

 

2010

 

2009

 

Other income:

 

 

 

 

 

 

 

Interest income

 

$

1,850

 

$

3,255

 

$

1,503

 

Investment gains — net

 

1,165

 

2,797

 

2,512

 

Miscellaneous

 

96

 

335

 

1,144

 

Total other income

 

$

3,111

 

$

6,387

 

$

5,159

 

 

 

 

 

 

 

 

 

Other expense:

 

 

 

 

 

 

 

Non-operating costs

 

$

(7,037

)

$

(6,831

)

$

(6,675

)

Miscellaneous

 

(3,414

)

(3,090

)

(7,625

)

Total other expense

 

$

(10,451

)

$

(9,921

)

$

(14,300

)

Palo Verde Sale Leaseback Variable Interest Entities (Tables)
Amounts relating to the VIEs included in Condensed Consolidated Balance Sheets

 

 

 

 

December 31,
2011

 

December 31,
2010

 

Palo Verde sale leaseback property plant and equipment, net of accumulated depreciation

 

$

133

 

$

138

 

Current maturities of long term-debt

 

31

 

29

 

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

 

66

 

97

 

Equity-Noncontrolling interests

 

108

 

91

 

Discontinued Operations (Tables)
Revenue, income (loss) before income taxes and income (loss) after taxes from discontinued operations

 

 

 

 

2011

 

2010

 

2009

 

Revenue:

 

 

 

 

 

 

 

SunCor

 

$

1

 

$

30

 

$

114

 

APSES

 

36

 

127

 

40

 

Total revenue

 

$

37

 

$

157

 

$

154

 

 

 

 

 

 

 

 

 

Income (loss) before taxes:

 

 

 

 

 

 

 

SunCor

 

$

(2

)

$

(10

)

$

(276

)

APSES

 

21

 

51

 

(3

)

Total income (loss) before taxes

 

$

19

 

$

41

 

$

(279

)

 

 

 

 

 

 

 

 

Income (loss) after taxes:

 

 

 

 

 

 

 

SunCor (a)

 

$

(1

)

$

(6

)

$

(167

)

APSES

 

12

 

31

 

(2

)

Total income (loss) after taxes

 

$

11

 

$

25

 

$

(169

)

 

(a)                                  Includes a tax benefit recognized by the parent company in accordance with an intercompany tax sharing agreement of $1 million for the year ended December 31, 2011, $4 million for the year ended December 31, 2010, and $113 million for the year ended December 31, 2009.

Real Estate Impairment Charge (Tables)
Schedule of the impairment charge before income taxes

 

 

 

 

2010

 

2009

 

Discontinued Operations:

 

 

 

 

 

Homebuilding and master-planned communities

 

$

1

 

$

170

 

Land parcels and commercial assets

 

11

 

87

 

Golf courses

 

1

 

23

 

Other

 

4

 

 

Subtotal

 

17

 

280

 

Less noncontrolling interests

 

 

(14

)

Total

 

$

17

 

$

266

 

Nuclear Decommissioning Trust (Tables)

 

 

 

 

Fair Value

 

Total
Unrealized
Gains

 

Total
Unrealized
Losses

 

2011

 

 

 

 

 

 

 

Equity securities

 

$

175

 

$

44

 

$

(1

)

Fixed income securities

 

340

 

23

 

(1

)

Net payables (a)

 

(1

)

 

 

Total

 

$

514

 

$

67

 

$

(2

)

 

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

 

 

 

Fair Value

 

Total
Unrealized
Gains

 

Total
Unrealized
Losses

 

2010

 

 

 

 

 

 

 

Equity securities

 

$

168

 

$

43

 

$

(1

)

Fixed income securities

 

312

 

12

 

(2

)

Net payables (a)

 

(10

)

 

 

Total

 

$

470

 

$

55

 

$

(3

)

 

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

 

 

 

 

 

Year Ended December 31,

 

 

 

2011

 

2010

 

2009

 

 

 

 

 

 

 

 

 

Realized gains

 

$

8

 

$

17

 

$

10

 

Realized losses

 

(5

)

(4

)

(7

)

Proceeds from the sale of securities (a)

 

498

 

560

 

441

 

 

(a)           Proceeds are reinvested in the trust.

 

 

 

 

 

Fair Value

 

Less than one year

 

$

13

 

1 year - 5 years

 

83

 

5 years - 10 years

 

114

 

Greater than 10 years

 

130

 

Total

 

$

340

 

 

Summary of Significant Accounting Policies (Details) (USD $)
In Thousands, unless otherwise specified
3 Months Ended 12 Months Ended 3 Months Ended 12 Months Ended 3 Months Ended 12 Months Ended 3 Months Ended 12 Months Ended
Dec. 31, 2011
Sep. 30, 2011
Jun. 30, 2011
Mar. 31, 2011
Dec. 31, 2011
Dec. 31, 2010
Dec. 31, 2009
Dec. 31, 2010
As previously reported
Sep. 30, 2010
As previously reported
Jun. 30, 2010
As previously reported
Mar. 31, 2010
As previously reported
Dec. 31, 2010
As previously reported
Dec. 31, 2009
As previously reported
Dec. 31, 2010
Restatements
Sep. 30, 2010
Restatements
Jun. 30, 2010
Restatements
Mar. 31, 2010
Restatements
Dec. 31, 2010
Restatements
Dec. 31, 2009
Restatements
Dec. 31, 2010
Amount reported after reclassification
Sep. 30, 2010
Amount reported after reclassification
Jun. 30, 2010
Amount reported after reclassification
Mar. 31, 2010
Amount reported after reclassification
Dec. 31, 2010
Amount reported after reclassification
Dec. 31, 2009
Amount reported after reclassification
Operating Revenues
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Other revenues
 
 
 
 
$ 4,185 
$ 8,521 
$ 4,469 
 
 
 
 
$ 82,967 
$ 26,723 
 
 
 
 
$ (74,446)
$ (22,254)
 
 
 
 
$ 8,521 
$ 4,469 
Operating Expenses
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Operations and maintenance
228,632 
210,035 
210,590 
255,029 
904,286 
870,185 
822,300 
232,991 
221,469 
215,104 
207,842 
877,406 
831,863 
(2,386)
(1,811)
(1,495)
(1,529)
(7,221)
(9,563)
230,605 
219,658 
213,609 
206,313 
870,185 
822,300 
Depreciation and amortization
 
 
 
 
427,054 
414,479 
407,354 
 
 
 
 
414,555 
407,463 
 
 
 
 
(76)
(109)
 
 
 
 
414,479 
407,354 
Taxes other than income taxes
 
 
 
 
147,408 
135,328 
123,270 
 
 
 
 
135,334 
123,277 
 
 
 
 
(6)
(7)
 
 
 
 
135,328 
123,270 
Other expenses
 
 
 
 
6,659 
7,509 
5,984 
 
 
 
 
65,651 
24,534 
 
 
 
 
(58,142)
(18,550)
 
 
 
 
7,509 
5,984 
Other
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Other income
 
 
 
 
3,111 
6,387 
5,159 
 
 
 
 
6,368 
5,278 
 
 
 
 
19 
(119)
 
 
 
 
6,387 
5,159 
Other expense (Note 19)
 
 
 
 
(10,451)
(9,921)
(14,300)
 
 
 
 
(9,764)
(14,269)
 
 
 
 
(157)
(31)
 
 
 
 
(9,921)
(14,300)
Interest Expense
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Interest charges
 
 
 
 
241,995 
244,174 
237,766 
 
 
 
 
 
237,527 
 
 
 
 
 
239 
 
 
 
 
 
237,766 
Allowance for borrowed funds used during construction
 
 
 
 
(18,358)
(16,479)
(10,379)
 
 
 
 
(16,539)
(10,430)
 
 
 
 
60 
51 
 
 
 
 
(16,479)
(10,379)
Income Taxes
7,375 
131,416 
50,818 
(6,005)
183,604 
160,869 
138,551 
(3,822)
123,486 
51,829 
(7,172)
164,321 
136,506 
(1,191)
(1,139)
(641)
(481)
(3,452)
2,045 
(5,013)
122,347 
51,188 
(7,653)
160,869 
138,551 
Income From Continuing Operations
19,544 
253,273 
93,185 
(10,368)
355,634 
344,851 
256,048 
12,203 
231,828 
94,584 
11,983 
350,598 
252,558 
(1,919)
(2,266)
(1,270)
(292)
(5,747)
3,490 
10,284 
229,562 
93,314 
11,691 
344,851 
256,048 
Income From Discontinued Operations
 
 
 
 
11,306 
25,358 
(183,284)
 
 
 
 
19,611 
(179,794)
 
 
 
 
5,747 
(3,490)
 
 
 
 
25,358 
(183,284)
Balance Sheets
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Current Assets - Other regulatory assets
69,072 
 
 
 
69,072 
62,286 
 
 
 
 
 
 
 
62,286 
 
 
 
62,286 
 
62,286 
 
 
 
62,286 
 
Current Assets - Deferred income taxes
130,571 
 
 
 
130,571 
124,897 
 
94,602 
 
 
 
94,602 
 
30,295 
 
 
 
30,295 
 
124,897 
 
 
 
124,897 
 
Deferred Debits - Regulatory assets
1,352,079 
 
 
 
1,352,079 
986,370 
 
1,048,656 
 
 
 
1,048,656 
 
(62,286)
 
 
 
(62,286)
 
986,370 
 
 
 
986,370 
 
Current Liabilities - Deferred fuel and purchased power regulatory liability
 
 
 
 
 
58,442 
 
 
 
 
 
 
 
58,442 
 
 
 
58,442 
 
58,442 
 
 
 
58,442 
 
Current Liabilities - Other regulatory liabilities
88,362 
 
 
 
88,362 
80,526 
 
 
 
 
 
 
 
80,526 
 
 
 
80,526 
 
80,526 
 
 
 
80,526 
 
Deferred Credits and Other - Deferred income taxes
1,925,388 
 
 
 
1,925,388 
1,863,861 
 
1,833,566 
 
 
 
1,833,566 
 
30,295 
 
 
 
30,295 
 
1,863,861 
 
 
 
1,863,861 
 
Deferred Credits and Other - Deferred fuel and purchased power regulatory liability
 
 
 
 
 
 
 
58,442 
 
 
 
58,442 
 
(58,442)
 
 
 
(58,442)
 
 
 
 
 
 
 
Deferred Credits and Other - Regulatory liabilities
737,332 
 
 
 
737,332 
614,063 
 
694,589 
 
 
 
694,589 
 
(80,526)
 
 
 
(80,526)
 
614,063 
 
 
 
614,063 
 
Cash Flows from Operating Activities
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Other current assets
 
 
 
 
(3,079)
9,375 
38,406 
 
 
 
 
5,246 
24,647 
 
 
 
 
4,129 
13,759 
 
 
 
 
9,375 
38,406 
Other current liabilities
 
 
 
 
20,358 
2,921 
57,280 
 
 
 
 
5,204 
29,274 
 
 
 
 
(2,283)
28,006 
 
 
 
 
2,921 
57,280 
Change in other regulatory liabilities
 
 
 
62,000 
37,009 
56,801 
82,650 
 
 
 
 
54,518 
110,642 
 
 
 
 
2,283 
(27,992)
 
 
 
 
56,801 
82,650 
Change in other long-term assets
 
 
 
 
(41,722)
(47,940)
(64,629)
 
 
 
 
(43,189)
(47,899)
 
 
 
 
(4,751)
(16,730)
 
 
 
 
(47,940)
(64,629)
Expenditures for real estate investments
 
 
 
 
 
 
 
 
 
 
 
(622)
(2,957)
 
 
 
 
622 
2,957 
 
 
 
 
 
 
Other changes in real estate assets
 
 
 
 
 
 
 
 
 
 
 
4,068 
(4,216)
 
 
 
 
(4,068)
4,216 
 
 
 
 
 
 
Change in other long-term liabilities
 
 
 
 
$ 58,484 
$ (97,388)
$ 12,161 
 
 
 
 
$ (101,456)
$ 16,337 
 
 
 
 
$ 4,068 
$ (4,216)
 
 
 
 
$ (97,388)
$ 12,161 
Summary of Significant Accounting Policies (Details 2) (USD $)
In Millions, unless otherwise specified
12 Months Ended 12 Months Ended 36 Months Ended 12 Months Ended 36 Months Ended 12 Months Ended
Dec. 31, 2011
Y
Dec. 31, 2010
Dec. 31, 2009
Dec. 31, 2011
ARIZONA PUBLIC SERVICE COMPANY
USDPerkWh
trust
Apr. 21, 2011
ARIZONA PUBLIC SERVICE COMPANY
Y
Dec. 31, 2008
ARIZONA PUBLIC SERVICE COMPANY
Y
trust
Dec. 31, 2011
Minimum
Dec. 31, 2011
Minimum
Dec. 31, 2011
Maximum
M
Dec. 31, 2011
Maximum
Dec. 31, 2011
Fossil plant
Y
Dec. 31, 2011
Nuclear plant
Y
Dec. 31, 2011
Other generation
Y
Dec. 31, 2011
Transmission
Y
Dec. 31, 2011
Distribution
Y
Dec. 31, 2011
Other:
Y
Approximate remaining average useful lives of utility property
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Average useful life (in years)
 
 
 
 
 
 
 
 
 
 
18 
29 
28 
38 
35 
Extension period of operating licenses for each of the three Palo Verde units (in years)
 
 
 
 
20 
20 
 
 
 
 
 
 
 
 
 
 
Number of VIE lessor trusts
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Depreciation rates (as a percent)
2.98% 
2.98% 
3.06% 
 
 
 
 
1.30% 
 
10.20% 
 
 
 
 
 
 
Allowance for Funds Used During Construction
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Composite rate used to calculate AFUDC (as a percent)
10.25% 
9.20% 
5.90% 
 
 
 
 
 
 
 
 
 
 
 
 
 
Nuclear Fuel
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Charges for the permanent disposal of spent nuclear fuel (in dollars per kWh)
 
 
 
0.001 
 
 
 
 
 
 
 
 
 
 
 
 
Income Taxes
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Percentage of likelihood of realization of recognized tax benefit
 
 
 
 
 
 
50.00% 
 
 
 
 
 
 
 
 
 
Cash and Cash Equivalents
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Maturity period of highly liquid investments for classification as cash equivalents (in months)
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Intangible Assets
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Amortization expense
$ 47 
$ 45 
$ 35 
 
 
 
 
 
 
 
 
 
 
 
 
 
Estimated amortization expense on existing intangible assets over the next five years
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
2012
42 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
2013
35 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
2014
28 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
2015
21 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
2016
$ 13 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Weighted average remaining amortization period for intangible assets (in years)
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Investments
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Ownership percentage for classification as cost method investments by El Dorado
 
 
 
 
 
 
 
 
20.00% 
 
 
 
 
 
 
 
Regulatory Matters (Details) (USD $)
12 Months Ended 1 Months Ended 6 Months Ended 12 Months Ended 1 Months Ended 1 Months Ended 12 Months Ended 1 Months Ended 1 Months Ended 12 Months Ended 1 Months Ended 1 Months Ended 6 Months Ended 1 Months Ended
Dec. 31, 2011
Dec. 31, 2010
Dec. 31, 2009
Jun. 30, 2011
ARIZONA PUBLIC SERVICE COMPANY
Jun. 30, 2010
ARIZONA PUBLIC SERVICE COMPANY
Dec. 31, 2011
ARIZONA PUBLIC SERVICE COMPANY
Dec. 31, 2010
ARIZONA PUBLIC SERVICE COMPANY
Dec. 31, 2009
ARIZONA PUBLIC SERVICE COMPANY
Dec. 31, 2011
ARIZONA PUBLIC SERVICE COMPANY
ACC
2012 RES
USDPerWatt
Dec. 14, 2011
ARIZONA PUBLIC SERVICE COMPANY
ACC
2012 RES
MW
Dec. 31, 2011
ARIZONA PUBLIC SERVICE COMPANY
ACC
2012 RES
Maximum
USDPerWatt
Jul. 31, 2011
ARIZONA PUBLIC SERVICE COMPANY
ACC
2012 RES
Maximum
Dec. 31, 2011
ARIZONA PUBLIC SERVICE COMPANY
ACC
2012 RES
Minimum
USDPerWatt
Jul. 31, 2011
ARIZONA PUBLIC SERVICE COMPANY
ACC
2012 RES
Minimum
Mar. 31, 2010
ARIZONA PUBLIC SERVICE COMPANY
ACC
2010 DSMAC
Y
Feb. 28, 2011
ARIZONA PUBLIC SERVICE COMPANY
ACC
2011 DSMAC
Dec. 31, 2011
ARIZONA PUBLIC SERVICE COMPANY
ACC
2011 DSMAC
Feb. 17, 2011
ARIZONA PUBLIC SERVICE COMPANY
ACC
2011 DSMAC
Jun. 2, 2010
ARIZONA PUBLIC SERVICE COMPANY
ACC
2011 DSMAC
Jun. 30, 2011
ARIZONA PUBLIC SERVICE COMPANY
ACC
2012 DSMAC
Jun. 2, 2011
ARIZONA PUBLIC SERVICE COMPANY
ACC
2012 DSMAC
Feb. 28, 2012
ARIZONA PUBLIC SERVICE COMPANY
ACC
Power Supply Adjustor (PSA)
USDPerkWh
Dec. 31, 2011
ARIZONA PUBLIC SERVICE COMPANY
ACC
Power Supply Adjustor (PSA)
USDPerkWh
Dec. 31, 2010
ARIZONA PUBLIC SERVICE COMPANY
ACC
Power Supply Adjustor (PSA)
Jan. 31, 2012
ARIZONA PUBLIC SERVICE COMPANY
ACC
2011 General retail rate case
Jun. 30, 2011
ARIZONA PUBLIC SERVICE COMPANY
ACC
2011 General retail rate case
USDPerkWh
Jan. 6, 2012
ARIZONA PUBLIC SERVICE COMPANY
ACC
2011 General retail rate case
Jun. 2, 2011
ARIZONA PUBLIC SERVICE COMPANY
ACC
2011 General retail rate case
Jan. 31, 2012
ARIZONA PUBLIC SERVICE COMPANY
ACC
2011 General retail rate case
Proposed
USDPerkWh
Jan. 31, 2012
ARIZONA PUBLIC SERVICE COMPANY
ACC
2011 General retail rate case
Current
USDPerkWh
Dec. 31, 2009
ARIZONA PUBLIC SERVICE COMPANY
ACC
2008 General retail rate case
Jun. 30, 2010
ARIZONA PUBLIC SERVICE COMPANY
ACC
2008 General retail rate case
Dec. 30, 2009
ARIZONA PUBLIC SERVICE COMPANY
ACC
2008 General retail rate case
party
Jun. 30, 2011
ARIZONA PUBLIC SERVICE COMPANY
FERC
Transmission Rates and Transmission Cost Adjustor
Regulatory Matters
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Net retail rate increase
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
$ 95,500,000 
 
 
 
 
 
 
 
 
Approximate percentage of increase in the average retail customer bill
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
6.60% 
 
 
 
 
 
 
 
 
Non-fuel base rate increase
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
194,100,000 
 
 
 
 
 
 
 
 
Reclassification of revenues to base rates
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
44,900,000 
 
 
 
 
 
 
 
 
Base rate decrease
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
143,500,000 
 
 
 
 
 
 
 
 
Rate base
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
5,700,000,000 
 
 
 
 
 
 
 
 
Proposed capital structure and costs of capital
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Percentage of long-term debt in capital structure
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
46.10% 
 
 
 
 
 
 
Percentage of common stock equity in capital structure
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
53.90% 
 
 
 
 
 
 
Cost of capital, long-term debt (as a percent)
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
6.38% 
 
 
 
 
 
 
Cost of capital, common stock equity (as a percent)
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
11.00% 
 
 
 
 
 
 
Weighted-average cost of capital (as a percent)
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
8.87% 
 
 
 
 
 
 
Proposed base fuel rate (in dollars per kWh)
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
0.03242 
 
 
 
 
 
 
 
 
Current base fuel rate (in dollars per kWh)
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
0.03757 
 
 
 
0.03757 
 
 
 
 
Current sharing provision of fuel and purchased power costs
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
90/10 
 
 
 
 
 
 
 
 
Settlement Agreement
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Net change in base rates
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Non-fuel base rate increase
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
116,300,000 
 
 
 
 
 
 
 
 
 
Fuel-related base rate decrease
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
153,100,000 
 
 
 
 
 
 
 
 
 
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% 
 
 
 
 
 
11.00% 
 
Percentage of debt in capital structure
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
46.10% 
 
 
 
 
 
46.20% 
 
Percentage of common equity in capital structure
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
53.90% 
 
 
 
 
 
53.80% 
 
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 current sharing provision of fuel and purchased power costs
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
90/10 
 
 
 
 
 
 
 
 
 
Approved Settlement
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Number of other parties to the settlement agreement
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
21 
 
Net retail rate increase
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
207,500,000 
 
 
 
Base rate increase
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
344,700,000 
 
 
 
Reclassification of fuel and purchased power revenues from the then-existing PSA to base rates
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
137,200,000 
 
 
 
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
 
 
 
252,833,000 
252,833,000 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
253,000,000 
 
 
Funding request
 
 
 
 
 
 
 
 
 
 
 
152,000,000 
 
129,000,000 
 
 
79,000,000 
 
 
90,000,000 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Funding approval as per budget authorized
 
 
 
 
 
 
 
 
110,000,000 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Additional capacity from APS-owned AZ Sun projects (in MW)
 
 
 
 
 
 
 
 
 
100 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Total capacity from APS-owned AZ Sun projects (in MW)
 
 
 
 
 
 
 
 
 
200 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Second additional solar capacity for which revenue requirements were authorized to be recovered
 
 
 
 
 
 
 
 
 
100 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Costs associated with program to be recovered through base rates or other mechanisms or next retail rate base (in MW)
 
 
 
 
 
 
 
 
 
100 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Additional capacity from APS-owned facilities on schools and government facilities (in MW)
 
 
 
 
 
 
 
 
 
6.25 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Initial upfront incentive per watt of solar capacity (in dollars per watt)
 
 
 
 
 
 
 
 
0.75 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Amount of solar capacity for residential incentives for next fiscal year
 
 
 
 
 
 
 
 
 
 
0.20 
 
0.10 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Additional capacity of renewable generation to be described later and installed in 2014 and 2015 (in MW)
 
 
 
 
 
 
 
 
 
25 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Period covered by cost recovery program (in years)
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Period over which program costs will be amortized (in years)
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Percentage of energy savings for prior year
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
1.75% 
 
 
 
 
 
 
 
 
 
 
 
 
 
Percentage of annual energy savings to meet energy efficiency goal for 2011
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
1.25% 
 
1.50% 
 
 
 
 
 
 
 
 
 
 
 
 
 
Amount of approved budget
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
80,000,000 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Costs already being recovered in general rates
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
10,000,000 
 
 
 
10,000,000 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Demand-side management adjustor charge (DSMAC)
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
75,000,000 
 
 
 
85,000,000 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Deferral of the difference between retail fuel and purchased power costs and the Base Fuel Rate (as a percent)
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
90.00% 
 
 
 
 
 
 
 
 
 
 
 
Absorption of the retail fuel and purchased power costs above the Base Fuel Rate (as a percent)
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
10.00% 
 
 
 
 
 
 
 
 
 
 
 
Retention of the benefit from the retail fuel and purchased power costs that are below the Base Fuel Rate (as a percent)
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
10.00% 
 
 
 
 
 
 
 
 
 
 
 
Maximum increase or decrease in PSA rate without permission of the ACC (in dollars per kWh)
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
0.004 
 
 
 
 
 
 
 
 
 
 
 
Increase in annual wholesale transmission rates
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
44,000,000 
Revenue increase related to transmission services used for APS's retail customers
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
38,000,000 
Changes in the deferred fuel and purchased power regulatory asset (liability)
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Beginning balance
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
(58,000,000)
(87,000,000)
 
 
 
 
 
 
 
 
 
 
Deferred fuel and purchased power costs-current period
69,166,000 
93,631,000 
(51,742,000)
 
 
69,166,000 
93,631,000 
(51,742,000)
 
 
 
 
 
 
 
 
 
 
 
 
 
 
(69,000,000)
(93,000,000)
 
 
 
 
 
 
 
 
 
 
Amounts refunded through revenues
(155,157,000)
(122,481,000)
147,018,000 
 
 
(155,157,000)
(122,481,000)
147,018,000 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
155,000,000 
122,000,000 
 
 
 
 
 
 
 
 
 
 
Ending balance
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
$ 28,000,000 
$ (58,000,000)
 
 
 
 
 
 
 
 
 
 
PSA rate (in dollars per kWh)
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
(0.0042)
 
 
 
 
 
 
 
 
 
 
 
 
PSA rate for prior year (in dollars per kWh)
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
(0.0057)
 
 
 
 
 
 
 
 
 
 
 
 
Regulatory Matters (Details 2) (USD $)
Dec. 31, 2011
Dec. 31, 2010
Detail of regulatory assets
 
 
Regulatory assets, current
$ 97,000,000 
$ 62,000,000 
Regulatory assets, non-current
1,352,079,000 
986,370,000 
Pension and other postretirement benefits
 
 
Detail of regulatory assets
 
 
Regulatory assets, non-current
1,023,000,000 
669,000,000 
Income taxes - AFUDC equity
 
 
Detail of regulatory assets
 
 
Regulatory assets, current
3,000,000 
3,000,000 
Regulatory assets, non-current
81,000,000 
69,000,000 
Deferred Fuel and Purchased Power MTM Costs
 
 
Detail of regulatory assets
 
 
Regulatory assets, current
43,000,000 
42,000,000 
Regulatory assets, non-current
34,000,000 
35,000,000 
Transmission vegetation management
 
 
Detail of regulatory assets
 
 
Regulatory assets, current
9,000,000 
 
Regulatory assets, non-current
32,000,000 
46,000,000 
Coal reclamation
 
 
Detail of regulatory assets
 
 
Regulatory assets, current
2,000,000 
2,000,000 
Regulatory assets, non-current
35,000,000 
36,000,000 
Consolidation of VIEs
 
 
Detail of regulatory assets
 
 
Regulatory assets, non-current
35,000,000 
33,000,000 
Deferred compensation
 
 
Detail of regulatory assets
 
 
Regulatory assets, non-current
33,000,000 
32,000,000 
Deferred Fuel and Purchased Power Costs
 
 
Detail of regulatory assets
 
 
Regulatory assets, current
28,000,000 
 
Income taxes - Medicare subsidy
 
 
Detail of regulatory assets
 
 
Regulatory assets, current
2,000,000 
2,000,000 
Regulatory assets, non-current
18,000,000 
21,000,000 
Loss on reacquired debt
 
 
Detail of regulatory assets
 
 
Regulatory assets, current
1,000,000 
1,000,000 
Regulatory assets, non-current
19,000,000 
21,000,000 
Income taxes - investment tax credit basis adjustment
 
 
Detail of regulatory assets
 
 
Regulatory assets, non-current
15,000,000 
 
Pension and other postretirement benefits deferral
 
 
Detail of regulatory assets
 
 
Regulatory assets, non-current
12,000,000 
 
Demand side management
 
 
Detail of regulatory assets
 
 
Regulatory assets, current
7,000,000 
12,000,000 
Regulatory assets, non-current
1,000,000 
6,000,000 
Other.
 
 
Detail of regulatory assets
 
 
Regulatory assets, current
2,000,000 
 
Regulatory assets, non-current
$ 14,000,000 
$ 18,000,000 
Regulatory Matters (Details 3) (USD $)
Dec. 31, 2011
Dec. 31, 2010
Detail of regulatory liabilities
 
 
Regulatory liabilities, current
$ 88,000,000 
$ 139,000,000 
Regulatory liabilities, non-current
737,332,000 
614,063,000 
Removal costs
 
 
Detail of regulatory liabilities
 
 
Regulatory liabilities, current
22,000,000 
22,000,000 
Regulatory liabilities, non-current
349,000,000 
357,000,000 
Asset retirement obligations
 
 
Detail of regulatory liabilities
 
 
Regulatory liabilities, non-current
225,000,000 
184,000,000 
Renewable energy standard
 
 
Detail of regulatory liabilities
 
 
Regulatory liabilities, current
54,000,000 
50,000,000 
Income taxes - change in rates
 
 
Detail of regulatory liabilities
 
 
Regulatory liabilities, non-current
59,000,000 
 
Spent nuclear fuel
 
 
Detail of regulatory liabilities
 
 
Regulatory liabilities, current
5,000,000 
4,000,000 
Regulatory liabilities, non-current
44,000,000 
41,000,000 
Deferred gains on utility property
 
 
Detail of regulatory liabilities
 
 
Regulatory liabilities, current
2,000,000 
2,000,000 
Regulatory liabilities, non-current
14,000,000 
16,000,000 
Income taxes - unamortized investment tax credit
 
 
Detail of regulatory liabilities
 
 
Regulatory liabilities, current
1,000,000 
 
Regulatory liabilities, non-current
30,000,000 
1,000,000 
Deferred Fuel and Purchased Power Costs
 
 
Detail of regulatory liabilities
 
 
Regulatory liabilities, current
 
58,000,000 
Other
 
 
Detail of regulatory liabilities
 
 
Regulatory liabilities, current
4,000,000 
3,000,000 
Regulatory liabilities, non-current
$ 16,000,000 
$ 15,000,000 
Income Taxes (Details) (USD $)
3 Months Ended 12 Months Ended
Mar. 31, 2010
Sep. 30, 2009
M
Dec. 31, 2011
Dec. 31, 2010
Dec. 31, 2009
Income Taxes
 
 
 
 
 
Income tax receivables, long-term portion
 
$ 69,000,000 
$ 68,633,000 
$ 65,103,000 
 
Period over which the cash refunds are not expected to be received (in months)
 
12 
 
 
 
Settlements with taxing authorities
62,000,000 
 
124,000 
62,199,000 
4,089,000 
Net decrease in uncertain tax positions which decreased our effective tax rate
3,000,000 
 
 
 
 
Net interest benefits through the effective tax rate
4,000,000 
 
 
 
 
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
201,216,000 
 
127,595,000 
201,216,000 
63,318,000 
Additions for tax positions of the current year
 
 
10,915,000 
7,551,000 
44,094,000 
Additions for tax positions of prior years
 
 
 
 
98,942,000 
Reductions for tax positions of prior years for:
 
 
 
 
 
Changes in judgment
 
 
(1,555,000)
(11,017,000)
 
Settlements with taxing authorities
(62,000,000)
 
(124,000)
(62,199,000)
(4,089,000)
Lapses of applicable statute of limitations
 
 
(826,000)
(7,956,000)
(1,049,000)
Total unrecognized tax benefits at the end of the year
 
 
136,005,000 
127,595,000 
201,216,000 
Unrecognized tax benefits if recognized, would decrease effective tax rate
 
 
8,000,000 
7,000,000 
16,000,000 
Pre-tax interest expense (benefit) related to unrecognized tax benefits
 
 
3,000,000 
(2,000,000)
2,000,000 
Accrued liabilities for interest related to unrecognized tax benefits
 
 
9,000,000 
6,000,000 
8,000,000 
Interest income to be received on the overpayment of income taxes for certain adjustments that we have filed, or will file, with the IRS
 
 
$ 4,000,000 
 
 
Income Taxes (Details 2) (USD $)
In Thousands, unless otherwise specified
3 Months Ended 12 Months Ended
Dec. 31, 2011
Sep. 30, 2011
Jun. 30, 2011
Mar. 31, 2011
Dec. 31, 2011
Dec. 31, 2010
Dec. 31, 2009
Current:
 
 
 
 
 
 
 
Federal
 
 
 
 
$ (310)
$ (108,827)
$ (38,502)
State
 
 
 
 
15,140 
25,545 
(38,080)
Total current
 
 
 
 
14,830 
(83,282)
(76,582)
Deferred:
 
 
 
 
 
 
 
Federal
 
 
 
 
159,566 
260,236 
62,874 
State
 
 
 
 
16,626 
10,911 
42,618 
Discontinued operations
 
 
 
 
 
(10,736)
 
Total deferred
 
 
 
 
176,192 
260,411 
105,492 
Total income tax expense
 
 
 
 
191,022 
177,129 
28,910 
Less: income tax expense (benefit) on discontinued operations
 
 
 
 
7,418 
16,260 
(109,641)
Income tax expense - continuing operations
$ 7,375 
$ 131,416 
$ 50,818 
$ (6,005)
$ 183,604 
$ 160,869 
$ 138,551 
Income Taxes (Details 3) (USD $)
1 Months Ended 3 Months Ended 12 Months Ended
Feb. 28, 2011
Y
Dec. 31, 2011
Sep. 30, 2011
Jun. 30, 2011
Mar. 31, 2011
Mar. 31, 2010
Dec. 31, 2011
Dec. 31, 2010
Dec. 31, 2009
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% 
35.00% 
35.00% 
Federal income tax expense at 35% statutory rate
 
 
 
 
 
 
$ 188,733,000 
$ 177,002,000 
$ 138,110,000 
Increases (reductions) in tax expense resulting from:
 
 
 
 
 
 
 
 
 
State income tax net of federal income tax benefit
 
 
 
 
 
 
19,594,000 
17,485,000 
15,068,000 
Credits and favorable adjustments related to prior years resolved in current year
 
 
 
 
 
 
 
(17,300,000)
 
Medicare Subsidy Part-D
 
 
 
 
 
 
823,000 
1,311,000 
(2,095,000)
Allowance for equity funds used during construction
 
 
 
 
 
 
(6,881,000)
(6,563,000)
(4,265,000)
Palo Verde VIE noncontrolling interest
 
 
 
 
 
 
(9,636,000)
(7,057,000)
(6,723,000)
Other
 
 
 
 
 
 
(9,029,000)
(4,009,000)
(1,544,000)
Income tax expense - continuing operations
 
7,375,000 
131,416,000 
50,818,000 
(6,005,000)
 
183,604,000 
160,869,000 
138,551,000 
Net deferred income tax liability recognized on the Consolidated Balance Sheets
 
 
 
 
 
 
 
 
 
Current asset
 
130,571,000 
 
 
 
 
130,571,000 
124,897,000 
 
Long-term liability
 
(1,925,388,000)
 
 
 
 
(1,925,388,000)
(1,863,861,000)
 
Deferred income taxes - net
 
(1,794,817,000)
 
 
 
 
(1,794,817,000)
(1,738,964,000)
 
Income Taxes, additional disclosures
 
 
 
 
 
 
 
 
 
Phase-in period of corporate income tax rate reductions beginning in 2014 (in years)
 
 
 
 
 
 
 
 
Decrease in deferred income tax liabilities
 
 
 
 
(62,000,000)
42,000,000 
 
 
 
Change in regulatory liabilities
 
 
 
 
$ 62,000,000 
 
$ 37,009,000 
$ 56,801,000 
$ 82,650,000 
Income Taxes (Details 4) (USD $)
Dec. 31, 2011
Dec. 31, 2010
DEFERRED TAX ASSETS
 
 
Risk management activities
$ 117,765,000 
$ 124,731,000 
Regulatory liabilities:
 
 
Asset retirement obligation and removal costs
236,739,000 
222,448,000 
Deferred fuel and purchased power
 
23,089,000 
Renewable energy standard
19,722,000 
18,749,000 
Unamortized investment tax credits
31,460,000 
642,000 
Other
33,155,000 
27,718,000 
Pension and other postretirement liabilities
501,202,000 
321,182,000 
Real estate investments and assets held for sale
 
19,855,000 
Renewable energy incentives
57,901,000 
37,327,000 
Credit and loss carryforwards
171,915,000 
42,971,000 
Other
73,759,000 
68,684,000 
Total deferred tax assets
1,243,618,000 
907,396,000 
DEFERRED TAX LIABILITIES
 
 
Plant-related
(2,446,908,000)
(2,210,976,000)
Risk management activities
(30,171,000)
(30,125,000)
Regulatory assets:
 
 
Allowance for equity funds used during construction
(33,347,000)
(28,276,000)
Deferred fuel and purchased power
(10,884,000)
 
Deferred fuel and purchased power - mark-to-market
(30,559,000)
(30,276,000)
Pension and other postretirement benefits
(408,716,000)
(264,313,000)
Other
(73,087,000)
(77,078,000)
Other
(4,763,000)
(5,316,000)
Total deferred tax liabilities
(3,038,435,000)
(2,646,360,000)
Deferred income taxes - net
(1,794,817,000)
(1,738,964,000)
Amount of federal general business credits carryforwards which begin to expire in 2029
67,000,000 
 
Amount of federal net operating losses carryforwards which begin to expire in 2029
92,000,000 
 
Amount of federal and state loss carryforwards which begin to expire in 2014
$ 13,000,000 
 
Lines of Credit and Short-Term Borrowings (Details) (USD $)
12 Months Ended 12 Months Ended 12 Months Ended 12 Months Ended 12 Months Ended 12 Months Ended
Dec. 31, 2011
Dec. 31, 2010
Dec. 31, 2010
Pinnacle West
Dec. 31, 2011
Pinnacle West
Long term debt
Dec. 31, 2010
Pinnacle West
Revolving credit facility maturing in 2013
Dec. 31, 2011
Pinnacle West
Revolving credit facility maturing in 2013
Nov. 4, 2011
Pinnacle West
Revolving credit facility maturing in 2013
Feb. 12, 2010
Pinnacle West
Revolving credit facility maturing in 2013
Dec. 31, 2011
Pinnacle West
Revolving credit facility maturing in 2016
Nov. 4, 2011
Pinnacle West
Revolving credit facility maturing in 2016
Dec. 31, 2011
Pinnacle West
Commercial Paper
Dec. 31, 2010
Pinnacle West
Commercial Paper
Feb. 12, 2010
Pinnacle West
Revolving credit facility maturing in 2010
Dec. 31, 2011
ARIZONA PUBLIC SERVICE COMPANY
ACC
Nov. 22, 2011
ARIZONA PUBLIC SERVICE COMPANY
ACC
Oct. 30, 2007
ARIZONA PUBLIC SERVICE COMPANY
ACC
Dec. 31, 2011
ARIZONA PUBLIC SERVICE COMPANY
Long term debt
Dec. 31, 2010
ARIZONA PUBLIC SERVICE COMPANY
Revolving credit facility maturing in 2013
Nov. 4, 2011
ARIZONA PUBLIC SERVICE COMPANY
Revolving credit facility maturing in 2013
Feb. 12, 2010
ARIZONA PUBLIC SERVICE COMPANY
Revolving credit facility maturing in 2013
Dec. 31, 2011
ARIZONA PUBLIC SERVICE COMPANY
Revolving credit facility maturing in 2016
Nov. 4, 2011
ARIZONA PUBLIC SERVICE COMPANY
Revolving credit facility maturing in 2016
Dec. 31, 2011
ARIZONA PUBLIC SERVICE COMPANY
Revolving credit facility maturing in 2015
Feb. 14, 2011
ARIZONA PUBLIC SERVICE COMPANY
Revolving credit facility maturing in 2015
Dec. 31, 2010
ARIZONA PUBLIC SERVICE COMPANY
Line of Credit Maturing in 2011
Feb. 14, 2011
ARIZONA PUBLIC SERVICE COMPANY
Line of Credit Maturing in 2011
Feb. 12, 2010
ARIZONA PUBLIC SERVICE COMPANY
Revolving credit facility maturing in 2010
Lines of Credit and Short-Term Borrowings
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Amount Committed
$ 1,200,000,000 
$ 1,189,000,000 
 
 
$ 200,000,000 
 
$ 200,000,000 
$ 200,000,000 
$ 200,000,000 
$ 200,000,000 
$ 200,000,000 
 
$ 283,000,000 
 
 
 
 
$ 500,000,000 
$ 500,000,000 
$ 500,000,000 
$ 500,000,000 
$ 500,000,000 
$ 500,000,000 
$ 500,000,000 
$ 489,000,000 
$ 489,000,000 
$ 377,000,000 
Letters of Credit Used
 
20,000,000 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
20,000,000 
 
 
Short-Term Borrowings
 
16,600,000 
16,600,000 
 
 
 
 
 
 
 
 
17,000,000 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Unused Amount
1,200,000,000 
1,152,000,000 
 
 
183,000,000 
 
 
 
200,000,000 
 
 
 
 
 
 
 
 
500,000,000 
 
 
500,000,000 
 
500,000,000 
 
469,000,000 
 
 
Weighted Average Interest Rate (as a percent)
 
 
 
 
 
 
 
 
 
 
 
0.84% 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Commitment Fees (as a percent)
 
 
 
 
0.625% 
 
 
 
0.275% 
 
 
 
 
 
 
 
 
0.50% 
 
 
0.225% 
 
0.25% 
 
0.10% 
 
 
Maximum commercial paper support available under credit facility
 
 
 
200,000,000 
 
 
 
 
 
 
 
 
 
 
 
 
250,000,000 
 
 
 
 
 
 
 
 
 
 
Maximum borrowing capacity on credit facility upon satisfaction of certain conditions and consent of lenders
 
 
 
 
 
300,000,000 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
700,000,000 
 
700,000,000 
 
 
 
 
Debt Provisions
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Short-term debt authorization as a percentage of APS's capitalization before increase
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
7.00% 
 
 
 
 
 
 
 
 
 
 
 
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
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
3,200,000,000 
 
 
 
 
 
 
 
 
 
 
 
Long-term debt authorization
 
 
 
 
 
 
 
 
 
 
 
 
 
4,200,000,000 
 
 
 
 
 
 
 
 
 
 
 
 
 
Long-term debt authorization requested in a financing application
 
 
 
 
 
 
 
 
 
 
 
 
 
 
$ 5,500,000,000 
 
 
 
 
 
 
 
 
 
 
 
 
Long-Term Debt and Liquidity Matters (Details) (USD $)
12 Months Ended 12 Months Ended 12 Months Ended 1 Months Ended 1 Months Ended 1 Months Ended 3 Months Ended
Dec. 31, 2011
Dec. 31, 2010
Dec. 31, 2011
Maximum
Dec. 31, 2011
Pinnacle West
Dec. 31, 2010
Pinnacle West
Dec. 31, 2011
ARIZONA PUBLIC SERVICE COMPANY
Dec. 31, 2010
ARIZONA PUBLIC SERVICE COMPANY
Dec. 31, 2011
ARIZONA PUBLIC SERVICE COMPANY
ACC
Dec. 31, 2011
ARIZONA PUBLIC SERVICE COMPANY
ACC
Minimum
Dec. 31, 2011
Pollution Control Bonds - Variable
ARIZONA PUBLIC SERVICE COMPANY
Dec. 31, 2010
Pollution Control Bonds - Variable
ARIZONA PUBLIC SERVICE COMPANY
Dec. 31, 2011
Pollution Control Bonds - Fixed
ARIZONA PUBLIC SERVICE COMPANY
Dec. 31, 2010
Pollution Control Bonds - Fixed
ARIZONA PUBLIC SERVICE COMPANY
Dec. 31, 2011
Pollution control bonds with senior notes
ARIZONA PUBLIC SERVICE COMPANY
Dec. 31, 2010
Pollution control bonds with senior notes
ARIZONA PUBLIC SERVICE COMPANY
Dec. 31, 2011
Total Pollution Control Bonds
ARIZONA PUBLIC SERVICE COMPANY
Dec. 31, 2010
Total Pollution Control Bonds
ARIZONA PUBLIC SERVICE COMPANY
Dec. 31, 2011
Senior unsecured notes
ARIZONA PUBLIC SERVICE COMPANY
Dec. 31, 2010
Senior unsecured notes
ARIZONA PUBLIC SERVICE COMPANY
Dec. 31, 2011
Palo Verde sale leaseback lessor notes
ARIZONA PUBLIC SERVICE COMPANY
Dec. 31, 2010
Palo Verde sale leaseback lessor notes
ARIZONA PUBLIC SERVICE COMPANY
Dec. 31, 2011
Capitalized lease obligations
ARIZONA PUBLIC SERVICE COMPANY
Dec. 31, 2010
Capitalized lease obligations
ARIZONA PUBLIC SERVICE COMPANY
Dec. 31, 2011
Term loan facility
Pinnacle West
Feb. 28, 2011
Term loan facility
Pinnacle West
Feb. 28, 2011
5.91% Senior Notes
Pinnacle West
Dec. 31, 2010
5.91% Senior Notes
Pinnacle West
Dec. 8, 2011
Long term debt
ARIZONA PUBLIC SERVICE COMPANY
Aug. 31, 2011
5.05% unsecured senior notes due 2041
ARIZONA PUBLIC SERVICE COMPANY
Dec. 31, 2011
5.05% unsecured senior notes due 2041
ARIZONA PUBLIC SERVICE COMPANY
Aug. 25, 2011
5.05% unsecured senior notes due 2041
ARIZONA PUBLIC SERVICE COMPANY
Aug. 25, 2011
6.375% senior notes due 2011
ARIZONA PUBLIC SERVICE COMPANY
Sep. 7, 2011
Pollution Control Revenue Refunding Bonds
ARIZONA PUBLIC SERVICE COMPANY
Jan. 31, 2012
4.50% unsecured senior notes that mature on April 1, 2042
ARIZONA PUBLIC SERVICE COMPANY
Jan. 10, 2012
4.50% unsecured senior notes that mature on April 1, 2042
ARIZONA PUBLIC SERVICE COMPANY
Mar. 31, 2012
6.50% senior notes due March 1, 2012
ARIZONA PUBLIC SERVICE COMPANY
Long-Term Debt and Liquidity Matters
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Long-term debt before deducting unamortized discount
 
 
 
$ 3,504,000,000 
 
$ 3,379,000,000 
 
 
 
$ 43,580,000 
$ 43,580,000 
$ 522,275,000 
$ 522,275,000 
$ 90,000,000 
$ 90,000,000 
$ 655,855,000 
$ 655,855,000 
$ 2,625,000,000 
$ 2,725,000,000 
 
 
$ 1,029,000 
$ 2,001,000 
 
 
 
 
 
 
 
 
 
 
 
 
 
Palo Verde sale leaseback lessor notes long-term debt excluding current maturities
65,547,000 
96,803,000 
 
 
 
65,547,000 
96,803,000 
 
 
 
 
 
 
 
 
 
 
 
 
96,803,000 
126,000,000 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Unamortized discount
 
 
 
 
 
(7,198,000)
(6,183,000)
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Long-term debt
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
125,000,000 
175,000,000 
 
 
 
 
 
 
 
 
 
 
 
Long-term debt
3,496,000,000 
3,678,000,000 
 
125,000,000 
175,000,000 
3,371,489,000 
3,502,673,000 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
175,000,000 
 
 
 
 
 
 
 
 
 
Long-term debt less current maturities (Note 6)
2,953,507,000 
2,948,991,000 
 
 
 
2,828,507,000 
2,948,991,000 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Less current maturities
477,435,000 
631,879,000 
 
 
175,000,000 
477,435,000 
456,879,000 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Interest rate (as a percent)
 
 
 
 
 
 
 
 
 
 
 
 
 
5.05% 
5.05% 
 
 
 
 
8.00% 
8.00% 
 
 
 
 
 
5.91% 
 
 
5.05% 
5.05% 
6.375% 
 
 
4.50% 
6.50% 
Total long-term debt less current maturities
3,019,054,000 
3,045,794,000 
 
125,000,000 
 
2,894,054,000 
3,045,794,000 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Interest Rates, low end of range (as a percent)
 
 
 
 
 
 
 
 
 
 
 
2.875% 
2.875% 
 
 
 
 
4.65% 
4.65% 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Interest Rates, high end of range (as a percent)
 
 
 
 
 
 
 
 
 
 
 
6.00% 
6.00% 
 
 
 
 
8.75% 
8.75% 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Weighted-average interest rate (as a percent)
 
 
 
 
 
 
 
 
 
0.09% 
0.32% 
 
 
 
 
 
 
 
 
 
 
5.27% 
5.29% 
1.794% 
 
 
 
 
 
 
 
 
 
 
 
 
Estimated fair value of long-term debt, including current maturities
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Carrying Amount
3,496,000,000 
3,678,000,000 
 
125,000,000 
175,000,000 
3,371,489,000 
3,502,673,000 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
175,000,000 
 
 
 
 
 
 
 
 
 
Fair Value
3,926,000,000 
3,913,000,000 
 
123,000,000 
176,000,000 
3,803,000,000 
3,737,000,000 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Repayment of debt
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
50,000,000 
 
175,000,000 
 
 
 
 
 
 
 
 
 
375,000,000 
Notes issued
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
300,000,000 
 
 
 
 
325,000,000 
 
 
Aggregate principal amount
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
400,000,000 
27,000,000 
 
 
 
Extended amount of letter of credit
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
17,000,000 
 
 
 
 
 
 
 
 
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% 
 
46.00% 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
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
3,821,850,000 
3,683,327,000 
 
3,821,850,000 
3,683,327,000 
3,943,007,000 
3,824,953,000 
3,900,000,000 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Total capitalization
 
 
 
 
 
 
 
7,200,000,000 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Dividend restrictions, shareholder equity required
 
 
 
 
 
 
 
 
$ 2,900,000,000 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Long-Term Debt and Liquidity Matters (Details 2) (USD $)
Dec. 31, 2011
ARIZONA PUBLIC SERVICE COMPANY
 
Principal payments due on long-term debt and capitalized lease requirements
 
2012
$ 477,000,000 
2013
123,000,000 
2014
502,000,000 
2015
313,000,000 
2016
358,000,000 
Thereafter
1,606,000,000 
Total
3,379,000,000 
Pinnacle West
 
Principal payments due on long-term debt and capitalized lease requirements
 
2012
477,000,000 
2013
123,000,000 
2014
502,000,000 
2015
438,000,000 
2016
358,000,000 
Thereafter
1,606,000,000 
Total
$ 3,504,000,000 
Common Stock and Treasury Stock (Details) (USD $)
12 Months Ended 1 Months Ended 12 Months Ended 12 Months Ended 12 Months Ended
Dec. 31, 2011
Dec. 31, 2010
Apr. 30, 2010
Pinnacle West
Dec. 31, 2011
Pinnacle West
Dec. 31, 2010
Pinnacle West
Apr. 10, 2010
Pinnacle West
Dec. 31, 2009
ARIZONA PUBLIC SERVICE COMPANY
Dec. 31, 2011
ARIZONA PUBLIC SERVICE COMPANY
Dec. 31, 2010
ARIZONA PUBLIC SERVICE COMPANY
Dec. 31, 2011
Common Stock
Dec. 31, 2010
Common Stock
Dec. 31, 2009
Common Stock
Dec. 31, 2011
Common Stock
ARIZONA PUBLIC SERVICE COMPANY
Dec. 31, 2010
Common Stock
ARIZONA PUBLIC SERVICE COMPANY
Dec. 31, 2009
Common Stock
ARIZONA PUBLIC SERVICE COMPANY
Dec. 31, 2008
Common Stock
ARIZONA PUBLIC SERVICE COMPANY
Dec. 31, 2011
Treasury Stock
Dec. 31, 2010
Treasury Stock
Dec. 31, 2009
Treasury Stock
Dec. 31, 2011
Serial preferred stock
Pinnacle West
Balance
$ 3,775,226,000 
$ 3,428,004,000 
 
$ 3,930,586,000 
$ 3,775,226,000 
 
 
$ 4,051,406,000 
$ 3,916,037,000 
$ 2,421,372,000 
$ 2,153,295,000 
$ 2,151,323,000 
$ 178,162,000 
$ 178,162,000 
$ 178,162,000 
$ 178,162,000 
$ (2,239,000)
$ (3,812,000)
$ (2,854,000)
 
Balance at the beginning of the period (in shares)
108,820,067 
 
 
 
 
 
 
 
 
108,820,067 
101,527,937 
100,948,436 
 
 
 
 
(50,410)
(93,239)
(59,827)
 
Common stock issuance
 
 
 
 
 
 
 
 
 
11,057,000 
263,297,000 
10,620,000 
 
 
 
 
 
 
 
 
Common stock issuance (in shares)
108,820,067 
6,900,000 
 
 
 
 
 
 
249,602 
7,172,405 
354,995 
 
 
 
 
 
 
 
 
Purchase of treasury stock
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
(3,720,000)
(82,000)
(2,156,000)
 
Purchase of treasury stock (in shares)
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
(88,440)
(1,994)
(66,173)
 
Reissuance of treasury stock for stock compensation
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
1,242,000 
1,655,000 
1,198,000 
 
Reissuance of treasury stock for stock compensation (in shares)
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
27,689 
44,823 
32,761 
 
Other
 
 
 
 
 
 
9,074,000 
 
 
11,818,000 
4,780,000 
(8,648,000)
 
 
 
 
 
 
 
 
Other (in shares)
 
 
 
 
 
 
 
 
 
287,305 
119,725 
224,506 
 
 
 
 
 
 
 
 
Balance
3,930,586,000 
3,775,226,000 
 
3,930,586,000 
3,775,226,000 
 
3,527,679,000 
4,051,406,000 
3,916,037,000 
2,444,247,000 
2,421,372,000 
2,153,295,000 
178,162,000 
178,162,000 
178,162,000 
178,162,000 
(4,717,000)
(2,239,000)
(3,812,000)
 
Balance at the end of the period (in shares)
109,356,974 
108,820,067 
 
 
 
 
 
 
 
109,356,974 
108,820,067 
101,527,937 
 
 
 
 
(111,161)
(50,410)
(93,239)
 
Common stock issued (in shares)
108,820,067 
6,900,000 
 
 
 
 
 
 
249,602 
7,172,405 
354,995 
 
 
 
 
 
 
 
 
Offering price of common stock issued (in dollars per share)
 
 
 
 
 
$ 38.00 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Net proceeds from issuance of common stock
 
 
$ 253,000,000 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Serial preferred stock authorized
 
 
 
 
 
 
 
15,535,000 
 
 
 
 
 
 
 
 
 
 
 
10,000,000 
Par value of preferred stock authorized (in dollars per share)
 
 
 
 
 
 
$ 100 
$ 25 
$ 50 
 
 
 
 
 
 
 
 
 
 
 
Retirement Plans and Other Benefits (Details) (USD $)
3 Months Ended 12 Months Ended 3 Months Ended 12 Months Ended
Mar. 31, 2011
Mar. 31, 2010
Dec. 31, 2011
Dec. 31, 2010
Mar. 31, 2011
ARIZONA PUBLIC SERVICE COMPANY
Dec. 31, 2011
ARIZONA PUBLIC SERVICE COMPANY
Dec. 31, 2010
ARIZONA PUBLIC SERVICE COMPANY
Dec. 31, 2011
Pension Benefits
Dec. 31, 2010
Pension Benefits
Dec. 31, 2009
Pension Benefits
Dec. 31, 2010
Pension Benefits
ARIZONA PUBLIC SERVICE COMPANY
Dec. 31, 2011
Other Benefits
Dec. 31, 2010
Other Benefits
Dec. 31, 2009
Other Benefits
Dec. 31, 2011
Other Benefits
ARIZONA PUBLIC SERVICE COMPANY
Dec. 31, 2010
Other Benefits
ARIZONA PUBLIC SERVICE COMPANY
Dec. 31, 2009
Other Benefits
ARIZONA PUBLIC SERVICE COMPANY
Retirement Plans and Other Benefits
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Change in regulatory assets
 
$ 42,000,000 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Increase in accumulated deferred income tax liabilities
(62,000,000)
42,000,000 
 
 
(62,000,000)
 
 
 
 
 
 
 
 
 
 
 
 
Amount of pension and other postretirement benefit costs deferred
 
 
12,000,000 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Net periodic benefit costs and the portion of these costs charged to expense
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Service cost - benefits earned during the period
 
 
 
 
 
 
 
57,605,000 
59,064,000 
54,288,000 
 
21,856,000 
19,236,000 
18,285,000 
 
 
 
Interest cost on benefit obligation
 
 
 
 
 
 
 
124,727,000 
122,724,000 
118,282,000 
 
46,807,000 
42,428,000 
39,180,000 
 
 
 
Expected return on plan assets
 
 
 
 
 
 
 
(133,678,000)
(124,161,000)
(116,535,000)
 
(41,536,000)
(39,257,000)
(34,428,000)
 
 
 
Amortization of transition obligation
 
 
 
 
 
 
 
 
 
 
 
452,000 
452,000 
3,005,000 
 
 
 
Amortization of prior service cost (credit)
 
 
 
 
 
 
 
1,400,000 
1,705,000 
2,080,000 
 
(179,000)
(539,000)
(125,000)
 
 
 
Amortization of net actuarial loss
 
 
 
 
 
 
 
25,956,000 
18,833,000 
14,216,000 
 
15,015,000 
10,317,000 
10,320,000 
 
 
 
Net periodic benefit cost
 
 
 
 
 
 
 
76,010,000 
78,165,000 
72,331,000 
 
42,415,000 
32,637,000 
36,237,000 
 
 
 
Portion of cost charged to expense
 
 
 
 
 
 
 
29,312,000 
37,933,000 
36,484,000 
 
15,208,000 
15,839,000 
18,278,000 
 
 
 
Change in Benefit Obligation
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Benefit obligation at the beginning of the period
 
 
 
 
 
 
 
2,345,060,000 
2,074,131,000 
 
 
827,897,000 
700,535,000 
 
 
 
 
Service cost
 
 
 
 
 
 
 
57,605,000 
59,064,000 
54,288,000 
 
21,856,000 
19,236,000 
18,285,000 
 
 
 
Interest cost
 
 
 
 
 
 
 
124,727,000 
122,724,000 
118,282,000 
 
46,807,000 
42,428,000 
39,180,000 
 
 
 
Benefit payments
 
 
 
 
 
 
 
(104,257,000)
(93,776,000)
 
 
(24,877,000)
(20,421,000)
 
 
 
 
Actuarial loss
 
 
 
 
 
 
 
275,991,000 
183,365,000 
 
 
171,674,000 
98,094,000 
 
 
 
 
Plan amendments
 
 
 
 
 
 
 
 
(448,000)
 
 
3,737,000 
(11,975,000)
 
 
 
 
Benefit obligation at the end of the period
 
 
 
 
 
 
 
2,699,126,000 
2,345,060,000 
2,074,131,000 
 
1,047,094,000 
827,897,000 
700,535,000 
 
 
 
Change in Plan Assets
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Fair value of plan assets at the beginning of the period
 
 
 
 
 
 
 
1,775,596,000 
1,461,808,000 
 
 
567,410,000 
490,455,000 
 
 
 
 
Actual return on plan assets
 
 
 
 
 
 
 
162,042,000 
190,380,000 
 
 
58,367,000 
60,255,000 
 
 
 
 
Employer contributions
 
 
 
 
 
 
 
 
200,000,000 
 
195,000,000 
18,769,000 
16,700,000 
 
19,000,000 
16,000,000 
15,000,000 
Benefit payments
 
 
 
 
 
 
 
(87,088,000)
(76,592,000)
 
 
(35,883,000)
 
 
 
 
 
Fair value of plan assets at the end of the period
 
 
 
 
 
 
 
1,850,550,000 
1,775,596,000 
1,461,808,000 
 
608,663,000 
567,410,000 
490,455,000 
 
 
 
Funded Status at the end of the period
 
 
 
 
 
 
 
(848,576,000)
(569,464,000)
 
 
(438,431,000)
(260,487,000)
 
 
 
 
Projected benefit obligation and the accumulated benefit obligation for pension plans with an accumulated obligation in excess of plan assets
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Projected benefit obligation
 
 
 
 
 
 
 
2,699,126,000 
2,345,060,000 
 
 
 
 
 
 
 
 
Accumulated benefit obligation
 
 
 
 
 
 
 
2,396,575,000 
2,065,091,000 
 
 
 
 
 
 
 
 
Fair value of plan assets
 
 
 
 
 
 
 
1,850,550,000 
1,775,596,000 
 
 
 
 
 
 
 
 
Amounts recognized on the Consolidated Balance Sheets
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Current liability
 
 
 
 
 
 
 
(18,097,000)
(16,830,000)
 
 
 
 
 
 
 
 
Noncurrent liability
 
 
(1,268,910,000)
(813,121,000)
 
(1,222,542,000)
(770,611,000)
(830,479,000)
(552,634,000)
 
 
(438,431,000)
(260,487,000)
 
 
 
 
Net amount recognized
 
 
 
 
 
 
 
$ (848,576,000)
$ (569,464,000)
 
 
$ (438,431,000)
$ (260,487,000)
 
 
 
 
Retirement Plans and Other Benefits (Details 2) (USD $)
12 Months Ended
Dec. 31, 2011
Y
Dec. 31, 2010
Y
Dec. 31, 2009
Y
Details related to accumulated other comprehensive loss
 
 
 
Accumulated other comprehensive loss
$ 65,447,000 
$ 59,420,000 
 
Weighted-average assumptions used to determine benefit obligations
 
 
 
Rate of compensation increase (as a percent)
4.00% 
4.00% 
 
Initial health care cost trend rate (as a percent)
7.50% 
8.00% 
 
Ultimate health care cost trend rate (as a percent)
5.00% 
5.00% 
5.00% 
Number of years to ultimate trend rate
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 (as a percent)
7.75% 
8.25% 
8.25% 
Expected long-term return on plan assets for next fiscal year (as a percent)
7.75% 
 
 
Initial health care cost trend rate (as a percent)
8.00% 
8.00% 
8.00% 
Ultimate health care cost trend rate (as a percent)
5.00% 
5.00% 
5.00% 
Number of years to ultimate trend rate
ARIZONA PUBLIC SERVICE COMPANY
 
 
 
Details related to accumulated other comprehensive loss
 
 
 
Accumulated other comprehensive loss
38,886,000 
35,961,000 
 
Pension Benefits
 
 
 
Details related to accumulated other comprehensive loss
 
 
 
Net actuarial loss
724,605,000 
502,938,000 
 
Prior service cost (credit)
4,312,000 
5,712,000 
 
APS's portion recorded as a regulatory asset
(632,099,000)
(419,774,000)
 
Income tax benefit
(38,243,000)
(35,106,000)
 
Accumulated other comprehensive loss
58,575,000 
53,770,000 
 
Estimated amounts that will be amortized from accumulated other comprehensive loss and regulatory assets into net periodic benefit cost in 2012
 
 
 
Net actuarial loss
43,070,000 
 
 
Prior service cost (credit)
1,143,000 
 
 
Total amounts estimated to be amortized from accumulated other comprehensive loss and regulatory assets in 2012
44,213,000 
 
 
Weighted-average assumptions used to determine benefit obligations
 
 
 
Discount rate (as a percent)
4.42% 
5.31% 
 
Weighted-average assumptions used to determine net periodic benefit costs
 
 
 
Discount rate (as a percent)
5.31% 
5.90% 
6.11% 
Other Benefits
 
 
 
Details related to accumulated other comprehensive loss
 
 
 
Net actuarial loss
400,892,000 
261,071,000 
 
Prior service cost (credit)
(655,000)
(4,571,000)
 
Transition obligation
452,000 
903,000 
 
APS's portion recorded as a regulatory asset
(390,521,000)
(249,255,000)
 
Income tax benefit
(3,296,000)
(2,498,000)
 
Accumulated other comprehensive loss
6,872,000 
5,650,000 
 
Estimated amounts that will be amortized from accumulated other comprehensive loss and regulatory assets into net periodic benefit cost in 2012
 
 
 
Net actuarial loss
23,638,000 
 
 
Prior service cost (credit)
(179,000)
 
 
Transition obligation
452,000 
 
 
Total amounts estimated to be amortized from accumulated other comprehensive loss and regulatory assets in 2012
23,911,000 
 
 
Weighted-average assumptions used to determine benefit obligations
 
 
 
Discount rate (as a percent)
4.59% 
5.49% 
 
Weighted-average assumptions used to determine net periodic benefit costs
 
 
 
Discount rate (as a percent)
5.49% 
6.00% 
6.13% 
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
11,000,000 
 
 
Effect of 1% decrease on other postretirement benefits expense, after consideration of amounts capitalized or billed to electric plant participants
(9,000,000)
 
 
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
187,000,000 
 
 
Effect of 1% decrease on the accumulated other postretirement benefit obligation
$ (148,000,000)
 
 
Retirement Plans and Other Benefits (Details 3) (USD $)
In Thousands, unless otherwise specified
12 Months Ended
Dec. 31, 2011
U.S. Companies, Equities
Dec. 31, 2011
International Companies, Equities
Dec. 31, 2011
Other investments, Equities
Dec. 31, 2011
Pension Benefits
Dec. 31, 2010
Pension Benefits
Dec. 31, 2009
Pension Benefits
Dec. 31, 2011
Pension Benefits
Pinnacle West
Dec. 31, 2010
Pension Benefits
Pinnacle West
Dec. 31, 2011
Pension Benefits
Quoted Prices in Active Markets for Identical Assets (Level 1)
Pinnacle West
Dec. 31, 2010
Pension Benefits
Quoted Prices in Active Markets for Identical Assets (Level 1)
Pinnacle West
Dec. 31, 2011
Pension Benefits
Significant Other Observable Inputs (Level 2)
Pinnacle West
Dec. 31, 2010
Pension Benefits
Significant Other Observable Inputs (Level 2)
Pinnacle West
Dec. 31, 2011
Pension Benefits
Counterparty Netting and Other
Pinnacle West
Dec. 31, 2010
Pension Benefits
Counterparty Netting and Other
Pinnacle West
Dec. 31, 2011
Pension Benefits
Fixed income securities.
Dec. 31, 2011
Pension Benefits
Return-generating assets
Dec. 31, 2011
Pension Benefits
Cash and cash equivalent funds
Pinnacle West
Dec. 31, 2010
Pension Benefits
Cash and cash equivalent funds
Pinnacle West
Dec. 31, 2011
Pension Benefits
Cash and cash equivalent funds
Quoted Prices in Active Markets for Identical Assets (Level 1)
Pinnacle West
Dec. 31, 2010
Pension Benefits
Cash and cash equivalent funds
Quoted Prices in Active Markets for Identical Assets (Level 1)
Pinnacle West
Dec. 31, 2011
Pension Benefits
Corporate debt
Pinnacle West
Dec. 31, 2010
Pension Benefits
Corporate debt
Pinnacle West
Dec. 31, 2011
Pension Benefits
Corporate debt
Significant Other Observable Inputs (Level 2)
Pinnacle West
Dec. 31, 2010
Pension Benefits
Corporate debt
Significant Other Observable Inputs (Level 2)
Pinnacle West
Dec. 31, 2011
Pension Benefits
U.S. Treasury
Pinnacle West
Dec. 31, 2010
Pension Benefits
U.S. Treasury
Pinnacle West
Dec. 31, 2011
Pension Benefits
U.S. Treasury
Quoted Prices in Active Markets for Identical Assets (Level 1)
Pinnacle West
Dec. 31, 2010
Pension Benefits
U.S. Treasury
Quoted Prices in Active Markets for Identical Assets (Level 1)
Pinnacle West
Dec. 31, 2011
Pension Benefits
Other
Pinnacle West
Dec. 31, 2010
Pension Benefits
Other
Pinnacle West
Dec. 31, 2011
Pension Benefits
Other
Significant Other Observable Inputs (Level 2)
Pinnacle West
Dec. 31, 2010
Pension Benefits
Other
Significant Other Observable Inputs (Level 2)
Pinnacle West
Dec. 31, 2011
Pension Benefits
U.S. Companies, Equities
Pinnacle West
Dec. 31, 2010
Pension Benefits
U.S. Companies, Equities
Pinnacle West
Dec. 31, 2011
Pension Benefits
U.S. Companies, Equities
Quoted Prices in Active Markets for Identical Assets (Level 1)
Pinnacle West
Dec. 31, 2010
Pension Benefits
U.S. Companies, Equities
Quoted Prices in Active Markets for Identical Assets (Level 1)
Pinnacle West
Dec. 31, 2011
Pension Benefits
International Companies, Equities
Pinnacle West
Dec. 31, 2010
Pension Benefits
International Companies, Equities
Pinnacle West
Dec. 31, 2011
Pension Benefits
International Companies, Equities
Quoted Prices in Active Markets for Identical Assets (Level 1)
Pinnacle West
Dec. 31, 2010
Pension Benefits
International Companies, Equities
Quoted Prices in Active Markets for Identical Assets (Level 1)
Pinnacle West
Dec. 31, 2010
Pension Benefits
Other investments, Equities
Pinnacle West
Dec. 31, 2010
Pension Benefits
Other investments, Equities
Significant Other Observable Inputs (Level 2)
Pinnacle West
Dec. 31, 2010
Pension Benefits
Other investments, Equities
Counterparty Netting and Other
Pinnacle West
Dec. 31, 2011
Pension Benefits
U.S. Equities
Pinnacle West
Dec. 31, 2010
Pension Benefits
U.S. Equities
Pinnacle West
Dec. 31, 2011
Pension Benefits
U.S. Equities
Significant Other Observable Inputs (Level 2)
Pinnacle West
Dec. 31, 2010
Pension Benefits
U.S. Equities
Significant Other Observable Inputs (Level 2)
Pinnacle West
Dec. 31, 2011
Pension Benefits
International Equities
Pinnacle West
Dec. 31, 2010
Pension Benefits
International Equities
Pinnacle West
Dec. 31, 2011
Pension Benefits
International Equities
Significant Other Observable Inputs (Level 2)
Pinnacle West
Dec. 31, 2010
Pension Benefits
International Equities
Significant Other Observable Inputs (Level 2)
Pinnacle West
Dec. 31, 2011
Pension Benefits
Real estate
Pinnacle West
Dec. 31, 2010
Pension Benefits
Real estate
Pinnacle West
Dec. 31, 2011
Pension Benefits
Real estate
Significant Other Observable Inputs (Level 2)
Pinnacle West
Dec. 31, 2010
Pension Benefits
Real estate
Significant Other Observable Inputs (Level 2)
Pinnacle West
Dec. 31, 2009
Pension Benefits
Real estate
Significant Unobservable Inputs (Level 3)
Pinnacle West
Dec. 31, 2011
Pension Benefits
Short-term investments and other
Pinnacle West
Dec. 31, 2011
Pension Benefits
Short-term investments and other
Significant Other Observable Inputs (Level 2)
Pinnacle West
Dec. 31, 2011
Pension Benefits
Short-term investments and other
Counterparty Netting and Other
Pinnacle West
Dec. 31, 2010
Pension Benefits
Short-term investments
Pinnacle West
Dec. 31, 2010
Pension Benefits
Short-term investments
Significant Other Observable Inputs (Level 2)
Pinnacle West
Dec. 31, 2011
Other Benefits
Dec. 31, 2010
Other Benefits
Dec. 31, 2009
Other Benefits
Dec. 31, 2011
Other Benefits
Pinnacle West
Dec. 31, 2010
Other Benefits
Pinnacle West
Dec. 31, 2011
Other Benefits
Quoted Prices in Active Markets for Identical Assets (Level 1)
Pinnacle West
Dec. 31, 2010
Other Benefits
Quoted Prices in Active Markets for Identical Assets (Level 1)
Pinnacle West
Dec. 31, 2011
Other Benefits
Significant Other Observable Inputs (Level 2)
Pinnacle West
Dec. 31, 2010
Other Benefits
Significant Other Observable Inputs (Level 2)
Pinnacle West
Dec. 31, 2011
Other Benefits
Counterparty Netting and Other
Pinnacle West
Dec. 31, 2010
Other Benefits
Counterparty Netting and Other
Pinnacle West
Dec. 31, 2011
Other Benefits
Fixed income securities.
Dec. 31, 2011
Other Benefits
Return-generating assets
Dec. 31, 2011
Other Benefits
Cash and cash equivalent funds
Pinnacle West
Dec. 31, 2010
Other Benefits
Cash and cash equivalent funds
Pinnacle West
Dec. 31, 2011
Other Benefits
Cash and cash equivalent funds
Quoted Prices in Active Markets for Identical Assets (Level 1)
Pinnacle West
Dec. 31, 2010
Other Benefits
Cash and cash equivalent funds
Quoted Prices in Active Markets for Identical Assets (Level 1)
Pinnacle West
Dec. 31, 2011
Other Benefits
Corporate debt
Pinnacle West
Dec. 31, 2010
Other Benefits
Corporate debt
Pinnacle West
Dec. 31, 2011
Other Benefits
Corporate debt
Significant Other Observable Inputs (Level 2)
Pinnacle West
Dec. 31, 2010
Other Benefits
Corporate debt
Significant Other Observable Inputs (Level 2)
Pinnacle West
Dec. 31, 2011
Other Benefits
U.S. Treasury
Pinnacle West
Dec. 31, 2010
Other Benefits
U.S. Treasury
Pinnacle West
Dec. 31, 2011
Other Benefits
U.S. Treasury
Quoted Prices in Active Markets for Identical Assets (Level 1)
Pinnacle West
Dec. 31, 2010
Other Benefits
U.S. Treasury
Quoted Prices in Active Markets for Identical Assets (Level 1)
Pinnacle West
Dec. 31, 2011
Other Benefits
Other
Pinnacle West
Dec. 31, 2010
Other Benefits
Other
Pinnacle West
Dec. 31, 2011
Other Benefits
Other
Significant Other Observable Inputs (Level 2)
Pinnacle West
Dec. 31, 2010
Other Benefits
Other
Significant Other Observable Inputs (Level 2)
Pinnacle West
Dec. 31, 2011
Other Benefits
U.S. Companies, Equities
Pinnacle West
Dec. 31, 2010
Other Benefits
U.S. Companies, Equities
Pinnacle West
Dec. 31, 2011
Other Benefits
U.S. Companies, Equities
Quoted Prices in Active Markets for Identical Assets (Level 1)
Pinnacle West
Dec. 31, 2010
Other Benefits
U.S. Companies, Equities
Quoted Prices in Active Markets for Identical Assets (Level 1)
Pinnacle West
Dec. 31, 2011
Other Benefits
International Companies, Equities
Pinnacle West
Dec. 31, 2010
Other Benefits
International Companies, Equities
Pinnacle West
Dec. 31, 2011
Other Benefits
International Companies, Equities
Quoted Prices in Active Markets for Identical Assets (Level 1)
Pinnacle West
Dec. 31, 2010
Other Benefits
International Companies, Equities
Quoted Prices in Active Markets for Identical Assets (Level 1)
Pinnacle West
Dec. 31, 2010
Other Benefits
Other investments, Equities
Pinnacle West
Dec. 31, 2010
Other Benefits
Other investments, Equities
Significant Other Observable Inputs (Level 2)
Pinnacle West
Dec. 31, 2010
Other Benefits
Other investments, Equities
Counterparty Netting and Other
Pinnacle West
Dec. 31, 2011
Other Benefits
U.S. Equities
Pinnacle West
Dec. 31, 2010
Other Benefits
U.S. Equities
Pinnacle West
Dec. 31, 2011
Other Benefits
U.S. Equities
Significant Other Observable Inputs (Level 2)
Pinnacle West
Dec. 31, 2010
Other Benefits
U.S. Equities
Significant Other Observable Inputs (Level 2)
Pinnacle West
Dec. 31, 2011
Other Benefits
International Equities
Pinnacle West
Dec. 31, 2010
Other Benefits
International Equities
Pinnacle West
Dec. 31, 2011
Other Benefits
International Equities
Significant Other Observable Inputs (Level 2)
Pinnacle West
Dec. 31, 2010
Other Benefits
International Equities
Significant Other Observable Inputs (Level 2)
Pinnacle West
Dec. 31, 2011
Other Benefits
Real estate
Pinnacle West
Dec. 31, 2010
Other Benefits
Real estate
Pinnacle West
Dec. 31, 2011
Other Benefits
Real estate
Significant Other Observable Inputs (Level 2)
Pinnacle West
Dec. 31, 2010
Other Benefits
Real estate
Significant Other Observable Inputs (Level 2)
Pinnacle West
Dec. 31, 2009
Other Benefits
Real estate
Significant Unobservable Inputs (Level 3)
Pinnacle West
Dec. 31, 2011
Other Benefits
Short-term investments and other
Pinnacle West
Dec. 31, 2011
Other Benefits
Short-term investments and other
Significant Other Observable Inputs (Level 2)
Pinnacle West
Dec. 31, 2011
Other Benefits
Short-term investments and other
Counterparty Netting and Other
Pinnacle West
Dec. 31, 2010
Other Benefits
Short-term investments
Pinnacle West
Dec. 31, 2010
Other Benefits
Short-term investments
Significant Other Observable Inputs (Level 2)
Pinnacle West
Retirement Plans and Other Benefits
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Actual asset allocation (as a percent)
 
 
 
 
 
 
 
 
 
 
 
 
 
 
46.00% 
54.00% 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
46.00% 
54.00% 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Target asset allocation
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Equities (as a percent)
64.00% 
27.00% 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Alternative investments (as a percent)
 
 
9.00% 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Fair value of Pinnacle West's pension plan and other postretirement benefit plan assets, by asset category
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Fair value of plan assets
 
 
 
$ 1,850,550 
$ 1,775,596 
$ 1,461,808 
$ 1,850,550 
$ 1,775,596 
$ 763,959 
$ 757,755 
$ 1,079,313 
$ 1,009,770 
$ 7,278 
$ 8,071 
 
 
$ 1,441 
$ 2,375 
$ 1,441 
$ 2,375 
$ 584,619 
$ 508,946 
$ 584,619 
$ 508,946 
$ 207,862 
$ 163,313 
$ 207,862 
$ 163,313 
$ 62,906 
$ 53,358 
$ 62,906 
$ 53,358 
$ 436,393 
$ 462,973 
$ 436,393 
$ 462,973 
$ 118,263 
$ 129,094 
$ 118,263 
$ 129,094 
$ 13,620 
$ 5,549 
$ 8,071 
$ 139,321 
$ 146,705 
$ 139,321 
$ 146,705 
$ 156,407 
$ 177,114 
$ 156,407 
$ 177,114 
$ 106,147 
$ 92,454 
$ 106,147 
$ 92,454 
$ 64,212 
$ 37,191 
$ 29,913 
$ 7,278 
$ 25,644 
$ 25,644 
$ 608,663 
$ 567,410 
$ 490,455 
$ 608,663 
$ 567,410 
$ 305,202 
$ 279,068 
$ 301,495 
$ 286,308 
$ 1,966 
$ 2,034 
 
 
$ 160 
$ 243 
$ 160 
$ 243 
$ 148,417 
$ 118,660 
$ 148,417 
$ 118,660 
$ 103,321 
$ 74,049 
$ 103,321 
$ 74,049 
$ 30,105 
$ 24,456 
$ 30,105 
$ 24,456 
$ 179,235 
$ 179,655 
$ 179,235 
$ 179,655 
$ 22,486 
$ 25,121 
$ 22,486 
$ 25,121 
$ 2,399 
$ 365 
$ 2,034 
$ 52,507 
$ 54,144 
$ 52,507 
$ 54,144 
$ 53,504 
$ 61,455 
$ 53,504 
$ 61,455 
$ 8,446 
$ 7,357 
$ 8,446 
$ 7,357 
$ 6,504 
$ 10,482 
$ 8,516 
$ 1,966 
$ 19,871 
$ 19,871 
Retirement Plans and Other Benefits (Details 4) (USD $)
12 Months Ended
Dec. 31, 2011
Dec. 31, 2010
Dec. 31, 2009
Pinnacle West
 
 
 
Employee Savings Plan Benefits
 
 
 
Expenses recorded for the defined contribution savings plan
$ 8,000,000 
$ 9,000,000 
$ 9,000,000 
ARIZONA PUBLIC SERVICE COMPANY
 
 
 
Employee Savings Plan Benefits
 
 
 
APS's employees share of total cost of the plans (as a percent)
99.00% 
 
 
Pension Benefits
 
 
 
Changes in fair value for assets that are measured at fair value on a recurring basis
 
 
 
Fair value of plan assets at the beginning of the period
 
1,461,808,000 
 
Fair value of plan assets at the end of the period
1,850,550,000 
1,775,596,000 
 
Contributions
 
 
 
Expected contributions in 2012
65,000,000 
 
 
Expected contributions in 2013
160,000,000 
 
 
Expected contributions in 2014
160,000,000 
 
 
Actual contribution to benefit plans in the current fiscal year
 
200,000,000 
 
Estimated Future Benefit Payments
 
 
 
2012
113,075,000 
 
 
2013
122,750,000 
 
 
2014
132,302,000 
 
 
2015
141,516,000 
 
 
2016
154,379,000 
 
 
Years 2017-2021
941,377,000 
 
 
Pension Benefits |
Pinnacle West
 
 
 
Changes in fair value for assets that are measured at fair value on a recurring basis
 
 
 
Fair value of plan assets at the end of the period
1,850,550,000 
1,775,596,000 
 
Pension Benefits |
ARIZONA PUBLIC SERVICE COMPANY
 
 
 
Contributions
 
 
 
Actual contribution to benefit plans in the current fiscal year
 
195,000,000 
 
Pension Benefits |
Real estate |
Pinnacle West
 
 
 
Changes in fair value for assets that are measured at fair value on a recurring basis
 
 
 
Fair value of plan assets at the end of the period
106,147,000 
92,454,000 
 
Pension Benefits |
Real estate |
Significant Unobservable Inputs (Level 3) |
Pinnacle West
 
 
 
Changes in fair value for assets that are measured at fair value on a recurring basis
 
 
 
Fair value of plan assets at the beginning of the period
 
64,212,000 
 
Actual return on assets still held
 
(204,000)
 
Purchases, sales, and settlements
 
18,003,000 
 
Transfers in and/or out of Level 3
 
(82,011,000)
 
Other Benefits
 
 
 
Changes in fair value for assets that are measured at fair value on a recurring basis
 
 
 
Fair value of plan assets at the beginning of the period
567,410,000 
490,455,000 
 
Fair value of plan assets at the end of the period
608,663,000 
567,410,000 
 
Contributions
 
 
 
Expected contributions in 2012
20,000,000 
 
 
Expected contributions in 2013
20,000,000 
 
 
Expected contributions in 2014
20,000,000 
 
 
Actual contribution to benefit plans in the current fiscal year
18,769,000 
16,700,000 
 
Estimated Future Benefit Payments
 
 
 
2012
27,610,000 
 
 
2013
30,562,000 
 
 
2014
33,451,000 
 
 
2015
36,489,000 
 
 
2016
39,525,000 
 
 
Years 2017-2021
246,091,000 
 
 
Other Benefits |
Pinnacle West
 
 
 
Changes in fair value for assets that are measured at fair value on a recurring basis
 
 
 
Fair value of plan assets at the end of the period
608,663,000 
567,410,000 
 
Other Benefits |
ARIZONA PUBLIC SERVICE COMPANY
 
 
 
Contributions
 
 
 
Actual contribution to benefit plans in the current fiscal year
19,000,000 
16,000,000 
15,000,000 
Other Benefits |
Real estate |
Pinnacle West
 
 
 
Changes in fair value for assets that are measured at fair value on a recurring basis
 
 
 
Fair value of plan assets at the end of the period
8,446,000 
7,357,000 
 
Other Benefits |
Real estate |
Significant Unobservable Inputs (Level 3) |
Pinnacle West
 
 
 
Changes in fair value for assets that are measured at fair value on a recurring basis
 
 
 
Fair value of plan assets at the beginning of the period
 
6,504,000 
 
Actual return on assets still held
 
(23,000)
 
Purchases, sales, and settlements
 
45,000 
 
Transfers in and/or out of Level 3
 
$ (6,526,000)
 
Leases (Details) (USD $)
In Millions, unless otherwise specified
12 Months Ended
Dec. 31, 2011
Dec. 31, 2010
Dec. 31, 2009
Dec. 31, 2011
ARIZONA PUBLIC SERVICE COMPANY
trust
Dec. 31, 2010
ARIZONA PUBLIC SERVICE COMPANY
Dec. 31, 2009
ARIZONA PUBLIC SERVICE COMPANY
Dec. 31, 2008
ARIZONA PUBLIC SERVICE COMPANY
trust
Dec. 31, 1986
Palo Verde Lessor Trusts
trust
Leases
 
 
 
 
 
 
 
 
Lease expense
$ 21 
$ 23 
$ 28 
$ 18 
$ 19 
$ 19 
 
 
Estimated future minimum lease payments for operating leases, excluding purchased power agreements
 
 
 
 
 
 
 
 
2012
21 
 
 
18 
 
 
 
 
2013
18 
 
 
15 
 
 
 
 
2014
15 
 
 
12 
 
 
 
 
2015
13 
 
 
10 
 
 
 
 
2016
 
 
 
 
 
 
Thereafter
23 
 
 
22 
 
 
 
 
Total future lease commitments
$ 92 
 
 
$ 79 
 
 
 
 
Number of VIE lessor trusts
 
 
 
 
 
Jointly-Owned Facilities (Details) (ARIZONA PUBLIC SERVICE COMPANY, USD $)
In Thousands, unless otherwise specified
Dec. 31, 2011
Palo Verde Units 1 and 3
 
Interests in jointly-owned facilities
 
Percent Owned
29.10% 
Plant in Service
$ 2,061,894 
Accumulated Depreciation
1,154,141 
Construction Work in Progress
66,558 
Palo Verde Unit 2
 
Interests in jointly-owned facilities
 
Percent Owned
17.00% 
Plant in Service
661,006 
Accumulated Depreciation
365,704 
Construction Work in Progress
33,032 
Palo Verde Sale Leaseback
 
Interests in jointly-owned facilities
 
Plant in Service
351,050 
Accumulated Depreciation
218,186 
Four Corners Units 4 and 5
 
Interests in jointly-owned facilities
 
Percent Owned
15.00% 
Plant in Service
165,139 
Accumulated Depreciation
104,910 
Construction Work in Progress
2,357 
Four Corners common
 
Interests in jointly-owned facilities
 
Percent Owned
38.44% 
Plant in Service
16,413 
Accumulated Depreciation
5,997 
Construction Work in Progress
750 
Navajo Generating Station Units 1, 2 and 3
 
Interests in jointly-owned facilities
 
Percent Owned
14.00% 
Plant in Service
264,227 
Accumulated Depreciation
170,777 
Construction Work in Progress
10,327 
Cholla common facilities
 
Interests in jointly-owned facilities
 
Percent Owned
63.30% 
Plant in Service
146,642 
Accumulated Depreciation
51,985 
Construction Work in Progress
1,661 
ANPP 500kV System
 
Interests in jointly-owned facilities
 
Percent Owned
33.00% 
Plant in Service
88,451 
Accumulated Depreciation
30,123 
Construction Work in Progress
10,161 
Navajo Southern System
 
Interests in jointly-owned facilities
 
Percent Owned
25.90% 
Plant in Service
51,174 
Accumulated Depreciation
15,161 
Construction Work in Progress
920 
Palo Verde - Yuma 500kV System
 
Interests in jointly-owned facilities
 
Percent Owned
44.10% 
Plant in Service
8,816 
Accumulated Depreciation
4,331 
Four Corners Switchyards
 
Interests in jointly-owned facilities
 
Percent Owned
39.60% 
Plant in Service
19,630 
Accumulated Depreciation
5,696 
Construction Work in Progress
1,004 
Phoenix - Mead System
 
Interests in jointly-owned facilities
 
Percent Owned
17.50% 
Plant in Service
39,374 
Accumulated Depreciation
10,731 
Palo Verde - Estrella 500kV System
 
Interests in jointly-owned facilities
 
Percent Owned
50.00% 
Plant in Service
85,643 
Accumulated Depreciation
11,769 
Construction Work in Progress
3,445 
North Valley System
 
Interests in jointly-owned facilities
 
Percent Owned
69.30% 
Plant in Service
95,057 
Accumulated Depreciation
1,757 
Construction Work in Progress
3,821 
Round Valley System
 
Interests in jointly-owned facilities
 
Percent Owned
50.00% 
Plant in Service
570 
Accumulated Depreciation
$ 320 
Commitments and Contingencies (Details) (ARIZONA PUBLIC SERVICE COMPANY, USD $)
12 Months Ended
Dec. 31, 2011
trust
D
Dec. 31, 2008
trust
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
49,000,000 
 
Maximum insurance against public liability per occurrence for a nuclear incident
12,600,000,000 
 
Maximum available nuclear liability insurance
375,000,000 
 
Remaining nuclear liability insurance through mandatory industry wide retrospective assessment program
12,200,000,000 
 
Maximum assessment per reactor for each nuclear incident
118,000,000 
 
Annual limit per incident with respect to maximum assessment
18,000,000 
 
Number of VIE lessor trusts
Maximum potential assessment per incident of APS
103,000,000 
 
Annual payment limitation with respect to maximum potential assessment
15,000,000 
 
Amount of "all risk" (including nuclear hazards) insurance for property damage to, and decontamination of, property at Palo Verde
2,750,000,000 
 
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
$ 46,000,000 
 
Period to provide collateral assurance based on rating triggers (in days)
20 
 
Commitments and Contingencies (Details 2) (USD $)
In Millions, unless otherwise specified
12 Months Ended 1 Months Ended 1 Months Ended 12 Months Ended
Dec. 31, 2011
Climate Change Lawsuit
oilcompany
powercompany
Dec. 31, 2011
Lawsuit
complaint
Sep. 30, 2011
ARIZONA PUBLIC SERVICE COMPANY
minute
kV
MW
customer
Dec. 31, 2011
ARIZONA PUBLIC SERVICE COMPANY
creditfacility
Sep. 8, 2011
ARIZONA PUBLIC SERVICE COMPANY
Sep. 30, 2011
ARIZONA PUBLIC SERVICE COMPANY
United States
customer
Sep. 30, 2011
ARIZONA PUBLIC SERVICE COMPANY
Northern Mexico
customer
Dec. 31, 2011
Coal take-or-pay commitments
ARIZONA PUBLIC SERVICE COMPANY
Dec. 31, 2010
Coal take-or-pay commitments
ARIZONA PUBLIC SERVICE COMPANY
Dec. 31, 2009
Coal take-or-pay commitments
ARIZONA PUBLIC SERVICE COMPANY
Dec. 31, 2011
Renewable energy credits
ARIZONA PUBLIC SERVICE COMPANY
Dec. 31, 2011
Coal Mine Reclamation Obligations
ARIZONA PUBLIC SERVICE COMPANY
Dec. 31, 2010
Coal Mine Reclamation Obligations
ARIZONA PUBLIC SERVICE COMPANY
Fuel and Purchased Power Commitments and Purchase Obligations
 
 
 
 
 
 
 
 
 
 
 
 
 
Actual purchases under commitment obligations
 
 
 
 
 
 
 
$ 68 
$ 66 
$ 93 
 
 
 
Contractual Obligations
 
 
 
 
 
 
 
 
 
 
 
 
 
2012
 
 
 
580 
 
 
 
79 
 
 
58 
 
 
2013
 
 
 
528 
 
 
 
82 
 
 
32 
 
 
2014
 
 
 
556 
 
 
 
86 
 
 
33 
 
 
2015
 
 
 
535 
 
 
 
88 
 
 
32 
 
 
2016
 
 
 
503 
 
 
 
58 
 
 
32 
 
 
Thereafter
 
 
 
6,800 
 
 
 
148 
 
 
388 
 
 
Total commitments
 
 
 
 
 
 
 
541 
 
 
 
118 
117 
Total net present value of commitments
 
 
 
 
 
 
 
401 
 
 
 
 
 
Climate Change Lawsuit
 
 
 
 
 
 
 
 
 
 
 
 
 
Number of oil companies
 
 
 
 
 
 
 
 
 
 
 
 
Number of power companies
14 
 
 
 
 
 
 
 
 
 
 
 
 
Number of consumer class action complaints filed
 
 
 
 
 
 
 
 
 
 
 
 
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 (in minutes)
 
 
10 
 
 
 
 
 
 
 
 
 
 
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
 
 
2,800,000 
 
 
1,600,000 
1,200,000 
 
 
 
 
 
 
Maximum possible fine per violation per day that the violation is found to have been in existence
 
 
 
 
 
 
 
 
 
 
 
 
Financial Assurances
 
 
 
 
 
 
 
 
 
 
 
 
 
Outstanding letters of credit to support existing pollution control bonds
 
 
 
44 
 
 
 
 
 
 
 
 
 
Letters of credit to support certain equity lessors in the Palo Verde sale leaseback transactions
 
 
 
52 
 
 
 
 
 
 
 
 
 
Outstanding letters of credit to support natural gas tolling contract obligations
 
 
 
$ 30 
 
 
 
 
 
 
 
 
 
Number of letters of credit issued
 
 
 
 
 
 
 
 
 
 
 
 
Asset Retirement Obligations (Details) (ARIZONA PUBLIC SERVICE COMPANY, USD $)
In Millions, unless otherwise specified
12 Months Ended
Dec. 31, 2011
Dec. 31, 2010
Apr. 21, 2011
Y
Dec. 31, 2008
Y
ARIZONA PUBLIC SERVICE COMPANY
 
 
 
 
Asset Retirement Obligations
 
 
 
 
License extension approved by the NRC (in years)
 
 
20 
20 
Change in asset retirement obligations
 
 
 
 
Asset retirement obligations at the beginning of year
$ 329 
$ 302 
 
 
Changes attributable to:
 
 
 
 
Accretion expense
19 
22 
 
 
Estimated cash flow revisions
(68)
 
 
Asset retirement obligations at the end of year
$ 280 
$ 329 
 
 
Selected Quarterly Financial Data (Unaudited) (Details) (USD $)
In Thousands, except Per Share data, unless otherwise specified
3 Months Ended 12 Months Ended 3 Months Ended 12 Months Ended 3 Months Ended 12 Months Ended 3 Months Ended 12 Months Ended
Dec. 31, 2011
Sep. 30, 2011
Jun. 30, 2011
Mar. 31, 2011
Dec. 31, 2011
Dec. 31, 2010
Dec. 31, 2009
Dec. 31, 2010
As previously reported
Sep. 30, 2010
As previously reported
Jun. 30, 2010
As previously reported
Mar. 31, 2010
As previously reported
Dec. 31, 2010
As previously reported
Dec. 31, 2009
As previously reported
Mar. 31, 2011
Restatements
Dec. 31, 2010
Restatements
Sep. 30, 2010
Restatements
Jun. 30, 2010
Restatements
Mar. 31, 2010
Restatements
Dec. 31, 2010
Restatements
Dec. 31, 2009
Restatements
Dec. 31, 2010
Amount reported after reclassification
Sep. 30, 2010
Amount reported after reclassification
Jun. 30, 2010
Amount reported after reclassification
Mar. 31, 2010
Amount reported after reclassification
Dec. 31, 2010
Amount reported after reclassification
Dec. 31, 2009
Amount reported after reclassification
Consolidated quarterly financial information
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Operating revenues
$ 667,892 
$ 1,124,841 
$ 799,799 
$ 648,847 
$ 3,241,379 
$ 3,189,199 
$ 3,153,656 
$ 683,611 
$ 1,139,085 
$ 820,594 
$ 620,355 
$ 3,263,645 
 
 
$ (26,179)
$ (22,375)
$ (17,799)
$ (8,093)
$ (74,446)
 
$ 657,432 
$ 1,116,710 
$ 802,795 
$ 612,262 
$ 3,189,199 
 
Operations and maintenance
228,632 
210,035 
210,590 
255,029 
904,286 
870,185 
822,300 
232,991 
221,469 
215,104 
207,842 
877,406 
831,863 
 
(2,386)
(1,811)
(1,495)
(1,529)
(7,221)
(9,563)
230,605 
219,658 
213,609 
206,313 
870,185 
822,300 
Operating income
78,715 
435,017 
196,992 
35,784 
746,508 
714,883 
616,128 
59,318 
403,625 
203,273 
57,668 
723,884 
 
 
(3,067)
(3,351)
(1,889)
(694)
(9,001)
 
56,251 
400,274 
201,384 
56,974 
714,883 
 
Income Taxes
7,375 
131,416 
50,818 
(6,005)
183,604 
160,869 
138,551 
(3,822)
123,486 
51,829 
(7,172)
164,321 
136,506 
 
(1,191)
(1,139)
(641)
(481)
(3,452)
2,045 
(5,013)
122,347 
51,188 
(7,653)
160,869 
138,551 
Income (loss) from continuing operations
19,544 
253,273 
93,185 
(10,368)
355,634 
344,851 
256,048 
12,203 
231,828 
94,584 
11,983 
350,598 
252,558 
 
(1,919)
(2,266)
(1,270)
(292)
(5,747)
3,490 
10,284 
229,562 
93,314 
11,691 
344,851 
256,048 
Net income (loss) attributable to common shareholders
12,564 
255,359 
86,685 
(15,135)
339,473 
350,053 
68,330 
7,350 
233,920 
114,797 
(6,014)
350,053 
 
 
 
 
 
 
 
 
7,350 
233,920 
114,797 
(6,014)
350,053 
 
Earnings Per Share:
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Income (loss) from continuing operations attributable to common shareholders - Basic (in dollars per share)
$ 0.11 
$ 2.25 
$ 0.79 
$ (0.15)
$ 3.01 
$ 3.05 
$ 2.34 
$ 0.07 
$ 2.09 
$ 0.84 
$ 0.07 
$ 3.10 
 
 
 
 
 
 
 
 
$ 0.05 
$ 2.07 
$ 0.82 
$ 0.06 
$ 3.05 
 
Net income (loss) attributable to common shareholders - Basic (in dollars per share)
$ 0.12 
$ 2.34 
$ 0.80 
$ (0.14)
$ 3.11 
$ 3.28 
$ 0.68 
$ 0.07 
$ 2.15 
$ 1.07 
$ (0.06)
$ 3.28 
 
 
 
 
 
 
 
 
$ 0.07 
$ 2.15 
$ 1.07 
$ (0.06)
$ 3.28 
 
Income (loss) from continuing operations attributable to common shareholders - Diluted (in dollars per share)
$ 0.11 
$ 2.24 
$ 0.78 
$ (0.15)
$ 2.99 
$ 3.03 
$ 2.34 
$ 0.06 
$ 2.08 
$ 0.83 
$ 0.07 
$ 3.08 
 
 
 
 
 
 
 
 
$ 0.05 
$ 2.06 
$ 0.82 
$ 0.06 
$ 3.03 
 
Net income (loss) attributable to common shareholders - Diluted (in dollars per share)
$ 0.11 
$ 2.32 
$ 0.79 
$ (0.14)
$ 3.09 
$ 3.27 
$ 0.67 
$ 0.07 
$ 2.14 
$ 1.07 
$ (0.06)
$ 3.27 
 
 
 
 
 
 
 
 
$ 0.07 
$ 2.14 
$ 1.07 
$ (0.06)
$ 3.27 
 
Reduction in operating revenues
 
 
 
 
 
 
 
 
 
 
 
 
 
10,728 
 
 
 
 
 
 
 
 
 
 
 
 
Reduction in operations and maintenance
 
 
 
 
 
 
 
 
 
 
 
 
 
1,457 
 
 
 
 
 
 
 
 
 
 
 
 
Reduction in operating income
 
 
 
 
 
 
 
 
 
 
 
 
 
1,357 
 
 
 
 
 
 
 
 
 
 
 
 
Decrease in income taxes
 
 
 
 
 
 
 
 
 
 
 
 
 
356 
 
 
 
 
 
 
 
 
 
 
 
 
Decrease in income from continuing operations
 
 
 
 
 
 
 
 
 
 
 
 
 
$ 1,043 
 
 
 
 
 
 
 
 
 
 
 
 
Fair Value Measurements (Details) (USD $)
12 Months Ended
Dec. 31, 2011
M
Dec. 31, 2010
Assets
 
 
Risk management activities: commodity contracts
$ 79,586,000 
$ 112,820,000 
Nuclear decommissioning trust
513,733,000 
469,886,000 
Liabilities
 
 
Risk management activities: commodity contracts
(136,463,000)
(124,366,000)
Cash equivalents maximum maturity period (in days)
 
Changes in fair value for assets and liabilities that are measured at fair value on a recurring basis using Level 3 inputs
 
 
Net risk management activities at beginning of period
(38,000,000)
(10,000,000)
Total net gains (losses) realized/unrealized:
 
 
Included in earnings
2,000,000 
(1,000,000)
Included in OCI
(5,000,000)
(14,000,000)
Deferred as a regulatory asset or liability
(10,000,000)
(38,000,000)
Settlements
11,000,000 
19,000,000 
Transfers into Level 3 from Level 2
(4,000,000)
5,000,000 
Transfers from Level 3 into Level 2
(7,000,000)
1,000,000 
Net risk management activities at end of period
(51,000,000)
(38,000,000)
Net unrealized gains (losses) included in earnings related to instruments still held at end of period
1,000,000 
(1,000,000)
Fair value measurement on a recurring basis |
Quoted Prices in Active Markets for Identical Assets (Level 1)
 
 
Assets
 
 
Cash equivalents
 
35,000,000 
Nuclear decommissioning trust
69,000,000 
50,000,000 
Total assets
69,000,000 
85,000,000 
Liabilities
 
 
Risk management activities: commodity contracts
 
(1,000,000)
Fair value measurement on a recurring basis |
Quoted Prices in Active Markets for Identical Assets (Level 1) |
U.S. Treasury
 
 
Assets
 
 
Nuclear decommissioning trust
69,000,000 
50,000,000 
Fair value measurement on a recurring basis |
Significant Other Observable Inputs (Level 2)
 
 
Assets
 
 
Risk management activities: commodity contracts
70,000,000 
80,000,000 
Nuclear decommissioning trust
446,000,000 
430,000,000 
Total assets
516,000,000 
510,000,000 
Liabilities
 
 
Risk management activities: commodity contracts
(241,000,000)
(280,000,000)
Fair value measurement on a recurring basis |
Significant Other Observable Inputs (Level 2) |
US commingled equity funds
 
 
Assets
 
 
Nuclear decommissioning trust
175,000,000 
168,000,000 
Fair value measurement on a recurring basis |
Significant Other Observable Inputs (Level 2) |
Cash and cash equivalent funds
 
 
Assets
 
 
Nuclear decommissioning trust
9,000,000 
22,000,000 
Fair value measurement on a recurring basis |
Significant Other Observable Inputs (Level 2) |
Corporate debt
 
 
Assets
 
 
Nuclear decommissioning trust
73,000,000 
60,000,000 
Fair value measurement on a recurring basis |
Significant Other Observable Inputs (Level 2) |
Mortgage-backed securities
 
 
Assets
 
 
Nuclear decommissioning trust
78,000,000 
81,000,000 
Fair value measurement on a recurring basis |
Significant Other Observable Inputs (Level 2) |
Municipality bonds
 
 
Assets
 
 
Nuclear decommissioning trust
90,000,000 
79,000,000 
Fair value measurement on a recurring basis |
Significant Other Observable Inputs (Level 2) |
Other
 
 
Assets
 
 
Nuclear decommissioning trust
21,000,000 
20,000,000 
Fair value measurement on a recurring basis |
Significant Unobservable Inputs (Level 3)
 
 
Assets
 
 
Risk management activities: commodity contracts
74,000,000 
61,000,000 
Total assets
74,000,000 
61,000,000 
Liabilities
 
 
Risk management activities: commodity contracts
(125,000,000)
(99,000,000)
Fair value measurement on a recurring basis |
Other
 
 
Assets
 
 
Risk management activities: commodity contracts
(64,000,000)
(28,000,000)
Nuclear decommissioning trust
(1,000,000)
(10,000,000)
Total assets
(65,000,000)
(38,000,000)
Liabilities
 
 
Risk management activities: commodity contracts
229,000,000 
256,000,000 
Fair value measurement on a recurring basis |
Other |
Cash and cash equivalent funds
 
 
Assets
 
 
Nuclear decommissioning trust
(1,000,000)
 
Fair value measurement on a recurring basis |
Other |
Other
 
 
Assets
 
 
Nuclear decommissioning trust
 
(10,000,000)
Fair value measurement on a recurring basis |
Fair Value
 
 
Assets
 
 
Cash equivalents
 
35,000,000 
Risk management activities: commodity contracts
80,000,000 
113,000,000 
Nuclear decommissioning trust
514,000,000 
470,000,000 
Total assets
594,000,000 
618,000,000 
Liabilities
 
 
Risk management activities: commodity contracts
(137,000,000)
(124,000,000)
Fair value measurement on a recurring basis |
Fair Value |
US commingled equity funds
 
 
Assets
 
 
Nuclear decommissioning trust
175,000,000 
168,000,000 
Fair value measurement on a recurring basis |
Fair Value |
U.S. Treasury
 
 
Assets
 
 
Nuclear decommissioning trust
69,000,000 
50,000,000 
Fair value measurement on a recurring basis |
Fair Value |
Cash and cash equivalent funds
 
 
Assets
 
 
Nuclear decommissioning trust
8,000,000 
22,000,000 
Fair value measurement on a recurring basis |
Fair Value |
Corporate debt
 
 
Assets
 
 
Nuclear decommissioning trust
73,000,000 
60,000,000 
Fair value measurement on a recurring basis |
Fair Value |
Mortgage-backed securities
 
 
Assets
 
 
Nuclear decommissioning trust
78,000,000 
81,000,000 
Fair value measurement on a recurring basis |
Fair Value |
Municipality bonds
 
 
Assets
 
 
Nuclear decommissioning trust
90,000,000 
79,000,000 
Fair value measurement on a recurring basis |
Fair Value |
Other
 
 
Assets
 
 
Nuclear decommissioning trust
$ 21,000,000 
$ 10,000,000 
Earnings Per Share (Details) (USD $)
3 Months Ended 12 Months Ended
Dec. 31, 2011
Sep. 30, 2011
Jun. 30, 2011
Mar. 31, 2011
Dec. 31, 2011
Dec. 31, 2010
Dec. 31, 2009
Basic earnings per share:
 
 
 
 
 
 
 
Income from continuing operations attributable to common shareholders (in dollars per share)
$ 0.11 
$ 2.25 
$ 0.79 
$ (0.15)
$ 3.01 
$ 3.05 
$ 2.34 
Income (loss) from discontinued operations (in dollars per share)
 
 
 
 
$ 0.10 
$ 0.23 
$ (1.66)
Earnings per share - basic (in dollars per share)
$ 0.12 
$ 2.34 
$ 0.80 
$ (0.14)
$ 3.11 
$ 3.28 
$ 0.68 
Diluted earnings per share:
 
 
 
 
 
 
 
Income from continuing operations attributable to common shareholders (in dollars per share)
$ 0.11 
$ 2.24 
$ 0.78 
$ (0.15)
$ 2.99 
$ 3.03 
$ 2.34 
Income (loss) from discontinued operations
 
 
 
 
$ 0.10 
$ 0.24 
$ (1.67)
Earnings per share - diluted (in dollars per share)
$ 0.11 
$ 2.32 
$ 0.79 
$ (0.14)
$ 3.09 
$ 3.27 
$ 0.67 
Dilutive stock options and performance shares
 
 
 
 
811,000 
565,000 
103,000 
Total average common shares outstanding for the purposes of calculating diluted earnings per share
 
 
 
 
109,864,000 
107,138,000 
101,264,000 
Options to purchase shares of common stock outstanding excluded from computation of diluted earnings per share due to its antidilutive effect
 
 
 
 
 
192,542 
572,301 
Stock-Based Compensation (Details) (USD $)
In Millions, except Share data, unless otherwise specified
12 Months Ended 0 Months Ended 12 Months Ended 1 Months Ended
May 23, 2007
2007 grant
Dec. 31, 2011
Restricted stock unit awards
Dec. 31, 2010
Restricted stock unit awards
Dec. 31, 2009
Restricted stock unit awards
Dec. 31, 2011
Restricted stock units and stock grants
stockunit
Dec. 31, 2010
Restricted stock units and stock grants
stockunit
Dec. 31, 2009
Restricted stock units and stock grants
stockunit
Dec. 31, 2011
Restricted stock units and stock grants
2007 grant
Dec. 31, 2010
Restricted stock units and stock grants
2007 grant
Dec. 31, 2009
Restricted stock units and stock grants
2007 grant
Dec. 31, 2011
Restricted stock units and stock grants
2008 grant
Dec. 31, 2010
Restricted stock units and stock grants
2008 grant
Dec. 31, 2009
Restricted stock units and stock grants
2008 grant
Dec. 31, 2011
Restricted stock units and stock grants
2009 grant
Dec. 31, 2010
Restricted stock units and stock grants
2009 grant
Dec. 31, 2011
Restricted stock units and stock grants
2010 grant
Dec. 31, 2011
Performance Share Awards
stockunit
Dec. 31, 2010
Performance Share Awards
stockunit
Dec. 31, 2009
Performance Share Awards
stockunit
Dec. 21, 2011
Performance Share Awards
2007 grant
criteria
Dec. 31, 2011
Performance Share Awards
2009 grant
Metrics
Dec. 31, 2011
Performance Share Awards
2009 grant
Maximum
Dec. 31, 2011
Performance Share Awards
2009 grant
Minimum
Dec. 31, 2011
Performance Share Awards
2010 grant
Metrics
Dec. 31, 2011
Performance Share Awards
2010 grant
Maximum
Dec. 31, 2011
Performance Share Awards
2010 grant
Minimum
Dec. 31, 2011
Performance Share Awards
2011 grant
Metrics
Dec. 31, 2011
Performance Share Awards
2011 grant
Maximum
Dec. 31, 2011
Performance Share Awards
2011 grant
Minimum
Jan. 2, 2010
Retention Units
Jan. 2, 2009
Retention Units
Dec. 31, 2011
Retention Units
Dec. 31, 2010
Retention Units
Dec. 31, 2009
Retention Units
Jan. 31, 2009
Incentive Shares
Stock-Based Compensation
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Maximum common shares to be available for grant under the 2007 Plan
8,000,000 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
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 (in years)
 
4 years 
4 years 
4 years 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
4 years 
 
 
 
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% 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Status of stock grants and changes during the year
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Nonvested at the beginning of the period (in shares)
 
 
 
 
223,681 
 
 
 
 
 
 
 
 
 
 
 
395,312 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Granted (in shares)
 
 
 
 
293,242 
 
 
 
 
 
 
 
 
 
 
 
175,072 
178,722 
240,624 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Vested (in shares)
 
 
 
 
98,362 
 
 
 
 
 
 
 
 
 
 
 
218,310 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Forfeited (in shares)
 
 
 
 
2,330 
 
 
 
 
 
 
 
 
 
 
 
4,128 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Nonvested at the end of the period (in shares)
 
 
 
 
416,231 
223,681 
 
 
 
 
 
 
 
 
 
 
347,946 
395,312 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Weighted-Average Grant-Date Fair Value
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Nonvested at the beginning of the period (in dollars per share)
 
 
 
 
$ 35.69 
 
 
 
 
 
 
 
 
 
 
 
$ 33.44 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Granted (in dollars per share)
 
 
 
 
$ 41.98 
$ 37.47 
$ 30.25 
 
 
 
 
 
 
 
 
 
$ 41.71 
$ 37.57 
$ 30.19 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
$ 32.58 
Vested (in dollars per share)
 
 
 
 
$ 37.84 
 
 
 
 
 
 
 
 
 
 
 
$ 30.14 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Forfeited (in dollars per share)
 
 
 
 
$ 37.93 
 
 
 
 
 
 
 
 
 
 
 
$ 36.09 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Nonvested at the end of the period (in dollars per share)
 
 
 
 
$ 39.61 
$ 35.69 
 
 
 
 
 
 
 
 
 
 
$ 39.64 
$ 33.44 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Stocks granted and the weighted average fair value
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Units granted (in shares)
 
 
 
 
292,242 
202,341 
261,006 
 
 
 
 
 
 
 
 
 
175,072 
178,722 
240,624 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Grant date fair value (in dollars per share)
 
 
 
 
$ 41.98 
$ 37.47 
$ 30.25 
 
 
 
 
 
 
 
 
 
$ 41.71 
$ 37.57 
$ 30.19 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
$ 32.58 
Additional disclosures
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Cash required to settle the payment for grant
 
 
 
 
 
 
 
$ 1.0 
$ 0.9 
$ 0.8 
$ 1.6 
$ 1.5 
$ 1.3 
$ 1.5 
$ 1.4 
$ 0.6 
 
 
 
 
 
 
 
 
 
 
 
 
 
$ 1.3 
$ 1.1 
 
$ 1.3 
$ 1.1 
 
Percentage of the awards that vest based on a percentile ranking of earnings per share growth rate
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
50.00% 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Percentage of the awards that vest based on a percentile ranking of total shareholder return
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
50.00% 
 
 
50.00% 
 
 
 
 
 
 
 
 
Percentage of the awards that vest based on non-financial separate performance metrics
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
50.00% 
 
 
50.00% 
 
 
 
 
 
 
 
 
Number of performance elements criteria
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Number of non-financial separate performance metrics based on which awards vest
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Performance period (in years)
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
3 years 
3 years 
 
 
3 years 
 
 
3 years 
 
 
 
 
 
 
 
 
Number of shares issued for stock grant
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
138,756 
Exact number of shares issued as a percentage of the target award
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
150.00% 
0.00% 
 
200.00% 
0.00% 
 
200.00% 
0.00% 
 
 
 
 
 
 
Stock-Based Compensation (Details 2) (USD $)
12 Months Ended
Dec. 31, 2011
Y
Dec. 31, 2010
Dec. 31, 2009
Additional disclosures
 
 
 
Total unrecognized compensation cost related to nonvested share-based compensation arrangements granted
$ 20,500,000 
 
 
Expected weighted-average period of recognition of unrecognized compensation cost (in years)
2.2 
 
 
Total fair value of shares vested
14,400,000 
11,000,000 
10,000,000 
Compensation cost that has been charged against income
23,000,000 
15,000,000 
5,000,000 
Total income tax benefit recognized
9,000,000 
6,000,000 
2,000,000 
ARIZONA PUBLIC SERVICE COMPANY
 
 
 
Additional disclosures
 
 
 
Compensation cost that has been charged against income
22,000,000 
15,000,000 
4,000,000 
Stock Options
 
 
 
Stock option activity under prior equity incentive plans
 
 
 
Outstanding at the beginning of the period (in shares)
82,224 
 
 
Exercised (in shares)
44,766 
 
 
Forfeited or expired (in shares)
14,500 
 
 
Outstanding at the end of the period (in shares)
22,958 
82,224 
 
Exercisable at the end of the period (in shares)
22,958 
 
 
Weighted-Average Exercise Price
 
 
 
Outstanding at the beginning of the period (in dollars per share)
$ 39.37 
 
 
Exercised (in dollars per share)
$ 40.70 
 
 
Forfeited or expired (in dollars per share)
$ 42.55 
 
 
Outstanding at the end of the period (in dollars per share)
$ 34.75 
$ 39.37 
 
Exercisable at the end of the period (in dollars per share)
$ 34.75 
 
 
Weighted-Average Remaining Contractual Term (in months)
 
 
 
Outstanding at the end of the period (in months)
11 
 
 
Exercisable at the end of the period (in months)
11 
 
 
Aggregate Intrinsic Value
 
 
 
Outstanding at the end of the period
308,000 
 
 
Exercisable at the end of the period
308,000 
 
 
Additional disclosures
 
 
 
Cash received from options exercised
$ 1,800,000 
$ 4,600,000 
$ 3,000,000 
Stock Options |
Maximum
 
 
 
Stock-Based Compensation
 
 
 
Term of outstanding options (in years)
10Y 
 
 
Business Segments (Details) (USD $)
3 Months Ended 12 Months Ended
Dec. 31, 2011
Sep. 30, 2011
Jun. 30, 2011
Mar. 31, 2011
Dec. 31, 2011
Dec. 31, 2010
Dec. 31, 2009
Financial data by business segment
 
 
 
 
 
 
 
Operating revenues
$ 667,892,000 
$ 1,124,841,000 
$ 799,799,000 
$ 648,847,000 
$ 3,241,379,000 
$ 3,189,199,000 
$ 3,153,656,000 
Fuel and purchased power costs
 
 
 
 
1,009,464,000 
1,046,815,000 
1,178,620,000 
Other operating expenses
 
 
 
 
1,058,000,000 
1,013,000,000 
952,000,000 
Operating margin
 
 
 
 
1,174,000,000 
1,129,000,000 
1,023,000,000 
Depreciation and amortization
 
 
 
 
427,054,000 
414,479,000 
407,354,000 
Interest expense
 
 
 
 
223,637,000 
227,695,000 
227,387,000 
Other expense (income)
 
 
 
 
(16,367,000)
(18,532,000)
(5,858,000)
INCOME FROM CONTINUING OPERATIONS BEFORE INCOME TAXES
 
 
 
 
539,238,000 
505,720,000 
394,599,000 
Income Taxes
7,375,000 
131,416,000 
50,818,000 
(6,005,000)
183,604,000 
160,869,000 
138,551,000 
INCOME FROM CONTINUING OPERATIONS
19,544,000 
253,273,000 
93,185,000 
(10,368,000)
355,634,000 
344,851,000 
256,048,000 
Income (loss) from discontinued operations - net of income tax expense (benefit)
 
 
 
 
11,306,000 
25,358,000 
(183,284,000)
Income tax expense (benefit) on discontinued operations
 
 
 
 
7,418,000 
16,260,000 
(109,641,000)
NET INCOME
 
 
 
 
366,940,000 
370,209,000 
72,764,000 
Net income attributable to noncontrolling interests
 
 
 
 
27,467,000 
20,156,000 
4,434,000 
Net income attributable to common shareholders
12,564,000 
255,359,000 
86,685,000 
(15,135,000)
339,473,000 
350,053,000 
68,330,000 
Total assets
13,111,018,000 
 
 
 
13,111,018,000 
12,392,998,000 
12,035,000,000 
Capital expenditures
 
 
 
 
885,000,000 
670,000,000 
745,000,000 
Regulated electricity segment
 
 
 
 
 
 
 
Financial data by business segment
 
 
 
 
 
 
 
Operating revenues
 
 
 
 
3,237,000,000 
3,181,000,000 
3,149,000,000 
Fuel and purchased power costs
 
 
 
 
1,009,000,000 
1,047,000,000 
1,179,000,000 
Other operating expenses
 
 
 
 
1,055,000,000 
1,009,000,000 
948,000,000 
Operating margin
 
 
 
 
1,173,000,000 
1,125,000,000 
1,022,000,000 
Depreciation and amortization
 
 
 
 
427,000,000 
415,000,000 
407,000,000 
Interest expense
 
 
 
 
224,000,000 
226,000,000 
226,000,000 
Other expense (income)
 
 
 
 
(19,000,000)
(22,000,000)
(16,000,000)
INCOME FROM CONTINUING OPERATIONS BEFORE INCOME TAXES
 
 
 
 
541,000,000 
506,000,000 
405,000,000 
Income Taxes
 
 
 
 
184,000,000 
161,000,000 
143,000,000 
INCOME FROM CONTINUING OPERATIONS
 
 
 
 
357,000,000 
345,000,000 
262,000,000 
NET INCOME
 
 
 
 
357,000,000 
345,000,000 
262,000,000 
Net income attributable to noncontrolling interests
 
 
 
 
28,000,000 
20,000,000 
19,000,000 
Net income attributable to common shareholders
 
 
 
 
329,000,000 
325,000,000 
243,000,000 
Total assets
13,068,000,000 
 
 
 
13,068,000,000 
12,285,000,000 
11,740,000,000 
Capital expenditures
 
 
 
 
885,000,000 
666,000,000 
732,000,000 
All other
 
 
 
 
 
 
 
Financial data by business segment
 
 
 
 
 
 
 
Operating revenues
 
 
 
 
4,000,000 
8,000,000 
5,000,000 
Other operating expenses
 
 
 
 
3,000,000 
4,000,000 
4,000,000 
Operating margin
 
 
 
 
1,000,000 
4,000,000 
1,000,000 
Interest expense
 
 
 
 
 
2,000,000 
1,000,000 
Other expense (income)
 
 
 
 
3,000,000 
2,000,000 
10,000,000 
INCOME FROM CONTINUING OPERATIONS BEFORE INCOME TAXES
 
 
 
 
(2,000,000)
 
(10,000,000)
Income Taxes
 
 
 
 
(1,000,000)
 
(4,000,000)
INCOME FROM CONTINUING OPERATIONS
 
 
 
 
(1,000,000)
 
(6,000,000)
Income (loss) from discontinued operations - net of income tax expense (benefit)
 
 
 
 
11,000,000 
25,000,000 
(183,000,000)
NET INCOME
 
 
 
 
10,000,000 
25,000,000 
(189,000,000)
Net income attributable to noncontrolling interests
 
 
 
 
 
 
(14,000,000)
Net income attributable to common shareholders
 
 
 
 
10,000,000 
25,000,000 
(175,000,000)
Total assets
43,000,000 
 
 
 
43,000,000 
108,000,000 
295,000,000 
Capital expenditures
 
 
 
 
 
$ 4,000,000 
$ 13,000,000 
Derivative Accounting (Details)
12 Months Ended
Dec. 31, 2011
billionbtu
GWh
Derivative Accounting
 
Maximum hedge period of majority of certain exposures (in months)
39 
Outstanding gross notional amount of derivatives
 
Outstanding gross notional amount of derivative instruments
11,882 
ARIZONA PUBLIC SERVICE COMPANY
 
Derivative Accounting
 
Percentage of unrealized gains and losses on certain derivatives deferred for future rate treatment
90.00% 
Derivative Accounting (Details 2) (Commodity Contracts, USD $)
12 Months Ended
Dec. 31, 2011
Dec. 31, 2010
Designated as Hedging Instruments
 
 
Gains and losses from derivative instruments
 
 
Loss Recognized in AOCI (Effective Portion)
$ (94,660,000)
$ (155,287,000)
Loss Reclassified from AOCI into Income (Effective Portion Realized)
(117,189,000)
(122,740,000)
Gain (Loss) Recognized in Income (Ineffective Portion and Amount Excluded from Effectiveness Testing)
(211,000)
3,680,000 
Estimated net loss before income taxes to be reclassified from AOCI
80,000,000 
 
Not Designated as Hedging Instruments
 
 
Gains and losses from derivative instruments
 
 
Net Gain (Loss) Recognized in Income
(52,140,000)
(106,254,000)
Not Designated as Hedging Instruments |
Fuel and purchased power expense
 
 
Gains and losses from derivative instruments
 
 
Net Gain (Loss) Recognized in Income
(52,113,000)
(107,690,000)
Not Designated as Hedging Instruments |
Regulated electricity segment |
Revenue
 
 
Gains and losses from derivative instruments
 
 
Net Gain (Loss) Recognized in Income
$ (27,000)
$ 1,436,000 
Derivative Accounting (Details 3) (USD $)
Dec. 31, 2011
Dec. 31, 2010
Fair value of derivative instruments, margin account and cash collateral reported on a gross basis
 
 
Assets
$ 79,586,000 
$ 112,820,000 
Liabilities
(136,463,000)
(124,366,000)
Current assets
30,264,000 
73,788,000 
Investments and Other Assets
49,322,000 
39,032,000 
Current Liabilities
(53,968,000)
(58,976,000)
Deferred Credits and Other
(82,495,000)
(65,390,000)
Derivative Instruments
(56,877,000)
(11,546,000)
Credit Risk and Credit-Related Contingent Features
 
 
Risk management assets
79,586,000 
112,820,000 
Commodity Contracts
 
 
Fair value of derivative instruments, margin account and cash collateral reported on a gross basis
 
 
Assets
80,000,000 
 
Margin and Collateral Provided to Counterparties
174,626,000 
228,892,000 
Collateral provided from counterparties
(11,145,000)
(3,000,000)
Other
1,356,000 
2,026,000 
Credit Risk and Credit-Related Contingent Features
 
 
Concentration of credit risk, number of counterparties
 
Concentration of risk with two counterparties, as a percentage of risk management assets
80.00% 
 
Risk management assets
80,000,000 
 
Aggregate Fair Value of Derivative Instruments in a Liability Position
330,000,000 
 
Cash Collateral Posted
147,000,000 
 
Additional Cash Collateral in the Event Credit-Risk Related Contingent Features were Fully Triggered
151,000,000 
 
Additional collateral to counterparties for energy related non-derivative instrument contracts
194,000,000 
 
Collateral Provided to Counterparties, relating to non-derivative instruments or derivative instruments that qualify for a scope exception
 
11,000,000 
Collateral Provided from Counterparties, relating to non-derivative instruments or derivative instruments that qualify for a scope exception
11,000,000 
1,000,000 
Commodity Contracts |
Current Assets
 
 
Fair value of derivative instruments, margin account and cash collateral reported on a gross basis
 
 
Margin and Collateral Provided to Counterparties
1,630,000 
36,135,000 
Collateral provided from counterparties
 
(1,750,000)
Other
(54,815,000)
(35,045,000)
Current assets
30,264,000 
73,788,000 
Commodity Contracts |
Investments and Other Assets
 
 
Fair value of derivative instruments, margin account and cash collateral reported on a gross basis
 
 
Other
(12,755,000)
(26,837,000)
Investments and Other Assets
49,322,000 
39,032,000 
Commodity Contracts |
Total Assets
 
 
Fair value of derivative instruments, margin account and cash collateral reported on a gross basis
 
 
Margin and Collateral Provided to Counterparties
1,630,000 
36,135,000 
Collateral provided from counterparties
 
(1,750,000)
Other
(67,570,000)
(61,882,000)
Commodity Contracts |
Current Liabilities
 
 
Fair value of derivative instruments, margin account and cash collateral reported on a gross basis
 
 
Margin and Collateral Provided to Counterparties
107,228,000 
126,364,000 
Collateral provided from counterparties
(11,145,000)
(1,250,000)
Other
56,172,000 
37,144,000 
Current Liabilities
(53,968,000)
(58,976,000)
Commodity Contracts |
Deferred Credits and Other
 
 
Fair value of derivative instruments, margin account and cash collateral reported on a gross basis
 
 
Margin and Collateral Provided to Counterparties
65,768,000 
66,393,000 
Other
12,754,000 
26,764,000 
Deferred Credits and Other
(82,495,000)
(65,390,000)
Commodity Contracts |
Total Liabilities
 
 
Fair value of derivative instruments, margin account and cash collateral reported on a gross basis
 
 
Margin and Collateral Provided to Counterparties
172,996,000 
192,757,000 
Collateral provided from counterparties
(11,145,000)
(1,250,000)
Other
68,926,000 
63,908,000 
Commodity Contracts |
Designated as Hedging Instruments
 
 
Fair value of derivative instruments, margin account and cash collateral reported on a gross basis
 
 
Total derivatives
(139,241,000)
(166,077,000)
Commodity Contracts |
Designated as Hedging Instruments |
Current Assets
 
 
Fair value of derivative instruments, margin account and cash collateral reported on a gross basis
 
 
Total derivatives
7,287,000 
10,295,000 
Commodity Contracts |
Designated as Hedging Instruments |
Investments and Other Assets
 
 
Fair value of derivative instruments, margin account and cash collateral reported on a gross basis
 
 
Total derivatives
3,804,000 
5,056,000 
Commodity Contracts |
Designated as Hedging Instruments |
Total Assets
 
 
Fair value of derivative instruments, margin account and cash collateral reported on a gross basis
 
 
Total derivatives
11,091,000 
15,351,000 
Commodity Contracts |
Designated as Hedging Instruments |
Current Liabilities
 
 
Fair value of derivative instruments, margin account and cash collateral reported on a gross basis
 
 
Total derivatives
(82,195,000)
(108,387,000)
Commodity Contracts |
Designated as Hedging Instruments |
Deferred Credits and Other
 
 
Fair value of derivative instruments, margin account and cash collateral reported on a gross basis
 
 
Total derivatives
(68,137,000)
(73,041,000)
Commodity Contracts |
Designated as Hedging Instruments |
Total Liabilities
 
 
Fair value of derivative instruments, margin account and cash collateral reported on a gross basis
 
 
Total derivatives
(150,332,000)
(181,428,000)
Commodity Contracts |
Not Designated as Hedging Instruments
 
 
Fair value of derivative instruments, margin account and cash collateral reported on a gross basis
 
 
Total derivatives
(82,473,000)
(73,387,000)
Commodity Contracts |
Not Designated as Hedging Instruments |
Current Assets
 
 
Fair value of derivative instruments, margin account and cash collateral reported on a gross basis
 
 
Total derivatives
76,162,000 
64,153,000 
Commodity Contracts |
Not Designated as Hedging Instruments |
Investments and Other Assets
 
 
Fair value of derivative instruments, margin account and cash collateral reported on a gross basis
 
 
Total derivatives
58,273,000 
60,813,000 
Commodity Contracts |
Not Designated as Hedging Instruments |
Total Assets
 
 
Fair value of derivative instruments, margin account and cash collateral reported on a gross basis
 
 
Total derivatives
134,435,000 
124,966,000 
Commodity Contracts |
Not Designated as Hedging Instruments |
Current Liabilities
 
 
Fair value of derivative instruments, margin account and cash collateral reported on a gross basis
 
 
Total derivatives
(124,028,000)
(112,847,000)
Commodity Contracts |
Not Designated as Hedging Instruments |
Deferred Credits and Other
 
 
Fair value of derivative instruments, margin account and cash collateral reported on a gross basis
 
 
Total derivatives
(92,880,000)
(85,506,000)
Commodity Contracts |
Not Designated as Hedging Instruments |
Total Liabilities
 
 
Fair value of derivative instruments, margin account and cash collateral reported on a gross basis
 
 
Total derivatives
$ (216,908,000)
$ (198,353,000)
Other Income and Other Expense (Details) (USD $)
In Thousands, unless otherwise specified
12 Months Ended
Dec. 31, 2011
Dec. 31, 2010
Dec. 31, 2009
Other income:
 
 
 
Interest income
$ 1,850 
$ 3,255 
$ 1,503 
Investment gains - net
1,165 
2,797 
2,512 
Miscellaneous
96 
335 
1,144 
Total other income
3,111 
6,387 
5,159 
Other expense:
 
 
 
Non-operating costs
(7,037)
(6,831)
(6,675)
Miscellaneous
(3,414)
(3,090)
(7,625)
Total other expense
$ (10,451)
$ (9,921)
$ (14,300)
Palo Verde Sale Leaseback Variable Interest Entities (Details) (USD $)
12 Months Ended
Dec. 31, 2011
trust
Dec. 31, 2010
Dec. 31, 2009
Dec. 31, 2008
trust
Palo Verde Sale Leaseback Variable Interest Entities
 
 
 
 
Increase in net income due to consolidation of Palo Verde Sale Leaseback Trusts
$ 27,467,000 
$ 20,156,000 
$ 4,434,000 
 
Amounts relating to the VIEs included in Condensed Consolidated Balance Sheets
 
 
 
 
Palo Verde sale leaseback property plant and equipment, net of accumulated depreciation
132,864,000 
137,956,000 
 
 
Current maturities of long-term debt
477,435,000 
631,879,000 
 
 
Palo Verde sale leaseback lessor notes long-term debt excluding current maturities
65,547,000 
96,803,000 
 
 
Equity-Noncontrolling interests
108,736,000 
91,899,000 
 
 
ARIZONA PUBLIC SERVICE COMPANY
 
 
 
 
Palo Verde Sale Leaseback Variable Interest Entities
 
 
 
 
Number of VIE lessor trusts
 
 
Annual lease payments
49,000,000 
 
 
 
Increase in net income due to consolidation of Palo Verde Sale Leaseback Trusts
(27,524,000)
(20,163,000)
(19,209,000)
 
Amounts relating to the VIEs included in Condensed Consolidated Balance Sheets
 
 
 
 
Palo Verde sale leaseback property plant and equipment, net of accumulated depreciation
132,864,000 
137,956,000 
 
 
Current maturities of long-term debt
477,435,000 
456,879,000 
 
 
Palo Verde sale leaseback lessor notes long-term debt excluding current maturities
65,547,000 
96,803,000 
 
 
Equity-Noncontrolling interests
108,399,000 
91,084,000 
 
 
ARIZONA PUBLIC SERVICE COMPANY |
Consolidation of VIEs
 
 
 
 
Palo Verde Sale Leaseback Variable Interest Entities
 
 
 
 
Increase in net income due to consolidation of Palo Verde Sale Leaseback Trusts
28,000,000 
20,000,000 
19,000,000 
 
Amounts relating to the VIEs included in Condensed Consolidated Balance Sheets
 
 
 
 
Palo Verde sale leaseback property plant and equipment, net of accumulated depreciation
133,000,000 
137,956,000 
 
 
Current maturities of long-term debt
31,000,000 
29,000,000 
 
 
Palo Verde sale leaseback lessor notes long-term debt excluding current maturities
66,000,000 
96,803,000 
 
 
Equity-Noncontrolling interests
108,000,000 
91,084,000 
 
 
Maximum payment to the VIEs' noncontrolling equity participants upon the occurrence of certain unlikely events
141,000,000 
 
 
 
VIE debt to be assumed upon the occurrence of certain unlikely events
$ 97,000,000 
 
 
 
Discontinued Operations (Details) (USD $)
1 Months Ended 12 Months Ended
Aug. 31, 2011
Jun. 30, 2010
Dec. 31, 2011
Dec. 31, 2010
Dec. 31, 2009
Discontinued Operations
 
 
 
 
 
After-tax gain from discontinued operations
 
 
 
$ 41,973,000 
 
Revenue
 
 
37,000,000 
157,000,000 
154,000,000 
Income (loss) before taxes
 
 
19,000,000 
41,000,000 
(279,000,000)
Income (loss) after taxes
 
 
11,363,000 
25,365,000 
(168,509,000)
Tax benefit in accordance with an intercompany tax sharing agreement
 
 
1,000,000 
4,000,000 
113,000,000 
SunCor
 
 
 
 
 
Discontinued Operations
 
 
 
 
 
Revenue
 
 
1,000,000 
30,000,000 
114,000,000 
Income (loss) before taxes
 
 
(2,000,000)
(10,000,000)
(276,000,000)
Income (loss) after taxes
 
 
(1,000,000)
(6,000,000)
(167,000,000)
Assets
 
 
9,000,000 
 
 
Inter-company receivables
 
 
7,000,000 
 
 
Other assets
 
 
2,000,000 
 
 
APSES
 
 
 
 
 
Discontinued Operations
 
 
 
 
 
After-tax gain from discontinued operations
10,000,000 
25,000,000 
 
 
 
Revenue
 
 
36,000,000 
127,000,000 
40,000,000 
Income (loss) before taxes
 
 
21,000,000 
51,000,000 
(3,000,000)
Income (loss) after taxes
 
 
$ 12,000,000 
$ 31,000,000 
$ (2,000,000)
Real Estate Impairment Charge (Details) (USD $)
12 Months Ended
Dec. 31, 2010
Dec. 31, 2009
Real Estate Impairment Charge
 
 
Real estate impairment charges
$ 16,731,000 
$ 280,188,000 
SunCor
 
 
Real Estate Impairment Charge
 
 
Real estate impairment charges
17,000,000 
280,000,000 
Less noncontrolling interests
 
(14,000,000)
Total
17,000,000 
266,000,000 
SunCor |
Homebuilding and master-planned communities
 
 
Real Estate Impairment Charge
 
 
Real estate impairment charges
1,000,000 
170,000,000 
SunCor |
Land parcels and commercial assets
 
 
Real Estate Impairment Charge
 
 
Real estate impairment charges
11,000,000 
87,000,000 
SunCor |
Golf courses
 
 
Real Estate Impairment Charge
 
 
Real estate impairment charges
1,000,000 
23,000,000 
SunCor |
Other operations
 
 
Real Estate Impairment Charge
 
 
Real estate impairment charges
$ 4,000,000 
 
Nuclear Decommissioning Trust (Details) (USD $)
12 Months Ended
Dec. 31, 2011
Dec. 31, 2010
Dec. 31, 2009
Nuclear decommissioning trust fund assets
 
 
 
Fair Value
$ 513,733,000 
$ 469,886,000 
 
Realized gains and losses and proceeds from the sale of securities by the nuclear decommissioning trust funds
 
 
 
Proceeds from the sale of securities
497,780,000 
560,469,000 
441,242,000 
Fair value of fixed income securities, summarized by contractual maturities
 
 
 
Total
513,733,000 
469,886,000 
 
ARIZONA PUBLIC SERVICE COMPANY
 
 
 
Nuclear decommissioning trust fund assets
 
 
 
Fair Value
513,733,000 
469,886,000 
 
Unrealized Gains
67,000,000 
55,000,000 
 
Unrealized Losses
(2,000,000)
(3,000,000)
 
Net payables for securities purchases
(1,000,000)
(10,000,000)
 
Realized gains and losses and proceeds from the sale of securities by the nuclear decommissioning trust funds
 
 
 
Realized gains
8,000,000 
17,000,000 
10,000,000 
Realized losses
(5,000,000)
(4,000,000)
(7,000,000)
Proceeds from the sale of securities
497,780,000 
560,469,000 
441,242,000 
Fair value of fixed income securities, summarized by contractual maturities
 
 
 
Total
513,733,000 
469,886,000 
 
ARIZONA PUBLIC SERVICE COMPANY |
Equity securities
 
 
 
Nuclear decommissioning trust fund assets
 
 
 
Fair Value
175,000,000 
168,000,000 
 
Unrealized Gains
44,000,000 
43,000,000 
 
Unrealized Losses
(1,000,000)
(1,000,000)
 
Fair value of fixed income securities, summarized by contractual maturities
 
 
 
Total
175,000,000 
168,000,000 
 
ARIZONA PUBLIC SERVICE COMPANY |
Fixed income securities.
 
 
 
Nuclear decommissioning trust fund assets
 
 
 
Fair Value
340,000,000 
312,000,000 
 
Unrealized Gains
23,000,000 
12,000,000 
 
Unrealized Losses
(1,000,000)
(2,000,000)
 
Fair value of fixed income securities, summarized by contractual maturities
 
 
 
Less than one year
13,000,000 
 
 
1 year - 5 years
83,000,000 
 
 
5 years - 10 years
114,000,000 
 
 
Greater than 10 years
130,000,000 
 
 
Total
$ 340,000,000 
$ 312,000,000 
 
SCHEDULE I CONDENSED FINANCIAL INFORMATION OF REGISTRANT (Details) (USD $)
In Thousands, unless otherwise specified
3 Months Ended 12 Months Ended
Dec. 31, 2011
Sep. 30, 2011
Jun. 30, 2011
Mar. 31, 2011
Dec. 31, 2011
Dec. 31, 2010
Dec. 31, 2009
CONDENSED STATEMENTS OF INCOME
 
 
 
 
 
 
 
Operating revenues
$ 667,892 
$ 1,124,841 
$ 799,799 
$ 648,847 
$ 3,241,379 
$ 3,189,199 
$ 3,153,656 
Operating expenses
 
 
 
 
2,494,871 
2,474,316 
2,537,528 
Operating loss
78,715 
435,017 
196,992 
35,784 
746,508 
714,883 
616,128 
Other
 
 
 
 
 
 
 
Total
 
 
 
 
16,367 
18,532 
5,858 
Interest expense
 
 
 
 
241,995 
244,174 
237,766 
INCOME FROM CONTINUING OPERATIONS BEFORE INCOME TAXES
 
 
 
 
539,238 
505,720 
394,599 
Income tax benefit
7,375 
131,416 
50,818 
(6,005)
183,604 
160,869 
138,551 
INCOME FROM CONTINUING OPERATIONS
19,544 
253,273 
93,185 
(10,368)
355,634 
344,851 
256,048 
Income from discontinued operations - net of income taxes
 
 
 
 
11,306 
25,358 
(183,284)
Net income attributable to common shareholders
12,564 
255,359 
86,685 
(15,135)
339,473 
350,053 
68,330 
Pinnacle West
 
 
 
 
 
 
 
CONDENSED STATEMENTS OF INCOME
 
 
 
 
 
 
 
Operating revenues
 
 
 
 
1,034 
2,810 
1,157 
Operating expenses
 
 
 
 
8,811 
9,880 
10,420 
Operating loss
 
 
 
 
(7,777)
(7,070)
(9,263)
Other
 
 
 
 
 
 
 
Equity in earnings (losses) of subsidiaries
 
 
 
 
335,859 
358,527 
(37,214)
Other income (expense)
 
 
 
 
(1,481)
(588)
2,102 
Total
 
 
 
 
334,378 
357,939 
(35,112)
Interest expense
 
 
 
 
8,053 
14,346 
14,129 
INCOME FROM CONTINUING OPERATIONS BEFORE INCOME TAXES
 
 
 
 
318,548 
336,523 
(58,504)
Income tax benefit
 
 
 
 
(8,938)
(9,596)
(14,060)
INCOME FROM CONTINUING OPERATIONS
 
 
 
 
327,486 
346,119 
(44,444)
Income from discontinued operations - net of income taxes
 
 
 
 
11,987 
3,934 
112,774 
Net income attributable to common shareholders
 
 
 
 
$ 339,473 
$ 350,053 
$ 68,330 
SCHEDULE I CONDENSED FINANCIAL INFORMATION OF REGISTRANT (Details 2) (USD $)
In Thousands, unless otherwise specified
Dec. 31, 2011
Dec. 31, 2010
Dec. 31, 2009
Dec. 31, 2008
Current assets
 
 
 
 
Cash and cash equivalents
$ 33,583 
$ 110,188 
$ 145,378 
$ 105,245 
Customer and other receivables
284,183 
324,207 
 
 
Current deferred income taxes
130,571 
124,897 
 
 
Income tax receivable
6,466 
2,483 
 
 
Other current assets
26,904 
28,362 
 
 
Total current assets
956,470 
1,024,511 
 
 
Investments and other assets
 
 
 
 
Other assets
64,588 
116,216 
 
 
Total investments and other assets
627,643 
625,134 
 
 
TOTAL ASSETS
13,111,018 
12,392,998 
12,035,000 
 
Current liabilities
 
 
 
 
Accounts payable
326,987 
236,354 
 
 
Accrued taxes
120,289 
104,711 
 
 
Short-Term Borrowings
 
16,600 
 
 
Current maturities of long-term debt
477,435 
631,879 
 
 
Other current liabilities
148,616 
139,063 
 
 
Total current liabilities
1,342,705 
1,449,704 
 
 
Long-term debt less current maturities
3,019,054 
3,045,794 
 
 
Deferred credits and other
 
 
 
 
Pension and other postretirement liabilities
1,268,910 
813,121 
 
 
Other
217,934 
132,031 
 
 
Total deferred credits and other
4,818,673 
4,122,274 
 
 
Common stock equity
 
 
 
 
Common stock
2,444,247 
2,421,372 
 
 
Accumulated other comprehensive loss
(152,163)
(159,767)
 
 
Retained earnings
1,534,483 
1,423,961 
 
 
Total shareholders' equity
3,821,850 
3,683,327 
 
 
Noncontrolling interests
108,736 
91,899 
 
 
Total equity
3,930,586 
3,775,226 
3,428,004 
 
TOTAL LIABILITIES AND EQUITY
13,111,018 
12,392,998 
 
 
Pinnacle West
 
 
 
 
Current assets
 
 
 
 
Cash and cash equivalents
12,710 
7,725 
17,284 
6,262 
Customer and other receivables
62,418 
75,745 
 
 
Current deferred income taxes
19,068 
19,855 
 
 
Income tax receivable
1,804 
3,736 
 
 
Other current assets
55 
61 
 
 
Total current assets
96,055 
107,122 
 
 
Investments and other assets
 
 
 
 
Investments in subsidiaries
4,026,289 
3,901,935 
 
 
Deferred income taxes
27,220 
 
 
 
Other assets
16,898 
58,071 
 
 
Total investments and other assets
4,070,407 
3,960,006 
 
 
TOTAL ASSETS
4,166,462 
4,067,128 
 
 
Current liabilities
 
 
 
 
Accounts payable
4,811 
4,981 
 
 
Accrued taxes
9,795 
4,216 
 
 
Short-Term Borrowings
 
16,600 
 
 
Current maturities of long-term debt
 
175,000 
 
 
Other current liabilities
28,295 
28,101 
 
 
Total current liabilities
42,901 
228,898 
 
 
Long-term debt less current maturities
125,000 
 
 
 
Deferred credits and other
 
 
 
 
Pension and other postretirement liabilities
32,513 
28,607 
 
 
Other
35,462 
34,397 
 
 
Total deferred credits and other
67,975 
63,004 
 
 
Common stock equity
 
 
 
 
Common stock
2,439,530 
2,419,133 
 
 
Accumulated other comprehensive loss
(152,163)
(159,767)
 
 
Retained earnings
1,534,483 
1,423,961 
 
 
Total shareholders' equity
3,821,850 
3,683,327 
 
 
Noncontrolling interests
108,736 
91,899 
 
 
Total equity
3,930,586 
3,775,226 
 
 
TOTAL LIABILITIES AND EQUITY
$ 4,166,462 
$ 4,067,128 
 
 
SCHEDULE I CONDENSED FINANCIAL INFORMATION OF REGISTRANT (Details 3) (USD $)
In Thousands, unless otherwise specified
12 Months Ended
Dec. 31, 2011
Dec. 31, 2010
Dec. 31, 2009
Cash flows from operating activities
 
 
 
Net Income
$ 366,940 
$ 370,209 
$ 72,764 
Adjustments to reconcile net income to net cash provided by operating activities:
 
 
 
Depreciation and amortization
493,784 
472,807 
450,864 
Gain on sale of energy-related business
(10,404)
 
 
Deferred income taxes
176,192 
260,411 
105,492 
Customer and other receivables
40,626 
(67,943)
12,292 
Accounts payable
58,346 
9,125 
(27,328)
Accrued taxes and income tax receivable - net
12,068 
24,222 
(31,792)
Net cash flow provided by operating activities
1,125,583 
750,457 
1,067,305 
Cash flows from investing activities
 
 
 
Proceeds from sale of energy-related products and services business
45,111 
 
 
Net cash flow used for investing activities
(782,007)
(575,900)
(704,917)
Cash flows from financing activities
 
 
 
Issuance of long-term debt
470,353 
 
867,469 
Short-term borrowings and payments - net
(16,600)
(137,115)
(516,754)
Dividends paid on common stock
(221,728)
(216,979)
(205,076)
Repayment of long-term debt
(655,169)
(106,572)
(456,882)
Common stock equity issuance
15,841 
255,971 
3,302 
Other
(2,668)
6,351 
171 
Net cash flow used for financing activities
(420,181)
(209,747)
(322,255)
Net increase (decrease) in cash and cash equivalents
(76,605)
(35,190)
40,133 
CASH AND CASH EQUIVALENTS AT BEGINNING OF YEAR
110,188 
145,378 
105,245 
CASH AND CASH EQUIVALENTS AT END OF YEAR
33,583 
110,188 
145,378 
Pinnacle West
 
 
 
Cash flows from operating activities
 
 
 
Net Income
339,473 
350,053 
68,330 
Adjustments to reconcile net income to net cash provided by operating activities:
 
 
 
Equity in earnings (losses) of subsidiaries
(335,859)
(358,527)
37,214 
Depreciation and amortization
97 
143 
127 
Gain on sale of energy-related business
(10,404)
 
 
Deferred income taxes
7,387 
40,342 
(106,536)
Customer and other receivables
(24,201)
(18,175)
(2,303)
Accounts payable
(2,677)
7,468 
466 
Accrued taxes and income tax receivable - net
7,512 
59,640 
44,625 
Dividends received from subsidiaries
228,900 
207,000 
170,000 
Other net
19,270 
423 
(2,379)
Net cash flow provided by operating activities
229,498 
288,367 
209,544 
Cash flows from investing activities
 
 
 
Investments in subsidiaries
 
(183,544)
(4,967)
Repayments of loans from subsidiaries
61,143 
98,406 
25,240 
Proceeds from sale of energy-related products and services business
45,111 
 
 
Advances of loans to subsidiaries
(64,970)
(119,293)
(21,587)
Proceeds from sale of life insurance policies
9,357 
 
 
Net cash flow used for investing activities
50,641 
(204,431)
(1,314)
Cash flows from financing activities
 
 
 
Issuance of long-term debt
175,000 
 
 
Short-term borrowings and payments - net
(16,600)
(132,487)
4,566 
Dividends paid on common stock
(221,728)
(216,979)
(205,076)
Repayment of long-term debt
(225,000)
 
 
Common stock equity issuance
15,841 
255,971 
3,302 
Other
(2,667)
 
 
Net cash flow used for financing activities
(275,154)
(93,495)
(197,208)
Net increase (decrease) in cash and cash equivalents
4,985 
(9,559)
11,022 
CASH AND CASH EQUIVALENTS AT BEGINNING OF YEAR
7,725 
17,284 
6,262 
CASH AND CASH EQUIVALENTS AT END OF YEAR
$ 12,710 
$ 7,725 
$ 17,284 
SCHEDULE II RESERVE FOR UNCOLLECTIBLES (Details) (USD $)
In Thousands, unless otherwise specified
12 Months Ended
Dec. 31, 2011
Dec. 31, 2010
Dec. 31, 2009
Changes in reserve for uncollectibles
 
 
 
Additions, Charged to other accounts
$ 0 
 
 
Reserve for uncollectibles. |
Pinnacle West
 
 
 
Changes in reserve for uncollectibles
 
 
 
Balance at beginning of period
4,709 
4,573 
3,383 
Additions, Charged to cost and expenses
5,672 
6,905 
7,617 
Deductions
6,633 
6,769 
6,427 
Balance at end of period
$ 3,748 
$ 4,709 
$ 4,573 
CONSOLIDATED STATEMENTS OF INCOME (APSC) (USD $)
In Thousands, unless otherwise specified
12 Months Ended
Dec. 31, 2011
Dec. 31, 2010
Dec. 31, 2009
ELECTRIC OPERATING REVENUES
$ 3,237,194 
$ 3,180,678 
$ 3,149,187 
OPERATING EXPENSES
 
 
 
Fuel and purchased power
1,009,464 
1,046,815 
1,178,620 
Operations and maintenance
904,286 
870,185 
822,300 
Depreciation and amortization
427,054 
414,479 
407,354 
Income taxes (Notes 4 and S-1)
6,659 
7,509 
5,984 
Taxes other than income taxes
147,408 
135,328 
123,270 
Total
2,494,871 
2,474,316 
2,537,528 
OPERATING INCOME
746,508 
714,883 
616,128 
OTHER INCOME (DEDUCTIONS)
 
 
 
Allowance for equity funds used during construction (Note 1)
23,707 
22,066 
14,999 
Other income (Note S-3)
3,111 
6,387 
5,159 
Other expense (Note S-3)
(10,451)
(9,921)
(14,300)
Total
16,367 
18,532 
5,858 
INTEREST EXPENSE
 
 
 
Allowance for borrowed funds used during construction (Note 1)
(18,358)
(16,479)
(10,379)
Total
223,637 
227,695 
227,387 
NET INCOME
366,940 
370,209 
72,764 
Less: Net income attributable to noncontrolling interests (Note 20)
27,467 
20,156 
4,434 
Net income attributable to common shareholders
339,473 
350,053 
68,330 
ARIZONA PUBLIC SERVICE COMPANY
 
 
 
ELECTRIC OPERATING REVENUES
3,237,241 
3,180,807 
3,149,500 
OPERATING EXPENSES
 
 
 
Fuel and purchased power
1,009,464 
1,046,815 
1,178,620 
Operations and maintenance
895,917 
860,712 
812,903 
Depreciation and amortization
426,958 
414,336 
407,159 
Income taxes (Notes 4 and S-1)
204,066 
175,440 
158,661 
Taxes other than income taxes
146,453 
134,467 
122,358 
Total
2,682,858 
2,631,770 
2,679,701 
OPERATING INCOME
554,383 
549,037 
469,799 
OTHER INCOME (DEDUCTIONS)
 
 
 
Income taxes (Notes 4 and S-1)
11,524 
4,975 
6,087 
Allowance for equity funds used during construction (Note 1)
23,707 
22,066 
14,999 
Other income (Note S-3)
5,071 
8,956 
10,808 
Other expense (Note S-3)
(15,328)
(15,859)
(18,001)
Total
24,974 
20,138 
13,893 
INTEREST EXPENSE
 
 
 
Interest on long-term debt
218,981 
217,002 
212,654 
Interest on short-term borrowings
10,345 
8,267 
6,315 
Debt discount, premium and expense
4,616 
4,559 
4,675 
Allowance for borrowed funds used during construction (Note 1)
(18,358)
(16,479)
(10,386)
Total
215,584 
213,349 
213,258 
NET INCOME
363,773 
355,826 
270,434 
Less: Net income attributable to noncontrolling interests (Note 20)
(27,524)
(20,163)
(19,209)
Net income attributable to common shareholders
$ 336,249 
$ 335,663 
$ 251,225 
CONSOLIDATED BALANCE SHEETS (APSC) (USD $)
In Thousands, unless otherwise specified
Dec. 31, 2011
Dec. 31, 2010
Sep. 30, 2009
PROPERTY, PLANT AND EQUIPMENT (Notes 1, 6, 9 and 10)
 
 
 
Plant in service and held for future use
$ 13,753,971 
$ 13,201,960 
 
Accumulated depreciation and amortization
(4,709,991)
(4,514,204)
 
Net
9,043,980 
8,687,756 
 
Construction work in progress
496,745 
459,361 
 
Palo Verde sale leaseback, net of accumulated depreciation of $218,186 and $213,094 (Note 20)
132,864 
137,956 
 
Intangible assets, net of accumulated amortization of $372,573 and $329,444
170,571 
184,952 
 
Nuclear fuel, net of accumulated amortization of $113,375 and $85,270
118,098 
108,794 
 
Total property, plant and equipment
9,962,258 
9,578,819 
 
INVESTMENTS AND OTHER ASSETS
 
 
 
Nuclear decommissioning trust (Notes 14 and 23)
513,733 
469,886 
 
Assets from risk management activities (Note 18)
49,322 
39,032 
 
Other assets
64,588 
116,216 
 
Total investments and other assets
627,643 
625,134 
 
CURRENT ASSETS
 
 
 
Cash and cash equivalents
33,583 
110,188 
 
Customer and other receivables
284,183 
324,207 
 
Accrued unbilled revenues
125,239 
103,292 
 
Allowance for doubtful accounts
(3,748)
(7,981)
 
Materials and supplies (at average cost)
204,387 
181,414 
 
Fossil fuel (at average cost)
22,000 
21,575 
 
Assets from risk management activities (Note 18)
30,264 
73,788 
 
Deferred fuel and purchased power regulatory asset (Note 3)
27,549 
 
 
Other regulatory assets (Note 3)
69,072 
62,286 
 
Deferred income taxes (Notes 4 and S-1)
130,571 
124,897 
 
Other current assets
26,904 
28,362 
 
Total current assets
956,470 
1,024,511 
 
DEFERRED DEBITS
 
 
 
Regulatory assets (Notes 1, 3, 4 and S-1)
1,352,079 
986,370 
 
Income tax receivable (Note 4 and S-1)
68,633 
65,103 
69,000 
Other
143,935 
113,061 
 
Total deferred debits
1,564,647 
1,164,534 
 
TOTAL ASSETS
13,111,018 
12,392,998 
 
CAPITALIZATION
 
 
 
Common stock
2,439,530 
2,419,133 
 
Retained earnings
1,534,483 
1,423,961 
 
Accumulated other comprehensive (loss):
 
 
 
Pension and other postretirement benefits (Note 8)
(65,447)
(59,420)
 
Derivative instruments
(86,716)
(100,347)
 
Total shareholder equity
3,821,850 
3,683,327 
 
Noncontrolling interests (Note 20)
108,736 
91,899 
 
Total equity
3,930,586 
3,775,226 
 
Long-term debt less current maturities (Note 6)
2,953,507 
2,948,991 
 
Palo Verde sale leaseback lessor notes less current maturities (Notes 6 and 20)
65,547 
96,803 
 
CURRENT LIABILITIES
 
 
 
Current maturities of long-term debt (Note 6)
477,435 
631,879 
 
Accounts payable
326,987 
236,354 
 
Accrued taxes
120,289 
104,711 
 
Accrued interest
54,872 
54,831 
 
Customer deposits
72,176 
68,322 
 
Liabilities from risk management activities (Note 18)
53,968 
58,976 
 
Deferred fuel and purchased power regulatory liability (Note 3)
 
58,442 
 
Other regulatory liabilities (Note 3)
88,362 
80,526 
 
Other current liabilities
148,616 
139,063 
 
Total current liabilities
1,342,705 
1,449,704 
 
DEFERRED CREDITS AND OTHER
 
 
 
Deferred income taxes (Notes 4 and S-1)
1,925,388 
1,863,861 
 
Regulatory liabilities (Notes 1, 3, 4, and S-1)
737,332 
614,063 
 
Liability for asset retirements (Note 12)
279,643 
328,571 
 
Liabilities for pension and other postretirement benefits (Note 8)
1,268,910 
813,121 
 
Liabilities from risk management activities (Note 18)
82,495 
65,390 
 
Customer advances
116,805 
121,645 
 
Coal mine reclamation
117,896 
117,243 
 
Unrecognized tax benefits (Notes 4 and S-1)
72,270 
66,349 
 
Other
217,934 
132,031 
 
Total deferred credits and other
4,818,673 
4,122,274 
 
COMMITMENTS AND CONTINGENCIES (SEE NOTES)
   
   
 
TOTAL LIABILITIES AND EQUITY
13,111,018 
12,392,998 
 
ARIZONA PUBLIC SERVICE COMPANY
 
 
 
PROPERTY, PLANT AND EQUIPMENT (Notes 1, 6, 9 and 10)
 
 
 
Plant in service and held for future use
13,750,105 
13,197,254 
 
Accumulated depreciation and amortization
(4,706,462)
(4,510,591)
 
Net
9,043,643 
8,686,663 
 
Construction work in progress
496,745 
459,316 
 
Palo Verde sale leaseback, net of accumulated depreciation of $218,186 and $213,094 (Note 20)
132,864 
137,956 
 
Intangible assets, net of accumulated amortization of $372,573 and $329,444
170,416 
184,768 
 
Nuclear fuel, net of accumulated amortization of $113,375 and $85,270
118,098 
108,794 
 
Total property, plant and equipment
9,961,766 
9,577,497 
 
INVESTMENTS AND OTHER ASSETS
 
 
 
Nuclear decommissioning trust (Notes 14 and 23)
513,733 
469,886 
 
Assets from risk management activities (Note 18)
49,322 
39,032 
 
Other assets
30,551 
71,428 
 
Total investments and other assets
593,606 
580,346 
 
CURRENT ASSETS
 
 
 
Cash and cash equivalents
19,873 
99,937 
 
Customer and other receivables
280,100 
288,323 
 
Accrued unbilled revenues
125,239 
103,292 
 
Allowance for doubtful accounts
(3,748)
(7,646)
 
Materials and supplies (at average cost)
204,387 
181,414 
 
Fossil fuel (at average cost)
22,000 
21,575 
 
Assets from risk management activities (Note 18)
30,264 
73,788 
 
Deferred fuel and purchased power regulatory asset (Note 3)
27,549 
 
 
Other regulatory assets (Note 3)
69,072 
62,286 
 
Deferred income taxes (Notes 4 and S-1)
111,503 
105,042 
 
Other current assets
29,355 
25,135 
 
Total current assets
915,594 
953,146 
 
DEFERRED DEBITS
 
 
 
Regulatory assets (Notes 1, 3, 4 and S-1)
1,352,079 
986,370 
 
Income tax receivable (Note 4 and S-1)
69,028 
65,498 
69,000 
Unamortized debt issue costs
21,181 
20,530 
 
Other
118,983 
88,490 
 
Total deferred debits
1,561,271 
1,160,888 
 
TOTAL ASSETS
13,032,237 
12,271,877 
 
CAPITALIZATION
 
 
 
Common stock
178,162 
178,162 
 
Additional paid-in capital
2,379,696 
2,379,696 
 
Retained earnings
1,510,740 
1,403,390 
 
Accumulated other comprehensive (loss):
 
 
 
Pension and other postretirement benefits (Note 8)
(38,886)
(35,961)
 
Derivative instruments
(86,705)
(100,334)
 
Total shareholder equity
3,943,007 
3,824,953 
 
Noncontrolling interests (Note 20)
108,399 
91,084 
 
Total equity
4,051,406 
3,916,037 
 
Long-term debt less current maturities (Note 6)
2,828,507 
2,948,991 
 
Palo Verde sale leaseback lessor notes less current maturities (Notes 6 and 20)
65,547 
96,803 
 
Total capitalization
6,945,460 
6,961,831 
 
CURRENT LIABILITIES
 
 
 
Current maturities of long-term debt (Note 6)
477,435 
456,879 
 
Accounts payable
322,047 
218,491 
 
Accrued taxes
113,930 
106,431 
 
Accrued interest
54,611 
54,638 
 
Customer deposits
72,176 
68,312 
 
Liabilities from risk management activities (Note 18)
53,968 
58,976 
 
Deferred fuel and purchased power regulatory liability (Note 3)
 
58,442 
 
Other regulatory liabilities (Note 3)
88,362 
80,526 
 
Other current liabilities
140,185 
132,170 
 
Total current liabilities
1,322,714 
1,234,865 
 
DEFERRED CREDITS AND OTHER
 
 
 
Deferred income taxes (Notes 4 and S-1)
1,952,608 
1,895,654 
 
Regulatory liabilities (Notes 1, 3, 4, and S-1)
737,332 
614,063 
 
Liability for asset retirements (Note 12)
279,643 
328,571 
 
Liabilities for pension and other postretirement benefits (Note 8)
1,222,542 
770,611 
 
Liabilities from risk management activities (Note 18)
82,495 
65,390 
 
Customer advances
116,805 
121,645 
 
Coal mine reclamation
117,896 
117,243 
 
Unrecognized tax benefits (Notes 4 and S-1)
72,073 
65,363 
 
Other
182,669 
96,641 
 
Total deferred credits and other
4,764,063 
4,075,181 
 
COMMITMENTS AND CONTINGENCIES (SEE NOTES)
   
   
 
TOTAL LIABILITIES AND EQUITY
$ 13,032,237 
$ 12,271,877 
 
CONSOLIDATED BALANCE SHEETS (APSC) (Parenthetical) (USD $)
In Thousands, unless otherwise specified
Dec. 31, 2011
Dec. 31, 2010
PROPERTY, PLANT AND EQUIPMENT (Notes 1, 6, 9 and 10)
 
 
Accumulated depreciation of Palo Verde sale leaseback
$ 218,186 
$ 213,094 
Accumulated amortization on intangible assets
373,706 
330,584 
Accumulated amortization on nuclear fuel
113,375 
85,270 
ARIZONA PUBLIC SERVICE COMPANY
 
 
PROPERTY, PLANT AND EQUIPMENT (Notes 1, 6, 9 and 10)
 
 
Accumulated depreciation of Palo Verde sale leaseback
218,186 
213,094 
Accumulated amortization on intangible assets
372,573 
329,444 
Accumulated amortization on nuclear fuel
$ 113,375 
$ 85,270 
CONSOLIDATED STATEMENTS OF CASH FLOWS (APSC) (USD $)
In Thousands, unless otherwise specified
12 Months Ended
Dec. 31, 2011
Dec. 31, 2010
Dec. 31, 2009
CASH FLOWS FROM OPERATING ACTIVITIES
 
 
 
Net income
$ 366,940 
$ 370,209 
$ 72,764 
Adjustments to reconcile net income to net cash provided by operating activities:
 
 
 
Depreciation and amortization including nuclear fuel
493,784 
472,807 
450,864 
Deferred fuel and purchased power
69,166 
93,631 
(51,742)
Deferred fuel and purchased power amortization
(155,157)
(122,481)
147,018 
Allowance for equity funds used during construction
(23,707)
(22,066)
(14,999)
Deferred income taxes
176,192 
260,411 
105,492 
Change in mark-to-market valuations
4,064 
2,688 
(6,939)
Changes in current assets and liabilities:
 
 
 
Customer and other receivables
40,626 
(67,943)
12,292 
Accrued unbilled revenues
(21,947)
7,679 
(10,882)
Materials, supplies and fossil fuel
(23,398)
12,276 
(12,261)
Other current assets
(3,079)
9,375 
38,406 
Accounts payable
58,346 
9,125 
(27,328)
Accrued taxes
12,068 
24,222 
(31,792)
Other current liabilities
20,358 
2,921 
57,280 
Change in margin and collateral accounts - assets
33,349 
(9,937)
(12,806)
Change in margin and collateral accounts - liabilities
29,731 
(88,315)
35,654 
Change in long-term regulatory liabilities
37,009 
56,801 
82,650 
Change in long-term income tax receivable
(3,530)
 
(131,984)
Change in unrecognized tax benefits
8,410 
(73,621)
137,898 
Change in other long-term assets
(41,722)
(47,940)
(64,629)
Change in other long-term liabilities
58,484 
(97,388)
12,161 
Net cash flow provided by operating activities
1,125,583 
750,457 
1,067,305 
CASH FLOWS FROM INVESTING ACTIVITIES
 
 
 
Capital expenditures
(884,350)
(748,374)
(764,609)
Contributions in aid of construction
38,096 
32,754 
53,525 
Allowance for borrowed funds used during construction
(18,358)
(16,778)
(10,745)
Proceeds from nuclear decommissioning trust sales
497,780 
560,469 
441,242 
Investment in nuclear decommissioning trust
(513,799)
(584,885)
(463,033)
Proceeds from sale of life insurance policies
55,444 
 
 
Other
(3,306)
8,576 
(4,667)
Net cash flow used for investing activities
(782,007)
(575,900)
(704,917)
CASH FLOWS FROM FINANCING ACTIVITIES
 
 
 
Issuance of long-term debt
470,353 
 
867,469 
Repayment of long-term debt
(655,169)
(106,572)
(456,882)
Short-term borrowings and payments - net
(16,600)
(137,115)
(516,754)
Dividends paid on common stock
(221,728)
(216,979)
(205,076)
Noncontrolling interests
(10,210)
(11,403)
(14,485)
Net cash flow provided by (used for) financing activities
(420,181)
(209,747)
(322,255)
NET INCREASE (DECREASE) IN CASH AND CASH EQUIVALENTS
(76,605)
(35,190)
40,133 
CASH AND CASH EQUIVALENTS AT BEGINNING OF YEAR
110,188 
145,378 
105,245 
CASH AND CASH EQUIVALENTS AT END OF YEAR
33,583 
110,188 
145,378 
Cash paid during the year for:
 
 
 
Income taxes, net of refunds
10,324 
(23,447)
(52,776)
Interest, net of amounts capitalized
217,789 
221,728 
216,608 
ARIZONA PUBLIC SERVICE COMPANY
 
 
 
CASH FLOWS FROM OPERATING ACTIVITIES
 
 
 
Net income
363,773 
355,826 
270,434 
Adjustments to reconcile net income to net cash provided by operating activities:
 
 
 
Depreciation and amortization including nuclear fuel
493,653 
471,226 
445,988 
Deferred fuel and purchased power
69,166 
93,631 
(51,742)
Deferred fuel and purchased power amortization
(155,157)
(122,481)
147,018 
Allowance for equity funds used during construction
(23,707)
(22,066)
(14,999)
Deferred income taxes
168,805 
224,095 
192,914 
Change in mark-to-market valuations
4,064 
2,688 
(6,939)
Changes in current assets and liabilities:
 
 
 
Customer and other receivables
34,913 
(49,956)
2,603 
Accrued unbilled revenues
(21,947)
7,679 
(10,882)
Materials, supplies and fossil fuel
(23,398)
12,276 
(12,261)
Income tax receivable
(2,869)
 
 
Other current assets
(5,473)
4,718 
4,332 
Accounts payable
73,369 
18,066 
(22,129)
Accrued taxes
7,972 
(51,620)
(61,078)
Other current liabilities
18,762 
(2,853)
54,913 
Change in margin and collateral accounts - assets
33,349 
(9,937)
(13,206)
Change in margin and collateral accounts - liabilities
29,731 
(88,315)
35,654 
Change in long-term regulatory liabilities
37,009 
56,801 
82,650 
Change in long-term income tax receivable
(3,530)
 
(132,379)
Change in unrecognized tax benefits
9,125 
(73,189)
137,478 
Change in other long-term assets
(41,788)
(46,118)
(67,507)
Change in other long-term liabilities
61,990 
(85,136)
14,097 
Net cash flow provided by operating activities
1,127,812 
695,335 
994,959 
CASH FLOWS FROM INVESTING ACTIVITIES
 
 
 
Capital expenditures
(878,546)
(747,967)
(754,301)
Contributions in aid of construction
38,096 
32,754 
53,525 
Allowance for borrowed funds used during construction
(18,358)
(16,479)
(10,386)
Proceeds from nuclear decommissioning trust sales
497,780 
560,469 
441,242 
Investment in nuclear decommissioning trust
(513,799)
(584,885)
(463,033)
Proceeds from sale of life insurance policies
44,183 
 
 
Other
(3,306)
8,576 
(4,667)
Net cash flow used for investing activities
(833,950)
(747,532)
(737,620)
CASH FLOWS FROM FINANCING ACTIVITIES
 
 
 
Issuance of long-term debt
295,353 
 
863,780 
Repayment of long-term debt
(430,169)
(27,694)
(365,696)
Short-term borrowings and payments - net
 
 
(521,684)
Dividends paid on common stock
(228,900)
(182,400)
(170,000)
Noncontrolling interests
(10,210)
(11,403)
(14,485)
Net cash flow provided by (used for) financing activities
(373,926)
31,336 
(208,085)
NET INCREASE (DECREASE) IN CASH AND CASH EQUIVALENTS
(80,064)
(20,861)
49,254 
CASH AND CASH EQUIVALENTS AT BEGINNING OF YEAR
99,937 
120,798 
71,544 
CASH AND CASH EQUIVALENTS AT END OF YEAR
19,873 
99,937 
120,798 
Cash paid during the year for:
 
 
 
Income taxes, net of refunds
25,975 
81,339 
13,555 
Interest, net of amounts capitalized
$ 210,995 
$ 208,251 
$ 194,346 
CONSOLIDATED STATEMENTS OF CHANGES IN EQUITY (APSC) (USD $)
In Thousands, unless otherwise specified
Total
ARIZONA PUBLIC SERVICE COMPANY
COMMON STOCK (Note 7)
COMMON STOCK (Note 7)
ARIZONA PUBLIC SERVICE COMPANY
ADDITIONAL PAID-IN CAPITAL
ARIZONA PUBLIC SERVICE COMPANY
RETAINED EARNINGS
RETAINED EARNINGS
ARIZONA PUBLIC SERVICE COMPANY
ACCUMULATED OTHER COMPREHENSIVE INCOME (LOSS)
ACCUMULATED OTHER COMPREHENSIVE INCOME (LOSS)
ARIZONA PUBLIC SERVICE COMPANY
NONCONTROLLING INTERESTS
NONCONTROLLING INTERESTS
ARIZONA PUBLIC SERVICE COMPANY
COMPREHENSIVE INCOME ATTRIBUTABLE TO COMMON SHAREHOLDERS
COMPREHENSIVE INCOME ATTRIBUTABLE TO COMMON SHAREHOLDERS
ARIZONA PUBLIC SERVICE COMPANY
TREASURY STOCK (Note 7)
Balance at Dec. 31, 2008
 
 
$ 2,151,323 
$ 178,162 
$ 2,117,789 
$ 1,444,208 
$ 1,168,901 
$ (146,698)
$ (125,702)
$ 124,990 
$ 77,601 
 
 
$ (2,854)
Increase (Decrease) in Shareholders' Equity
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Net income attributable to common shareholders
68,330 
251,225 
 
 
 
68,330 
251,225 
 
 
 
 
68,330 
251,225 
 
Dividends on common stock
 
(170,000)
 
 
 
(212,386)
(170,000)
 
 
 
 
 
 
 
Pension and other postretirement benefits (Note 8):
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Unrealized actuarial loss, net of tax benefit of $(3,828), $(6,344) and $(2,938)
 
(4,571)
 
 
 
 
 
(6,350)
(4,571)
 
 
 
 
 
Amortization to income:
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Actuarial loss, net of tax benefit of $1,724, $1,658 and $1,387
 
(2,126)
 
 
 
 
 
2,615 
2,126 
 
 
 
 
 
Prior service cost, net of tax benefit of $194, $193 and $190
 
291 
 
 
 
 
 
329 
291 
 
 
 
 
 
Derivative instruments:
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Net unrealized loss, net of tax benefit of $(37,397), $(61,358) and $(61,317)
 
(94,008)
 
 
 
 
 
(93,996)
(94,008)
 
 
 
 
 
Reclassification of net realized (gain) loss to income, net of tax (expense) benefit of $46,298, $48,462 and $73,261
 
112,068 
 
 
 
 
 
112,452 
112,068 
 
 
 
 
 
Net income attributable to noncontrolling interests
(4,434)
19,209 
 
 
 
 
 
 
 
4,434 
19,209 
 
 
 
COMPREHENSIVE INCOME ATTRIBUTABLE TO COMMON SHAREHOLDERS
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Other comprehensive income (loss)
15,111 
 
 
 
 
 
 
 
 
 
 
15,111 
15,906 
 
Total comprehensive income attributable to common shareholders
 
 
 
 
 
 
 
 
 
 
 
68,330 
267,131 
 
Net capital activities by noncontrolling interests
 
(14,486)
 
 
 
 
 
 
 
(17,529)
(14,486)
 
 
 
Other
 
9,074 
(8,648)
 
9,074 
(1,939)
 
 
 
 
 
 
 
 
Balance at Dec. 31, 2009
3,428,004 
3,527,679 
2,153,295 
178,162 
2,126,863 
1,298,213 
1,250,126 
(131,587)
(109,796)
111,895 
82,324 
 
 
(3,812)
Increase (Decrease) in Shareholders' Equity
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Net income attributable to common shareholders
 
10,984 
 
 
 
 
 
 
 
 
 
 
 
 
Balance at Mar. 31, 2010
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Balance at Dec. 31, 2009
3,428,004 
3,527,679 
2,153,295 
178,162 
2,126,863 
1,298,213 
1,250,126 
(131,587)
(109,796)
111,895 
82,324 
 
 
(3,812)
Increase (Decrease) in Shareholders' Equity
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Equity infusion
 
252,833 
 
 
252,833 
 
 
 
 
 
 
 
 
 
Net income attributable to common shareholders
350,053 
335,663 
 
 
 
350,053 
335,663 
 
 
 
 
350,053 
335,663 
 
Dividends on common stock
 
(182,400)
 
 
 
(224,305)
(182,400)
 
 
 
 
 
 
 
Pension and other postretirement benefits (Note 8):
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Unrealized actuarial loss, net of tax benefit of $(3,828), $(6,344) and $(2,938)
 
(9,684)
 
 
 
 
 
(11,795)
(9,684)
 
 
 
 
 
Amortization to income:
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Actuarial loss, net of tax benefit of $1,724, $1,658 and $1,387
 
(2,541)
 
 
 
 
 
2,868 
2,541 
 
 
 
 
 
Prior service cost, net of tax benefit of $194, $193 and $190
 
295 
 
 
 
 
 
308 
295 
 
 
 
 
 
Derivative instruments:
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Net unrealized loss, net of tax benefit of $(37,397), $(61,358) and $(61,317)
 
(93,929)
 
 
 
 
 
(93,939)
(93,929)
 
 
 
 
 
Reclassification of net realized (gain) loss to income, net of tax (expense) benefit of $46,298, $48,462 and $73,261
 
74,278 
 
 
 
 
 
74,287 
74,278 
 
 
 
 
 
Net income attributable to noncontrolling interests
(20,156)
20,163 
 
 
 
 
 
 
 
20,156 
20,163 
 
 
 
COMPREHENSIVE INCOME ATTRIBUTABLE TO COMMON SHAREHOLDERS
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Other comprehensive income (loss)
(28,180)
 
 
 
 
 
 
 
 
 
 
(28,180)
(26,499)
 
Total comprehensive income attributable to common shareholders
 
 
 
 
 
 
 
 
 
 
 
 
309,164 
 
Net capital activities by noncontrolling interests
 
(11,403)
 
 
 
 
 
 
 
(40,152)
(11,403)
 
 
 
Other
 
 
4,780 
 
 
 
 
 
 
 
 
 
 
Balance at Dec. 31, 2010
3,775,226 
3,916,037 
2,421,372 
178,162 
2,379,696 
1,423,961 
1,403,390 
(159,767)
(136,295)
91,899 
91,084 
 
 
(2,239)
Balance at Sep. 30, 2010
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Increase (Decrease) in Shareholders' Equity
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Net income attributable to common shareholders
 
7,811 
 
 
 
 
 
 
 
 
 
 
 
 
Balance at Dec. 31, 2010
3,775,226 
3,916,037 
 
178,162 
 
 
 
 
 
 
 
 
 
(2,239)
Increase (Decrease) in Shareholders' Equity
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Net income attributable to common shareholders
(15,135)
(12,081)
 
 
 
 
 
 
 
 
 
 
 
 
Balance at Mar. 31, 2011
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Balance at Dec. 31, 2010
3,775,226 
3,916,037 
2,421,372 
178,162 
2,379,696 
1,423,961 
1,403,390 
(159,767)
(136,295)
91,899 
91,084 
 
 
(2,239)
Increase (Decrease) in Shareholders' Equity
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Equity infusion
 
 
 
 
 
 
 
 
 
 
 
 
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)
 
 
 
 
 
 
 
Pension and other postretirement benefits (Note 8):
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Unrealized actuarial loss, net of tax benefit of $(3,828), $(6,344) and $(2,938)
 
 
 
 
 
 
 
(9,296)
(5,860)
 
 
 
 
 
Amortization to income:
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Actuarial loss, net of tax benefit of $1,724, $1,658 and $1,387
 
 
 
 
 
 
 
2,990 
2,639 
 
 
 
 
 
Prior service cost, net of tax benefit of $194, $193 and $190
 
 
 
 
 
 
275 
296 
 
 
 
 
 
Derivative instruments:
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Net unrealized loss, net of tax benefit of $(37,397), $(61,358) and $(61,317)
 
 
 
 
 
 
 
(57,271)
(57,262)
 
 
 
 
 
Reclassification of net realized (gain) loss to income, net of tax (expense) benefit of $46,298, $48,462 and $73,261
 
 
 
 
 
 
 
70,901 
70,891 
 
 
 
 
 
Net income attributable to noncontrolling interests
(27,467)
27,524 
 
 
 
 
 
 
 
27,467 
27,524 
 
 
 
COMPREHENSIVE INCOME ATTRIBUTABLE TO COMMON SHAREHOLDERS
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Other comprehensive income (loss)
7,605 
 
 
 
 
 
 
 
 
 
 
7,605 
10,704 
 
Total comprehensive income attributable to common shareholders
 
 
 
 
 
 
 
 
 
 
 
346,953 
 
Net capital activities by noncontrolling interests
 
 
 
 
 
 
 
 
 
(10,630)
(10,209)
 
 
 
Other
 
 
11,818 
 
 
 
 
 
 
 
 
 
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 
 
 
(4,717)
Balance at Sep. 30, 2011
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Increase (Decrease) in Shareholders' Equity
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Net income attributable to common shareholders
12,564 
14,292 
 
 
 
 
 
 
 
 
 
 
 
 
Balance at Dec. 31, 2011
$ 3,930,586 
$ 4,051,406 
 
$ 178,162 
 
 
 
 
 
 
 
 
 
$ (4,717)
CONSOLIDATED STATEMENTS OF CHANGES IN EQUITY (APSC) (Parenthetical) (USD $)
In Thousands, unless otherwise specified
12 Months Ended
Dec. 31, 2011
Dec. 31, 2010
Dec. 31, 2009
Pension and other postretirement benefits (Note 8):
 
 
 
Unrealized actuarial loss, net of tax benefit
$ (6,067)
$ (7,738)
$ (4,223)
Amortization to income:
 
 
 
Actuarial loss, net of tax benefit
1,950 
1,870 
1,705 
Prior service cost, tax benefit
179 
201 
215 
Derivative instruments:
 
 
 
Net unrealized gain (loss), net of tax
(37,389)
(61,348)
(61,329)
Reclassification of net realized (gain) loss to income, net of tax (expense) benefit
46,288 
48,453 
72,877 
ARIZONA PUBLIC SERVICE COMPANY
 
 
 
Pension and other postretirement benefits (Note 8):
 
 
 
Unrealized actuarial loss, net of tax benefit
(3,828)
(6,344)
(2,938)
Amortization to income:
 
 
 
Actuarial loss, net of tax benefit
1,724 
1,658 
1,387 
Prior service cost, tax benefit
194 
193 
190 
Derivative instruments:
 
 
 
Net unrealized gain (loss), net of tax
(37,397)
(61,358)
(61,317)
Reclassification of net realized (gain) loss to income, net of tax (expense) benefit
$ 46,298 
$ 48,462 
$ 73,261 
Income Taxes (APSC)

 

 

4.                                      Income Taxes

 

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 the 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 investment tax credits 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 $69 million long-term income tax receivable on the Consolidated Balance Sheets represents the anticipated refunds related to an APS tax accounting method change approved by the IRS in the third quarter of 2009.  This amount is classified as long-term, as cash refunds are not expected to be received in the next twelve months.

 

During the first quarter of 2010, the Company reached a settlement with the IRS with regard to the examination of tax returns for the years ended December 31, 2005 through 2007.  As a result of this settlement, net uncertain tax positions decreased $62 million, including approximately $3 million which decreased our effective tax rate.  Additionally, the settlement resulted in the recognition of net interest benefits of approximately $4 million through the effective tax rate.

 

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):

 

 

 

2011

 

2010

 

2009

 

Total unrecognized tax benefits, January 1

 

$

127,595

 

$

201,216

 

$

63,318

 

Additions for tax positions of the current year

 

10,915

 

7,551

 

44,094

 

Additions for tax positions of prior years

 

 

 

98,942

 

Reductions for tax positions of prior years for:

 

 

 

 

 

 

 

Changes in judgment

 

(1,555

)

(11,017

)

 

Settlements with taxing authorities

 

(124

)

(62,199

)

(4,089

)

Lapses of applicable statute of limitations

 

(826

)

(7,956

)

(1,049

)

Total unrecognized tax benefits, December 31

 

$

136,005

 

$

127,595

 

$

201,216

 

 

Included in the balances of unrecognized tax benefits at December 31, 2011, 2010 and 2009 were approximately $8 million, $7 million and $16 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, 2008 and all subsequent tax years remain subject to examination by the IRS.  With few exceptions, we are no longer subject to state income tax examinations by tax authorities for years prior to 2006.  We do not anticipate that there will be any significant increases or decreases in our unrecognized tax benefits within the next twelve months.

 

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 Statement of Income related to unrecognized tax benefits was a pre-tax expense of $3 million for 2011, a pre-tax benefit of $2 million for 2010 and a pre-tax expense of $2 million for 2009.

 

The total amount of accrued liabilities for interest recognized in the Consolidated Balance Sheets related to unrecognized tax benefits was $9 million as of December 31, 2011, $6 million as of December 31, 2010 and $8 million as of December 31, 2009.  To the extent that matters are settled favorably, this amount could reverse and decrease our effective tax rate.  Additionally, as of December 31, 2011, we have recognized $4 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,

 

 

 

2011

 

2010

 

2009

 

Current:

 

 

 

 

 

 

 

Federal

 

$

(310

)

$

(108,827

)

$

(38,502

)

State

 

15,140

 

25,545

 

(38,080

)

Total current

 

14,830

 

(83,282

)

(76,582

)

Deferred:

 

 

 

 

 

 

 

Federal

 

159,566

 

260,236

 

62,874

 

State

 

16,626

 

10,911

 

42,618

 

Discontinued operations

 

 

(10,736

)

 

Total deferred

 

176,192

 

260,411

 

105,492

 

Total income tax expense

 

191,022

 

177,129

 

28,910

 

Less: income tax expense (benefit) on discontinued operations

 

7,418

 

16,260

 

(109,641

)

Income tax expense — continuing operations

 

$

183,604

 

$

160,869

 

$

138,551

 

 

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,

 

 

 

2011

 

2010

 

2009

 

 

 

 

 

 

 

 

 

Federal income tax expense at 35% statutory rate

 

$

188,733

 

$

177,002

 

$

138,110

 

Increases (reductions) in tax expense resulting from:

 

 

 

 

 

 

 

State income tax net of federal income tax benefit

 

19,594

 

17,485

 

15,068

 

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

 

 

(17,300

)

 

Medicare Subsidy Part-D

 

823

 

1,311

 

(2,095

)

Allowance for equity funds used during construction (see Note 1)

 

(6,881

)

(6,563

)

(4,265

)

Palo Verde VIE noncontrolling interest (see Note 20)

 

(9,636

)

(7,057

)

(6,723

)

Other

 

(9,029

)

(4,009

)

(1,544

)

Income tax expense — continuing operations

 

$

183,604

 

$

160,869

 

$

138,551

 

 

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

 

 

 

December 31,

 

 

 

2011

 

2010

 

Current asset

 

$

130,571

 

$

124,897

 

Long-term liability

 

(1,925,388

)

(1,863,861

)

Deferred income taxes — net

 

$

(1,794,817

)

$

(1,738,964

)

 

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. In 2011, APS increased regulatory liabilities by a total of $62 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,

 

 

 

2011

 

2010

 

DEFERRED TAX ASSETS

 

 

 

 

 

Risk management activities

 

$

117,765

 

$

124,731

 

Regulatory liabilities:

 

 

 

 

 

Asset retirement obligation and removal costs

 

236,739

 

222,448

 

Deferred fuel and purchased power

 

 

23,089

 

Renewable energy standard

 

19,722

 

18,749

 

Unamortized investment tax credits

 

31,460

 

642

 

Other

 

33,155

 

27,718

 

Pension and other postretirement liabilities

 

501,202

 

321,182

 

Real estate investments and assets held for sale

 

 

19,855

 

Renewable energy incentives

 

57,901

 

37,327

 

Credit and loss carryforwards

 

171,915

 

42,971

 

Other

 

73,759

 

68,684

 

Total deferred tax assets

 

1,243,618

 

907,396

 

DEFERRED TAX LIABILITIES

 

 

 

 

 

Plant-related

 

(2,446,908

)

(2,210,976

)

Risk management activities

 

(30,171

)

(30,125

)

Regulatory assets:

 

 

 

 

 

Allowance for equity funds used during construction

 

(33,347

)

(28,276

)

Deferred fuel and purchased power

 

(10,884

)

 

Deferred fuel and purchased power — mark-to-market

 

(30,559

)

(30,276

)

Pension and other postretirement benefits

 

(408,716

)

(264,313

)

Other

 

(73,087

)

(77,078

)

Other

 

(4,763

)

(5,316

)

Total deferred tax liabilities

 

(3,038,435

)

(2,646,360

)

Deferred income taxes — net

 

$

(1,794,817

)

$

(1,738,964

)

 

As of December 31, 2011, the deferred tax assets for credit and loss carryforwards relate to federal general business credits ($67 million) and federal net operating losses ($92 million), both of which first begin to expire in 2029, and other federal and state loss carryforwards ($13 million) which first begin to expire in 2014.

 

 

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 investment tax credits 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.

 

During the first quarter of 2010, the Company reached a settlement with the IRS with regard to the examination of tax returns for the years ended December 31, 2005 through 2007.  As a result of this settlement, net uncertain tax positions decreased $62 million, including approximately $3 million which decreased our effective tax rate.  Additionally, the settlement resulted in the recognition of net interest benefits of approximately $4 million through the effective tax rate.

 

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):

 

 

 

2011

 

2010

 

2009

 

Total unrecognized tax benefits, January 1

 

$

126,698

 

$

199,887

 

$

62,409

 

Additions for tax positions of the current year

 

10,915

 

7,551

 

44,094

 

Additions for tax positions of prior years

 

 

 

98,269

 

Reductions for tax positions of prior years for:

 

 

 

 

 

 

 

Changes in judgment

 

(1,555

)

(10,964

)

 

Settlements with taxing authorities

 

(124

)

(61,820

)

(4,089

)

Lapses of applicable statute of limitations

 

(110

)

(7,956

)

(796

)

Total unrecognized tax benefits, December 31

 

$

135,824

 

$

126,698

 

$

199,887

 

 

Included in the balance of unrecognized tax benefits at December 31, 2011, 2010 and 2009 were approximately $8 million, $6 million and $15 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, 2008 and all subsequent tax years remain subject to examination by the IRS.  With few exceptions, we are no longer subject to state income tax examinations by tax authorities for years prior to 2006.  We do not anticipate that there will be any significant increases or decreases in our unrecognized tax benefits within the next twelve months.

 

We reflect interest and penalties, if any, on unrecognized tax benefits in the statement 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 expense of $3 million for 2011, a pre-tax benefit of $2 million for 2010 and a pre-tax expense of $2 million for 2009.

 

The total amount of accrued liabilities for interest recognized in the Balance Sheets related to unrecognized tax benefits was $9 million as of December 31, 2011, $6 million as of December 31, 2010 and $8 million as of December 31, 2009.  To the extent that matters are settled favorably, this amount could reverse and decrease our effective tax rate.  Additionally, as of December 31, 2011, we have recognized $4 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,

 

 

 

2011

 

2010

 

2009

 

Current:

 

 

 

 

 

 

 

Federal

 

$

4,633

 

$

(71,036

)

$

(8,667

)

State

 

19,104

 

17,406

 

(31,673

)

Total current

 

23,737

 

(53,630

)

(40,340

)

Deferred:

 

 

 

 

 

 

 

Federal

 

154,632

 

207,334

 

163,572

 

State

 

14,173

 

16,761

 

29,342

 

Total deferred

 

168,805

 

224,095

 

192,914

 

Total income tax expense

 

$

192,542

 

$

170,465

 

$

152,574

 

 

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,

 

 

 

2011

 

2010

 

2009

 

 

 

 

 

 

 

 

 

Federal income tax expense at 35% statutory rate

 

$

194,710

 

$

184,202

 

$

148,053

 

Increases (reductions) in tax expense resulting from:

 

 

 

 

 

 

 

State income tax net of federal income tax benefit

 

21,139

 

19,186

 

16,691

 

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

 

 

(17,300

)

 

Medicare Subsidy Part-D

 

823

 

889

 

(2,025

)

Allowance for equity funds used during construction (see Note 1)

 

(6,880

)

(6,563

)

(4,265

)

Palo Verde VIE noncontrolling interest (see Note 20)

 

(9,633

)

(7,057

)

(6,723

)

Other

 

(7,617

)

(2,892

)

843

 

Income tax expense

 

$

192,542

 

$

170,465

 

$

152,574

 

 

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

 

 

 

December 31,

 

 

 

2011

 

2010

 

Current asset

 

$

111,503

 

$

105,042

 

Long-term liability

 

(1,952,608

)

(1,895,654

)

Deferred income taxes — net

 

$

(1,841,105

)

$

(1,790,612

)

 

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 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. In 2011, APS increased regulatory liabilities by a total of $62 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,

 

 

 

2011

 

2010

 

DEFERRED TAX ASSETS

 

 

 

 

 

Regulatory liabilities:

 

 

 

 

 

Asset retirement obligation and removal costs

 

$

236,739

 

$

222,448

 

Deferred fuel and purchased power

 

 

23,089

 

Renewable energy standard

 

19,722

 

18,749

 

Unamortized investment tax credits

 

31,460

 

642

 

Other

 

33,155

 

27,718

 

Risk management activities

 

117,765

 

124,731

 

Pension and other postretirement liabilities

 

494,744

 

303,055

 

Renewable energy incentives

 

57,901

 

37,327

 

Credit and loss carryforwards

 

106,668

 

 

Other

 

99,176

 

97,989

 

Total deferred tax assets

 

1,197,330

 

855,748

 

DEFERRED TAX LIABILITIES

 

 

 

 

 

Plant-related

 

(2,446,908

)

(2,210,976

)

Risk management activities

 

(30,171

)

(30,125

)

Regulatory assets:

 

 

 

 

 

Allowance for equity funds used during construction

 

(33,347

)

(28,276

)

Deferred fuel and purchased power

 

(10,884

)

 

Deferred fuel and purchased power — mark-to-market

 

(30,559

)

(30,276

)

Pension and other postretirement benefits

 

(408,716

)

(264,313

)

Other

 

(73,087

)

(77,078

)

Other

 

(4,763

)

(5,316

)

Total deferred tax liabilities

 

(3,038,435

)

(2,646,360

)

Deferred income taxes — net

 

$

(1,841,105

)

$

(1,790,612

)

 

As of December 31, 2011, the deferred tax assets for credit and loss carryforwards relate to federal general business credits ($60 million) and federal net operating losses ($37 million), both of which first begin to expire in 2031, and other federal and state loss carryforwards ($10 million) which first begin to expire in 2013.

Selected Quarterly Financial Data (Unaudited) (APSC)

 

 

13.          Selected Quarterly Financial Data (Unaudited)

 

Consolidated quarterly financial information for 2011 and 2010 is as follows (dollars in thousands, except per share amounts):

 

 

 

2011 Quarter Ended

 

2011

 

 

 

March 31,(a)

 

June 30,

 

Sept. 30,

 

Dec. 31,

 

Total

 

 

 

 

 

 

 

 

 

 

 

 

 

Operating revenues

 

$

648,847

 

$

799,799

 

$

1,124,841

 

$

667,892

 

$

3,241,379

 

Operations and maintenance

 

255,029

 

210,590

 

210,035

 

228,632

 

904,286

 

Operating income

 

35,784

 

196,992

 

435,017

 

78,715

 

746,508

 

Income taxes

 

(6,005

)

50,818

 

131,416

 

7,375

 

183,604

 

Income (loss) from continuing operations

 

(10,368

)

93,185

 

253,273

 

19,544

 

355,634

 

Net income (loss) attributable to common shareholders

 

(15,135

)

86,685

 

255,359

 

12,564

 

339,473

 

 

 

 

 

 

 

 

 

 

 

 

 

Earnings Per Share:

 

 

 

 

 

 

 

 

 

 

 

Income (loss) from continuing operations attributable to common shareholders - Basic

 

$

(0.15

)

$

0.79

 

$

2.25

 

$

0.11

 

$

3.01

 

Net income (loss) attributable to common shareholders - Basic

 

(0.14

)

0.80

 

2.34

 

0.12

 

3.11

 

Income (loss) from continuing operations attributable to common shareholders - Diluted

 

(0.15

)

0.78

 

2.24

 

0.11

 

2.99

 

Net income (loss) attributable to common shareholders - Diluted

 

(0.14

)

0.79

 

2.32

 

0.11

 

3.09

 

 

(a)                                  The March 31, 2011 results were adjusted for the effect of reclassifications for discontinued operations (see Note 21).  The adjustments resulted in a reduction in operating revenues of $10,728, a reduction in operations and maintenance of $1,457, a reduction in operating income of $1,357, a decrease in income taxes of $356, and a decrease in income from continuing operations of $1,043.

 

 

 

2010 Quarter Ended

 

2010

 

 

 

March 31,

 

June 30,

 

Sept. 30,

 

Dec. 31,

 

Total

 

 

 

 

 

 

 

 

 

 

 

 

 

As originally reported in the 2010 10-K:

 

 

 

 

 

 

 

 

 

 

 

Operating revenues

 

$

620,355

 

$

820,594

 

$

1,139,085

 

$

683,611

 

$

3,263,645

 

Operations and maintenance

 

207,842

 

215,104

 

221,469

 

232,991

 

877,406

 

Operating income

 

57,668

 

203,273

 

403,625

 

59,318

 

723,884

 

Income taxes

 

(7,172

)

51,829

 

123,486

 

(3,822

)

164,321

 

Income from continuing operations

 

11,983

 

94,584

 

231,828

 

12,203

 

350,598

 

Net income (loss) attributable to common shareholders

 

(6,014

)

114,797

 

233,920

 

7,350

 

350,053

 

 

 

 

 

 

 

 

 

 

 

 

 

Reclassification of discontinued operations (Note 21):

 

 

 

 

 

 

 

 

 

 

 

Operating revenues

 

$

(8,093

)

$

(17,799

)

$

(22,375

)

$

(26,179

)

$

(74,446

)

Operations and maintenance

 

(1,529

)

(1,495

)

(1,811

)

(2,386

)

(7,221

)

Operating income

 

(694

)

(1,889

)

(3,351

)

(3,067

)

(9,001

)

Income taxes

 

(481

)

(641

)

(1,139

)

(1,191

)

(3,452

)

Income (loss) from continuing operations

 

(292

)

(1,270

)

(2,266

)

(1,919

)

(5,747

)

 

 

 

 

 

 

 

 

 

 

 

 

After reclassifications:

 

 

 

 

 

 

 

 

 

 

 

Operating revenues

 

$

612,262

 

$

802,795

 

$

1,116,710

 

$

657,432

 

$

3,189,199

 

Operations and maintenance

 

206,313

 

213,609

 

219,658

 

230,605

 

870,185

 

Operating income

 

56,974

 

201,384

 

400,274

 

56,251

 

714,883

 

Income taxes

 

(7,653

)

51,188

 

122,347

 

(5,013

)

160,869

 

Income from continuing operations

 

11,691

 

93,314

 

229,562

 

10,284

 

344,851

 

Net income (loss) attributable to common shareholders

 

(6,014

)

114,797

 

233,920

 

7,350

 

350,053

 

 

 

 

 

 

 

 

 

 

 

 

 

Earnings Per Share:

 

 

 

 

 

 

 

 

 

 

 

As originally reported in the 2010 10-K

 

 

 

 

 

 

 

 

 

 

 

Income from continuing operations attributable to common shareholders - Basic

 

$

0.07

 

$

0.84

 

$

2.09

 

$

0.07

 

$

3.10

 

Net income (loss) attributable to common shareholders - Basic

 

(0.06

)

1.07

 

2.15

 

0.07

 

3.28

 

Income from continuing operations attributable to common shareholders - Diluted

 

0.07

 

0.83

 

2.08

 

0.06

 

3.08

 

Net income (loss) attributable to common shareholders - Diluted

 

(0.06

)

1.07

 

2.14

 

0.07

 

3.27

 

 

 

 

 

 

 

 

 

 

 

 

 

Earnings Per Share:

 

 

 

 

 

 

 

 

 

 

 

After reclassifications:

 

 

 

 

 

 

 

 

 

 

 

Income from continuing operations attributable to common shareholders - Basic

 

$

0.06

 

$

0.82

 

$

2.07

 

$

0.05

 

$

3.05

 

Net income (loss) attributable to common shareholders - Basic

 

(0.06

)

1.07

 

2.15

 

0.07

 

3.28

 

Income from continuing operations attributable to common shareholders - Diluted

 

0.06

 

0.82

 

2.06

 

0.05

 

3.03

 

Net income (loss) attributable to common shareholders - Diluted

 

(0.06

)

1.07

 

2.14

 

0.07

 

3.27

 

 

S-2.         Selected Quarterly Financial Data (Unaudited)

 

Quarterly financial information for 2011 and 2010 is as follows (dollars in thousands):

 

 

 

2011 Quarter Ended,

 

2011

 

 

 

March 31,

 

June 30,

 

September 30,

 

December 31,

 

Total

 

 

 

 

 

 

 

 

 

 

 

 

 

Operating revenues

 

$

647,994

 

$

798,686

 

$

1,124,057

 

$

666,504

 

$

3,237,241

 

Operations and maintenance

 

252,607

 

208,597

 

207,967

 

226,746

 

895,917

 

Operating income

 

45,574

 

145,400

 

292,783

 

70,626

 

554,383

 

Net income (loss) attributable to common shareholder

 

(12,081

)

87,705

 

246,333

 

14,292

 

336,249

 

 

 

 

2010 Quarter Ended,

 

2010

 

 

 

March 31,

 

June 30,

 

September 30,

 

December 31,

 

Total

 

 

 

 

 

 

 

 

 

 

 

 

 

Operating revenues

 

$

611,476

 

$

799,467

 

$

1,116,220

 

$

653,644

 

$

3,180,807

 

Operations and maintenance

 

203,881

 

211,310

 

217,044

 

228,477

 

860,712

 

Operating income

 

65,435

 

146,249

 

277,009

 

60,344

 

549,037

 

Net income attributable to common shareholder

 

10,984

 

90,220

 

226,648

 

7,811

 

335,663

Other Income and Other Expense (APSC)

 

 

19.          Other Income and Other Expense

 

The following table provides detail of other income and other expense for 2011, 2010 and 2009 (dollars in thousands):

 

 

 

2011

 

2010

 

2009

 

Other income:

 

 

 

 

 

 

 

Interest income

 

$

1,850

 

$

3,255

 

$

1,503

 

Investment gains — net

 

1,165

 

2,797

 

2,512

 

Miscellaneous

 

96

 

335

 

1,144

 

Total other income

 

$

3,111

 

$

6,387

 

$

5,159

 

 

 

 

 

 

 

 

 

Other expense:

 

 

 

 

 

 

 

Non-operating costs

 

$

(7,037

)

$

(6,831

)

$

(6,675

)

Miscellaneous

 

(3,414

)

(3,090

)

(7,625

)

Total other expense

 

$

(10,451

)

$

(9,921

)

$

(14,300

)

 

 

S-3.         Other Income and Other Expense

 

The following table provides detail of APS’s other income and other expense for 2011, 2010 and 2009 (dollars in thousands):

 

 

 

2011

 

2010

 

2009

 

Other income:

 

 

 

 

 

 

 

Interest income

 

$

406

 

$

668

 

$

502

 

SO2 emission allowance sales and other (a)

 

 

 

1,439

 

Investment gains — net

 

1,418

 

2,334

 

6,673

 

Miscellaneous

 

3,247

 

5,954

 

2,194

 

Total other income

 

$

5,071

 

$

8,956

 

$

10,808

 

 

 

 

 

 

 

 

 

Other expense:

 

 

 

 

 

 

 

Non-operating costs (a)

 

$

(8,810

)

$

(9,855

)

$

(7,368

)

Asset dispositions

 

(1,352

)

(612

)

(656

)

Miscellaneous

 

(5,166

)

(5,392

)

(9,977

)

Total other expense

 

$

(15,328

)

$

(15,859

)

$

(18,001

)

 

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

 

Income Taxes (APSC) (Tables)

 

 

 

 

2011

 

2010

 

2009

 

Total unrecognized tax benefits, January 1

 

$

127,595

 

$

201,216

 

$

63,318

 

Additions for tax positions of the current year

 

10,915

 

7,551

 

44,094

 

Additions for tax positions of prior years

 

 

 

98,942

 

Reductions for tax positions of prior years for:

 

 

 

 

 

 

 

Changes in judgment

 

(1,555

)

(11,017

)

 

Settlements with taxing authorities

 

(124

)

(62,199

)

(4,089

)

Lapses of applicable statute of limitations

 

(826

)

(7,956

)

(1,049

)

Total unrecognized tax benefits, December 31

 

$

136,005

 

$

127,595

 

$

201,216

 

 

 

 

 

Year Ended December 31,

 

 

 

2011

 

2010

 

2009

 

Current:

 

 

 

 

 

 

 

Federal

 

$

(310

)

$

(108,827

)

$

(38,502

)

State

 

15,140

 

25,545

 

(38,080

)

Total current

 

14,830

 

(83,282

)

(76,582

)

Deferred:

 

 

 

 

 

 

 

Federal

 

159,566

 

260,236

 

62,874

 

State

 

16,626

 

10,911

 

42,618

 

Discontinued operations

 

 

(10,736

)

 

Total deferred

 

176,192

 

260,411

 

105,492

 

Total income tax expense

 

191,022

 

177,129

 

28,910

 

Less: income tax expense (benefit) on discontinued operations

 

7,418

 

16,260

 

(109,641

)

Income tax expense — continuing operations

 

$

183,604

 

$

160,869

 

$

138,551

 

 

 

 

 

Year Ended December 31,

 

 

 

2011

 

2010

 

2009

 

 

 

 

 

 

 

 

 

Federal income tax expense at 35% statutory rate

 

$

188,733

 

$

177,002

 

$

138,110

 

Increases (reductions) in tax expense resulting from:

 

 

 

 

 

 

 

State income tax net of federal income tax benefit

 

19,594

 

17,485

 

15,068

 

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

 

 

(17,300

)

 

Medicare Subsidy Part-D

 

823

 

1,311

 

(2,095

)

Allowance for equity funds used during construction (see Note 1)

 

(6,881

)

(6,563

)

(4,265

)

Palo Verde VIE noncontrolling interest (see Note 20)

 

(9,636

)

(7,057

)

(6,723

)

Other

 

(9,029

)

(4,009

)

(1,544

)

Income tax expense — continuing operations

 

$

183,604

 

$

160,869

 

$

138,551

 

 

 

 

December 31,

 

 

 

2011

 

2010

 

Current asset

 

$

130,571

 

$

124,897

 

Long-term liability

 

(1,925,388

)

(1,863,861

)

Deferred income taxes — net

 

$

(1,794,817

)

$

(1,738,964

)

 

 

 

 

December 31,

 

 

 

2011

 

2010

 

DEFERRED TAX ASSETS

 

 

 

 

 

Risk management activities

 

$

117,765

 

$

124,731

 

Regulatory liabilities:

 

 

 

 

 

Asset retirement obligation and removal costs

 

236,739

 

222,448

 

Deferred fuel and purchased power

 

 

23,089

 

Renewable energy standard

 

19,722

 

18,749

 

Unamortized investment tax credits

 

31,460

 

642

 

Other

 

33,155

 

27,718

 

Pension and other postretirement liabilities

 

501,202

 

321,182

 

Real estate investments and assets held for sale

 

 

19,855

 

Renewable energy incentives

 

57,901

 

37,327

 

Credit and loss carryforwards

 

171,915

 

42,971

 

Other

 

73,759

 

68,684

 

Total deferred tax assets

 

1,243,618

 

907,396

 

DEFERRED TAX LIABILITIES

 

 

 

 

 

Plant-related

 

(2,446,908

)

(2,210,976

)

Risk management activities

 

(30,171

)

(30,125

)

Regulatory assets:

 

 

 

 

 

Allowance for equity funds used during construction

 

(33,347

)

(28,276

)

Deferred fuel and purchased power

 

(10,884

)

 

Deferred fuel and purchased power — mark-to-market

 

(30,559

)

(30,276

)

Pension and other postretirement benefits

 

(408,716

)

(264,313

)

Other

 

(73,087

)

(77,078

)

Other

 

(4,763

)

(5,316

)

Total deferred tax liabilities

 

(3,038,435

)

(2,646,360

)

Deferred income taxes — net

 

$

(1,794,817

)

$

(1,738,964

)

 

 

 

 

2011

 

2010

 

2009

 

Total unrecognized tax benefits, January 1

 

$

126,698

 

$

199,887

 

$

62,409

 

Additions for tax positions of the current year

 

10,915

 

7,551

 

44,094

 

Additions for tax positions of prior years

 

 

 

98,269

 

Reductions for tax positions of prior years for:

 

 

 

 

 

 

 

Changes in judgment

 

(1,555

)

(10,964

)

 

Settlements with taxing authorities

 

(124

)

(61,820

)

(4,089

)

Lapses of applicable statute of limitations

 

(110

)

(7,956

)

(796

)

Total unrecognized tax benefits, December 31

 

$

135,824

 

$

126,698

 

$

199,887

 

 

 

 

 

Year Ended December 31,

 

 

 

2011

 

2010

 

2009

 

Current:

 

 

 

 

 

 

 

Federal

 

$

4,633

 

$

(71,036

)

$

(8,667

)

State

 

19,104

 

17,406

 

(31,673

)

Total current

 

23,737

 

(53,630

)

(40,340

)

Deferred:

 

 

 

 

 

 

 

Federal

 

154,632

 

207,334

 

163,572

 

State

 

14,173

 

16,761

 

29,342

 

Total deferred

 

168,805

 

224,095

 

192,914

 

Total income tax expense

 

$

192,542

 

$

170,465

 

$

152,574

 

 

 

 

Year Ended December 31,

 

 

 

2011

 

2010

 

2009

 

 

 

 

 

 

 

 

 

Federal income tax expense at 35% statutory rate

 

$

194,710

 

$

184,202

 

$

148,053

 

Increases (reductions) in tax expense resulting from:

 

 

 

 

 

 

 

State income tax net of federal income tax benefit

 

21,139

 

19,186

 

16,691

 

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

 

 

(17,300

)

 

Medicare Subsidy Part-D

 

823

 

889

 

(2,025

)

Allowance for equity funds used during construction (see Note 1)

 

(6,880

)

(6,563

)

(4,265

)

Palo Verde VIE noncontrolling interest (see Note 20)

 

(9,633

)

(7,057

)

(6,723

)

Other

 

(7,617

)

(2,892

)

843

 

Income tax expense

 

$

192,542

 

$

170,465

 

$

152,574

 

 

 

 

December 31,

 

 

 

2011

 

2010

 

Current asset

 

$

111,503

 

$

105,042

 

Long-term liability

 

(1,952,608

)

(1,895,654

)

Deferred income taxes — net

 

$

(1,841,105

)

$

(1,790,612

)

 

 

 

 

December 31,

 

 

 

2011

 

2010

 

DEFERRED TAX ASSETS

 

 

 

 

 

Regulatory liabilities:

 

 

 

 

 

Asset retirement obligation and removal costs

 

$

236,739

 

$

222,448

 

Deferred fuel and purchased power

 

 

23,089

 

Renewable energy standard

 

19,722

 

18,749

 

Unamortized investment tax credits

 

31,460

 

642

 

Other

 

33,155

 

27,718

 

Risk management activities

 

117,765

 

124,731

 

Pension and other postretirement liabilities

 

494,744

 

303,055

 

Renewable energy incentives

 

57,901

 

37,327

 

Credit and loss carryforwards

 

106,668

 

 

Other

 

99,176

 

97,989

 

Total deferred tax assets

 

1,197,330

 

855,748

 

DEFERRED TAX LIABILITIES

 

 

 

 

 

Plant-related

 

(2,446,908

)

(2,210,976

)

Risk management activities

 

(30,171

)

(30,125

)

Regulatory assets:

 

 

 

 

 

Allowance for equity funds used during construction

 

(33,347

)

(28,276

)

Deferred fuel and purchased power

 

(10,884

)

 

Deferred fuel and purchased power — mark-to-market

 

(30,559

)

(30,276

)

Pension and other postretirement benefits

 

(408,716

)

(264,313

)

Other

 

(73,087

)

(77,078

)

Other

 

(4,763

)

(5,316

)

Total deferred tax liabilities

 

(3,038,435

)

(2,646,360

)

Deferred income taxes — net

 

$

(1,841,105

)

$

(1,790,612

)

Selected Quarterly Financial Data (Unaudited) (APSC) (Tables)

 

 

 

 

2011 Quarter Ended

 

2011

 

 

 

March 31,(a)

 

June 30,

 

Sept. 30,

 

Dec. 31,

 

Total

 

 

 

 

 

 

 

 

 

 

 

 

 

Operating revenues

 

$

648,847

 

$

799,799

 

$

1,124,841

 

$

667,892

 

$

3,241,379

 

Operations and maintenance

 

255,029

 

210,590

 

210,035

 

228,632

 

904,286

 

Operating income

 

35,784

 

196,992

 

435,017

 

78,715

 

746,508

 

Income taxes

 

(6,005

)

50,818

 

131,416

 

7,375

 

183,604

 

Income (loss) from continuing operations

 

(10,368

)

93,185

 

253,273

 

19,544

 

355,634

 

Net income (loss) attributable to common shareholders

 

(15,135

)

86,685

 

255,359

 

12,564

 

339,473

 

 

 

 

 

 

 

 

 

 

 

 

 

Earnings Per Share:

 

 

 

 

 

 

 

 

 

 

 

Income (loss) from continuing operations attributable to common shareholders - Basic

 

$

(0.15

)

$

0.79

 

$

2.25

 

$

0.11

 

$

3.01

 

Net income (loss) attributable to common shareholders - Basic

 

(0.14

)

0.80

 

2.34

 

0.12

 

3.11

 

Income (loss) from continuing operations attributable to common shareholders - Diluted

 

(0.15

)

0.78

 

2.24

 

0.11

 

2.99

 

Net income (loss) attributable to common shareholders - Diluted

 

(0.14

)

0.79

 

2.32

 

0.11

 

3.09

 

 

(a)                                  The March 31, 2011 results were adjusted for the effect of reclassifications for discontinued operations (see Note 21).  The adjustments resulted in a reduction in operating revenues of $10,728, a reduction in operations and maintenance of $1,457, a reduction in operating income of $1,357, a decrease in income taxes of $356, and a decrease in income from continuing operations of $1,043.

 

 

 

 

2011 Quarter Ended,

 

2011

 

 

 

March 31,

 

June 30,

 

September 30,

 

December 31,

 

Total

 

 

 

 

 

 

 

 

 

 

 

 

 

Operating revenues

 

$

647,994

 

$

798,686

 

$

1,124,057

 

$

666,504

 

$

3,237,241

 

Operations and maintenance

 

252,607

 

208,597

 

207,967

 

226,746

 

895,917

 

Operating income

 

45,574

 

145,400

 

292,783

 

70,626

 

554,383

 

Net income (loss) attributable to common shareholder

 

(12,081

)

87,705

 

246,333

 

14,292

 

336,249

 

 

 

 

2010 Quarter Ended,

 

2010

 

 

 

March 31,

 

June 30,

 

September 30,

 

December 31,

 

Total

 

 

 

 

 

 

 

 

 

 

 

 

 

Operating revenues

 

$

611,476

 

$

799,467

 

$

1,116,220

 

$

653,644

 

$

3,180,807

 

Operations and maintenance

 

203,881

 

211,310

 

217,044

 

228,477

 

860,712

 

Operating income

 

65,435

 

146,249

 

277,009

 

60,344

 

549,037

 

Net income attributable to common shareholder

 

10,984

 

90,220

 

226,648

 

7,811

 

335,663

Other Income and Other Expense (APSC) (Tables)

 

 

 

 

2011

 

2010

 

2009

 

Other income:

 

 

 

 

 

 

 

Interest income

 

$

1,850

 

$

3,255

 

$

1,503

 

Investment gains — net

 

1,165

 

2,797

 

2,512

 

Miscellaneous

 

96

 

335

 

1,144

 

Total other income

 

$

3,111

 

$

6,387

 

$

5,159

 

 

 

 

 

 

 

 

 

Other expense:

 

 

 

 

 

 

 

Non-operating costs

 

$

(7,037

)

$

(6,831

)

$

(6,675

)

Miscellaneous

 

(3,414

)

(3,090

)

(7,625

)

Total other expense

 

$

(10,451

)

$

(9,921

)

$

(14,300

)

 

 

 

 

2011

 

2010

 

2009

 

Other income:

 

 

 

 

 

 

 

Interest income

 

$

406

 

$

668

 

$

502

 

SO2 emission allowance sales and other (a)

 

 

 

1,439

 

Investment gains — net

 

1,418

 

2,334

 

6,673

 

Miscellaneous

 

3,247

 

5,954

 

2,194

 

Total other income

 

$

5,071

 

$

8,956

 

$

10,808

 

 

 

 

 

 

 

 

 

Other expense:

 

 

 

 

 

 

 

Non-operating costs (a)

 

$

(8,810

)

$

(9,855

)

$

(7,368

)

Asset dispositions

 

(1,352

)

(612

)

(656

)

Miscellaneous

 

(5,166

)

(5,392

)

(9,977

)

Total other expense

 

$

(15,328

)

$

(15,859

)

$

(18,001

)

 

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

Income Taxes (APSC) (Details) (USD $)
3 Months Ended 12 Months Ended
Mar. 31, 2010
Dec. 31, 2011
Dec. 31, 2010
Dec. 31, 2009
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
$ 201,216,000 
$ 127,595,000 
$ 201,216,000 
$ 63,318,000 
Additions for tax positions of the current year
 
10,915,000 
7,551,000 
44,094,000 
Additions for tax positions of prior years
 
 
 
98,942,000 
Reductions for tax positions of prior years for:
 
 
 
 
Changes in judgment
 
(1,555,000)
(11,017,000)
 
Settlements with taxing authorities
(62,000,000)
(124,000)
(62,199,000)
(4,089,000)
Lapses of applicable statute of limitations
 
(826,000)
(7,956,000)
(1,049,000)
Total unrecognized tax benefits at the end of the year
 
136,005,000 
127,595,000 
201,216,000 
Unrecognized tax benefits if recognized, would decrease effective tax rate
 
8,000,000 
7,000,000 
16,000,000 
Pre-tax interest expense (benefit) related to unrecognized tax benefits
 
3,000,000 
(2,000,000)
2,000,000 
Accrued liabilities for interest related to unrecognized tax benefits
 
9,000,000 
6,000,000 
8,000,000 
Interest income to be received on the overpayment of income taxes for certain adjustments that we have filed, or will file, with the IRS
 
4,000,000 
 
 
Settlements with taxing authorities
62,000,000 
124,000 
62,199,000 
4,089,000 
Net decrease in uncertain tax positions which decreased our effective tax rate
3,000,000 
 
 
 
Net interest benefits through the effective tax rate
4,000,000 
 
 
 
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
 
 
 
 
Total unrecognized tax benefits at the beginning of the year
199,887,000 
126,698,000 
199,887,000 
62,409,000 
Additions for tax positions of the current year
 
10,915,000 
7,551,000 
44,094,000 
Additions for tax positions of prior years
 
 
 
98,269,000 
Reductions for tax positions of prior years for:
 
 
 
 
Changes in judgment
 
(1,555,000)
(10,964,000)
 
Settlements with taxing authorities
(62,000,000)
(124,000)
(61,820,000)
(4,089,000)
Lapses of applicable statute of limitations
 
(110,000)
(7,956,000)
(796,000)
Total unrecognized tax benefits at the end of the year
 
135,824,000 
126,698,000 
199,887,000 
Unrecognized tax benefits if recognized, would decrease effective tax rate
 
8,000,000 
6,000,000 
15,000,000 
Pre-tax interest expense (benefit) related to unrecognized tax benefits
 
3,000,000 
(2,000,000)
2,000,000 
Accrued liabilities for interest related to unrecognized tax benefits
 
9,000,000 
6,000,000 
8,000,000 
Interest income to be received on the overpayment of income taxes for certain adjustments that we have filed, or will file, with the IRS
 
4,000,000 
 
 
Settlements with taxing authorities
62,000,000 
124,000 
61,820,000 
4,089,000 
Net decrease in uncertain tax positions which decreased our effective tax rate
3,000,000 
 
 
 
Net interest benefits through the effective tax rate
$ 4,000,000 
 
 
 
Income Taxes (APSC) (Details 2) (USD $)
1 Months Ended 3 Months Ended 12 Months Ended
Feb. 28, 2011
Y
Dec. 31, 2011
Sep. 30, 2011
Jun. 30, 2011
Mar. 31, 2011
Mar. 31, 2010
Dec. 31, 2011
Dec. 31, 2010
Dec. 31, 2009
Current:
 
 
 
 
 
 
 
 
 
Federal
 
 
 
 
 
 
$ (310,000)
$ (108,827,000)
$ (38,502,000)
State
 
 
 
 
 
 
15,140,000 
25,545,000 
(38,080,000)
Total current
 
 
 
 
 
 
14,830,000 
(83,282,000)
(76,582,000)
Deferred Income Tax Expense (Benefit), Continuing Operations [Abstract]
 
 
 
 
 
 
 
 
 
Federal
 
 
 
 
 
 
159,566,000 
260,236,000 
62,874,000 
State
 
 
 
 
 
 
16,626,000 
10,911,000 
42,618,000 
Total deferred
 
 
 
 
 
 
176,192,000 
260,411,000 
105,492,000 
Income tax expense - continuing operations
 
7,375,000 
131,416,000 
50,818,000 
(6,005,000)
 
183,604,000 
160,869,000 
138,551,000 
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% 
35.00% 
35.00% 
Federal income tax expense at 35% statutory rate
 
 
 
 
 
 
188,733,000 
177,002,000 
138,110,000 
Increases (reductions) in tax expense resulting from:
 
 
 
 
 
 
 
 
 
State income tax net of federal income tax benefit
 
 
 
 
 
 
19,594,000 
17,485,000 
15,068,000 
Credits and favorable adjustments related to prior years resolved in current year
 
 
 
 
 
 
 
(17,300,000)
 
Medicare Subsidy Part-D
 
 
 
 
 
 
823,000 
1,311,000 
(2,095,000)
Allowance for equity funds used during construction
 
 
 
 
 
 
(6,881,000)
(6,563,000)
(4,265,000)
Palo Verde VIE noncontrolling interest
 
 
 
 
 
 
(9,636,000)
(7,057,000)
(6,723,000)
Other
 
 
 
 
 
 
(9,029,000)
(4,009,000)
(1,544,000)
Income tax expense - continuing operations
 
7,375,000 
131,416,000 
50,818,000 
(6,005,000)
 
183,604,000 
160,869,000 
138,551,000 
Net deferred income tax liability recognized on the Consolidated Balance Sheets
 
 
 
 
 
 
 
 
 
Current asset
 
130,571,000 
 
 
 
 
130,571,000 
124,897,000 
 
Long-term liability
 
(1,925,388,000)
 
 
 
 
(1,925,388,000)
(1,863,861,000)
 
Deferred income taxes - net
 
(1,794,817,000)
 
 
 
 
(1,794,817,000)
(1,738,964,000)
 
Income Taxes, additional disclosures
 
 
 
 
 
 
 
 
 
Phase-in period of corporate income tax rate reductions beginning in 2014 (in years)
 
 
 
 
 
 
 
 
Decrease in deferred income tax liabilities
 
 
 
 
(62,000,000)
42,000,000 
 
 
 
Change in regulatory liabilities
 
 
 
 
62,000,000 
 
37,009,000 
56,801,000 
82,650,000 
ARIZONA PUBLIC SERVICE COMPANY
 
 
 
 
 
 
 
 
 
Current:
 
 
 
 
 
 
 
 
 
Federal
 
 
 
 
 
 
4,633,000 
(71,036,000)
(8,667,000)
State
 
 
 
 
 
 
19,104,000 
17,406,000 
(31,673,000)
Total current
 
 
 
 
 
 
23,737,000 
(53,630,000)
(40,340,000)
Deferred Income Tax Expense (Benefit), Continuing Operations [Abstract]
 
 
 
 
 
 
 
 
 
Federal
 
 
 
 
 
 
154,632,000 
207,334,000 
163,572,000 
State
 
 
 
 
 
 
14,173,000 
16,761,000 
29,342,000 
Total deferred
 
 
 
 
 
 
168,805,000 
224,095,000 
192,914,000 
Income tax expense - continuing operations
 
 
 
 
 
 
192,542,000 
170,465,000 
152,574,000 
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% 
35.00% 
35.00% 
Federal income tax expense at 35% statutory rate
 
 
 
 
 
 
194,710,000 
184,202,000 
148,053,000 
Increases (reductions) in tax expense resulting from:
 
 
 
 
 
 
 
 
 
State income tax net of federal income tax benefit
 
 
 
 
 
 
21,139,000 
19,186,000 
16,691,000 
Credits and favorable adjustments related to prior years resolved in current year
 
 
 
 
 
 
 
(17,300,000)
 
Medicare Subsidy Part-D
 
 
 
 
 
 
823,000 
889,000 
(2,025,000)
Allowance for equity funds used during construction
 
 
 
 
 
 
(6,880,000)
(6,563,000)
(4,265,000)
Palo Verde VIE noncontrolling interest
 
 
 
 
 
 
(9,633,000)
(7,057,000)
(6,723,000)
Other
 
 
 
 
 
 
(7,617,000)
(2,892,000)
843,000 
Income tax expense - continuing operations
 
 
 
 
 
 
192,542,000 
170,465,000 
152,574,000 
Net deferred income tax liability recognized on the Consolidated Balance Sheets
 
 
 
 
 
 
 
 
 
Current asset
 
111,503,000 
 
 
 
 
111,503,000 
105,042,000 
 
Long-term liability
 
(1,952,608,000)
 
 
 
 
(1,952,608,000)
(1,895,654,000)
 
Deferred income taxes - net
 
(1,841,105,000)
 
 
 
 
(1,841,105,000)
(1,790,612,000)
 
Income Taxes, additional disclosures
 
 
 
 
 
 
 
 
 
Phase-in period of corporate income tax rate reductions beginning in 2014 (in years)
 
 
 
 
 
 
 
 
Decrease in deferred income tax liabilities
 
 
 
 
(62,000,000)
 
 
 
 
Change in regulatory liabilities
 
 
 
 
$ 62,000,000 
 
$ 37,009,000 
$ 56,801,000 
$ 82,650,000 
Income Taxes (APSC) (Details 3) (USD $)
Dec. 31, 2011
Dec. 31, 2010
Regulatory liabilities:
 
 
Asset retirement obligation and removal costs
$ 236,739,000 
$ 222,448,000 
Deferred fuel and purchased power
 
23,089,000 
Renewable energy standard
19,722,000 
18,749,000 
Unamortized investment tax credits
31,460,000 
642,000 
Other
33,155,000 
27,718,000 
Risk management activities
117,765,000 
124,731,000 
Pension and other postretirement liabilities
501,202,000 
321,182,000 
Renewable energy incentives
57,901,000 
37,327,000 
Credit and loss carryforwards
171,915,000 
42,971,000 
Other
73,759,000 
68,684,000 
Total deferred tax assets
1,243,618,000 
907,396,000 
DEFERRED TAX LIABILITIES
 
 
Plant-related
(2,446,908,000)
(2,210,976,000)
Risk management activities
(30,171,000)
(30,125,000)
Regulatory assets:
 
 
Allowance for equity funds used during construction
(33,347,000)
(28,276,000)
Deferred fuel and purchased power
(10,884,000)
 
Deferred fuel and purchased power - mark-to-market
(30,559,000)
(30,276,000)
Pension and other postretirement benefits
(408,716,000)
(264,313,000)
Other
(73,087,000)
(77,078,000)
Other
(4,763,000)
(5,316,000)
Total deferred tax liabilities
(3,038,435,000)
(2,646,360,000)
Deferred income taxes - net
(1,794,817,000)
(1,738,964,000)
ARIZONA PUBLIC SERVICE COMPANY
 
 
Regulatory liabilities:
 
 
Asset retirement obligation and removal costs
236,739,000 
222,448,000 
Deferred fuel and purchased power
 
23,089,000 
Renewable energy standard
19,722,000 
18,749,000 
Unamortized investment tax credits
31,460,000 
642,000 
Other
33,155,000 
27,718,000 
Risk management activities
117,765,000 
124,731,000 
Pension and other postretirement liabilities
494,744,000 
303,055,000 
Renewable energy incentives
57,901,000 
37,327,000 
Credit and loss carryforwards
106,668,000 
 
Other
99,176,000 
97,989,000 
Total deferred tax assets
1,197,330,000 
855,748,000 
DEFERRED TAX LIABILITIES
 
 
Plant-related
(2,446,908,000)
(2,210,976,000)
Risk management activities
(30,171,000)
(30,125,000)
Regulatory assets:
 
 
Allowance for equity funds used during construction
(33,347,000)
(28,276,000)
Deferred fuel and purchased power
(10,884,000)
 
Deferred fuel and purchased power - mark-to-market
(30,559,000)
(30,276,000)
Pension and other postretirement benefits
(408,716,000)
(264,313,000)
Other
(73,087,000)
(77,078,000)
Other
(4,763,000)
(5,316,000)
Total deferred tax liabilities
(3,038,435,000)
(2,646,360,000)
Deferred income taxes - net
(1,841,105,000)
(1,790,612,000)
Amount of federal general business credits carryforwards which begin to expire in 2031
60,000,000 
 
Amount of federal net operating losses carryforwards which begin to expire in 2031
37,000,000 
 
Amount of federal and state loss carryforwards which begin to expire in 2013
$ 10,000,000 
 
Selected Quarterly Financial Data (Unaudited) (APSC) (Details) (USD $)
In Thousands, unless otherwise specified
3 Months Ended 12 Months Ended
Dec. 31, 2011
Sep. 30, 2011
Jun. 30, 2011
Mar. 31, 2011
Dec. 31, 2010
Sep. 30, 2010
Jun. 30, 2010
Mar. 31, 2010
Dec. 31, 2011
Dec. 31, 2010
Dec. 31, 2009
Consolidated quarterly financial information
 
 
 
 
 
 
 
 
 
 
 
Operating revenues
$ 667,892 
$ 1,124,841 
$ 799,799 
$ 648,847 
 
 
 
 
$ 3,241,379 
$ 3,189,199 
$ 3,153,656 
Operations and maintenance
228,632 
210,035 
210,590 
255,029 
 
 
 
 
904,286 
870,185 
822,300 
Operating income
78,715 
435,017 
196,992 
35,784 
 
 
 
 
746,508 
714,883 
616,128 
Net income (loss) attributable to common shareholders
12,564 
255,359 
86,685 
(15,135)
 
 
 
 
339,473 
350,053 
68,330 
ARIZONA PUBLIC SERVICE COMPANY
 
 
 
 
 
 
 
 
 
 
 
Consolidated quarterly financial information
 
 
 
 
 
 
 
 
 
 
 
Operating revenues
666,504 
1,124,057 
798,686 
647,994 
653,644 
1,116,220 
799,467 
611,476 
3,237,241 
3,180,807 
 
Operations and maintenance
226,746 
207,967 
208,597 
252,607 
228,477 
217,044 
211,310 
203,881 
895,917 
860,712 
812,903 
Operating income
70,626 
292,783 
145,400 
45,574 
60,344 
277,009 
146,249 
65,435 
554,383 
549,037 
469,799 
Net income (loss) attributable to common shareholders
$ 14,292 
$ 246,333 
$ 87,705 
$ (12,081)
$ 7,811 
$ 226,648 
$ 90,220 
$ 10,984 
$ 336,249 
$ 335,663 
$ 251,225 
Other Income and Other Expense (APSC) (Details) (USD $)
In Thousands, unless otherwise specified
12 Months Ended
Dec. 31, 2011
Dec. 31, 2010
Dec. 31, 2009
Other income:
 
 
 
Interest income
$ 1,850 
$ 3,255 
$ 1,503 
Investment gains - net
1,165 
2,797 
2,512 
Miscellaneous
96 
335 
1,144 
Total other income
3,111 
6,387 
5,159 
Other expense:
 
 
 
Non-operating costs
(7,037)
(6,831)
(6,675)
Miscellaneous
(3,414)
(3,090)
(7,625)
Total other expense
(10,451)
(9,921)
(14,300)
ARIZONA PUBLIC SERVICE COMPANY
 
 
 
Other income:
 
 
 
Interest income
406 
668 
502 
SO2 emission allowance sales and other
 
 
1,439 
Investment gains - net
1,418 
2,334 
6,673 
Miscellaneous
3,247 
5,954 
2,194 
Total other income
5,071 
8,956 
10,808 
Other expense:
 
 
 
Non-operating costs
(8,810)
(9,855)
(7,368)
Asset dispositions
(1,352)
(612)
(656)
Miscellaneous
(5,166)
(5,392)
(9,977)
Total other expense
$ (15,328)
$ (15,859)
$ (18,001)
SCHEDULE II RESERVE FOR UNCOLLECTIBLES (Details 2) (USD $)
In Thousands, unless otherwise specified
12 Months Ended
Dec. 31, 2011
Dec. 31, 2010
Dec. 31, 2009
Changes in reserve for uncollectibles
 
 
 
Additions, Charged to other accounts
$ 0 
 
 
Reserve for uncollectibles. |
ARIZONA PUBLIC SERVICE COMPANY
 
 
 
Changes in reserve for uncollectibles
 
 
 
Balance at beginning of period
4,376 
4,483 
3,155 
Additions, Charged to cost and expenses
5,751 
6,756 
7,062 
Deductions
6,379 
6,863 
5,734 
Balance at end of period
$ 3,748 
$ 4,376 
$ 4,483