UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

FORM 10-Q

(Mark One)

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

For the quarterly period ended March 31, 2014

OR

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

For the transition period from                     to                     .

Commission File Number	Registrant; State of Incorporation; Address; and Telephone Number	IRS Employer Identification Number
1-13739	UNS ENERGY CORPORATION (An Arizona Corporation) 88 East Broadway Boulevard Tucson, AZ 85701 (520) 571-4000	86-0786732
1-5924	TUCSON ELECTRIC POWER COMPANY (An Arizona Corporation) 88 East Broadway Boulevard Tucson, AZ 85701 (520) 571-4000	86-0062700

Indicate by check mark whether the registrant (1) has filed all reports required to be filed by Section 13 or 15(d) of the Exchange Act during the preceding 12 months (or for such shorter period that the registrant was required to file such reports), and (2) has been subject to such filing requirements for the past 90 days.

UNS Energy Corporation	Yes  x	No  ¨
Tucson Electric Power Company	Yes  x	No  ¨

Indicate by check mark whether the registrant has submitted electronically and posted on its corporate Web site, if any, every Interactive Data File required to be submitted and posted pursuant to Rule 405 of Regulation S-T during the preceding 12 months (or for such shorter period that the registrant was required to submit and post such files).

UNS Energy Corporation	Yes  x	No  ¨
Tucson Electric Power Company	Yes  x	No  ¨

Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer or a smaller reporting company. See the definitions of “large accelerated filer,” “accelerated filer,” and “smaller reporting company” in Rule 12b-2 of the Exchange Act. (Check one):

UNS Energy Corporation	Large Accelerated Filer	x	Accelerated Filer	¨
	Non-accelerated Filer	¨	Smaller Reporting Company	¨

Tucson Electric Power Company	Large Accelerated Filer	¨	Accelerated Filer	¨
	Non-accelerated Filer	x	Smaller Reporting Company	¨

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

UNS Energy Corporation	Yes  ¨	No  x
Tucson Electric Power Company	Yes  ¨	No  x

As of April 17, 2014, 41,701,718 shares of UNS Energy Corporation Common Stock, no par value (the only class of Common Stock), were outstanding. As of April 17, 2014, Tucson Electric Power Company had 32,139,434 shares of common stock outstanding, no par value, all of which were held by UNS Energy Corporation.

This combined Form 10-Q is separately filed by UNS Energy Corporation and Tucson Electric Power Company. Information contained in this document relating to Tucson Electric Power Company is filed by UNS Energy Corporation and separately by Tucson Electric Power Company on its own behalf. Tucson Electric Power Company makes no representation as to information relating to UNS Energy Corporation or its subsidiaries, except as it may relate to Tucson Electric Power Company.

ii

Table of Contents

Definitions	iv
PART I
Item 1. Financial Statements
UNS Energy Corporation
Condensed Consolidated Statements of Income	1
Condensed Consolidated Statements of Comprehensive Income	2
Condensed Consolidated Statements of Cash Flows	3
Condensed Consolidated Balance Sheets	4
Condensed Consolidated Statements of Changes in Stockholders’ Equity	6
Tucson Electric Power Company
Condensed Consolidated Statements of Income	7
Condensed Consolidated Statements of Comprehensive Income	8
Condensed Consolidated Statements of Cash Flows	9
Condensed Consolidated Balance Sheets	10
Condensed Consolidated Statements of Changes in Stockholder’s Equity	12
Notes to Condensed Consolidated Financial Statements
Note 1. Nature of Operations and Financial Statement Presentation	13
Note 2. Pending Merger with Fortis	13
Note 3. Regulatory Matters	14
Note 4. Business Segments	14
Note 5. Debt and Capital Lease Obligations	15
Note 6. Commitments, Contingencies, and Environmental Matters	16
Note 7. Planned Purchase of Gas-Fired Generation Facility	19
Note 8. Employee Benefit Plans	19
Note 9. Share-Based Compensation Plans	19
Note 10. UNS Energy Earnings Per Share	20
Note 11. Supplemental Cash Flow Information	21
Note 12. Fair Value Measurements and Derivative Instruments	22
Note 13. Changes in Accumulated Other Comprehensive Income by Component	28
Note 14. Recently Issued Accounting Pronouncements	29
Item  2. – Management’s Discussion and Analysis of Financial Condition and Results of Operations	30
UNS Energy Consolidated	30
Tucson Electric Power Company	36
UNS Electric	46
UNS Gas	50
Critical Accounting Policies	53
Safe Harbor for Forward-Looking Statements	53
Item 3. – Quantitative and Qualitative Disclosures about Market Risk	53
Item 4. – Controls and Procedures	54
PART II
Item 1. – Legal Proceedings	55
Item 1A. – Risk Factors	55
Item 5. – Other Information	56
Item 6. – Exhibits	58
Signatures	59
Exhibit Index	60

iii

DEFINITIONS

The abbreviations and acronyms used in the first quarter2014 Form 10-Q are defined below:

2013 Covenants Agreement	A Lender Rate Mode Covenants Agreements between TEP and the purchaser of $100 million of unsecured tax-exempt bonds that were issued behalf of TEP in November 2013 and sold in a private placement.
ACC	Arizona Corporation Commission
APS	Arizona Public Service Company
BART	Best Available Retrofit Technology
Base O&M	A non-GAAP financial measure that represents the fundamental level of operating and maintenance expense related to our business
Base Rates	The portion of TEP’s and UNS Electric’s Retail Rates attributed to generation, transmission, distribution costs, and customer charge; and UNS Gas’ delivery costs and customer charge. Base Rates exclude costs that are passed through to customers for fuel and purchased energy costs
Btu	British thermal unit(s)
Cooling Degree Days	An index used to measure the impact of weather on energy usage calculated by subtracting 75 from the average of the high and low daily temperatures
DSM	Demand Side Management
ECA	Environmental Compliance Adjustor
Entegra	a subsidiary of Entegra Power Group LLC
FERC	Federal Energy Regulatory Commission
Fortis	FortisUS, Inc., a Delaware corporation whose ultimate parent company is Fortis Parent
Fortis Parent	Fortis, Inc., a corporation incorporated under the Corporations Act of Newfoundland and Labrador, Canada
Four Corners	Four Corners Generating Station
GBtu	Billion British thermal units
GWh	Gigawatt-hour(s)
Gila River Unit 3	Unit 3 of the Gila River Generating Station
Heating Degree Days	An index used to measure the impact of weather on energy usage calculated by subtracting the average of the high and low daily temperatures from 65
kV	Kilo-volt
kWh	Kilowatt-hour(s)
LFCR	Lost Fixed Cost Recovery Mechanism
Millennium	Millennium Energy Holdings, Inc., a wholly-owned subsidiary of UNS Energy Corporation
MMBtu	Million British thermal units
MW	Megawatt(s)
MWh	Megawatt-hour(s)
Navajo	Navajo Generating Station
OATT	Open Access Transmission Tariff
PGA	Purchased Gas Adjustor, a Retail Rate mechanism designed to recover the cost of gas purchased for retail gas customers
PNM	Public Service Company of New Mexico
PPFAC	Purchased Power and Fuel Adjustment Clause
REC	Renewable Energy Credit
RES	Renewable Energy Standard
Regional Haze Rules	Rules promulgated by the EPA to improve visibility at national parks and wilderness areas
Retail Rates	Rates designed to allow a regulated utility an opportunity to recover its reasonable operating and capital costs and earn a return on its utility plant in service

iv

San Juan	San Juan Generating Station
SCR	Selective Catalytic Reduction
SJCC	San Juan Coal Company
SNCR	Selective Non-Catalytic Reduction
Springerville	Springerville Generating Station
Springerville Coal Handling Facilities	Coal handling facilities at Springerville used by all four Springerville units
Springerville Coal Handling Facilities Leases	Leases for coal handling facilities at Springerville used in common by all four Springerville units
Springerville Common Facilities	Facilities at Springerville used in common by all four Springerville units
Springerville Common Facilities Leases	Leveraged lease arrangements relating to an undivided one-half interest in certain Springerville Common Facilities
Springerville Unit 1	Unit 1 of the Springerville Generating Station
Springerville Unit 1 Leases	Leveraged lease arrangement relating to Springerville Unit 1 and an undivided one-half interest in certain Springerville Common Facilities
Springerville Unit 2	Unit 2 of the Springerville Generating Station
Springerville Unit 3	Unit 3 of the Springerville Generating Station
Springerville Unit 4	Unit 4 of the Springerville Generating Station
SRP	Salt River Project Agricultural Improvement and Power District
Sundt	H. Wilson Sundt Generating Station
Sundt Unit 4	Unit 4 of the H. Wilson Sundt Generating Station
TCA	Transmission Cost Adjustor
TEP	Tucson Electric Power Company, the principal subsidiary of UNS Energy Corporation
Therm	A unit of heating value equivalent to 100,000 Btus
Tri-State	Tri-State Generation and Transmission Association, Inc.
UED	UniSource Energy Development Company, a wholly-owned subsidiary of UNS Energy Corporation
UES	UniSource Energy Services, Inc., a wholly-owned subsidiary of UNS Energy, and intermediate holding company established to own the operating companies UNS Electric and UNS Gas
UNS Electric	UNS Electric, Inc., a wholly-owned subsidiary of UES
UNS Energy	UNS Energy Corporation (formerly known as UniSource Energy Corporation)
UNS Gas	UNS Gas, Inc., a wholly-owned subsidiary of UES

v

PART I—FINANCIAL INFORMATION

ITEM 1. FINANCIAL STATEMENTS

UNS ENERGY CORPORATION

CONDENSED CONSOLIDATED STATEMENTS OF INCOME

	Three Months Ended
	March 31,
	2014			2013
	(Unaudited)
	Thousands of Dollars
	(Except Per Share Amounts)
Operating Revenues
Electric Retail Sales	$	224,570		$	220,860
Electric Wholesale Sales	43,421			34,398
Gas Retail Sales	38,570			50,988
Other Revenues	26,831			25,895
Total Operating Revenues	333,392			332,141
Operating Expenses
Fuel	67,835			81,689
Purchased Energy	69,783			64,159
Transmission and Other PPFAC Recoverable Costs	6,528			3,186
Increase (Decrease) to Reflect PPFAC/PGA Recovery Treatment	(8,920		)	(5,368		)
Total Fuel and Purchased Energy	135,226			143,666
Operations and Maintenance	93,436			89,901
Depreciation	39,081			36,300
Amortization	6,176			8,289
Taxes Other Than Income Taxes	14,808			14,090
Total Operating Expenses	288,727			292,246
Operating Income	44,665			39,895
Other Income (Deductions)
Interest Income	80			10
Other Income	2,142			1,767
Other Expense	(730		)	(572		)
Appreciation in Fair Value of Investments	255			1,038
Total Other Income (Deductions)	1,747			2,243
Interest Expense
Long-Term Debt	17,888			18,254
Capital Leases	3,921			6,249
Other Interest Expense	483			(393		)
Interest Capitalized	(1,023		)	(675		)
Total Interest Expense	21,269			23,435
Income Before Income Taxes	25,143			18,703
Income Tax Expense	9,668			7,358
Net Income	$	15,475		$	11,345
Weighted-Average Shares of Common Stock Outstanding (000)
Basic	41,737			41,540
Diluted	42,084			41,875
Earnings Per Share
Basic	$	0.37		$	0.27
Diluted	$	0.37		$	0.27
Dividends Declared Per Share	$	0.48		$	0.435

See Notes to Condensed Consolidated Financial Statements.

1

UNS ENERGY CORPORATION

CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME

	Three Months Ended
	March 31,
	2014		2013
	(Unaudited)
	Thousands of Dollars
Comprehensive Income
Net Income	$	15,475	$	11,345
Other Comprehensive Income
Net Changes in Fair Value of Cash Flow Hedges, net of income tax (expense) benefit of $(356) and $(401)	493		612
SERP Benefit Amortization, net of income tax (expense) benefit of $(15) and $(42)	24		68
Total Other Comprehensive Income, Net of Tax	517		680
Total Comprehensive Income	$	15,992	$	12,025

See Notes to Condensed Consolidated Financial Statements.

2

UNS ENERGY CORPORATION

CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS

	Three Months Ended
	March 31,
	2014			2013
	(Unaudited)
	Thousands of Dollars
Cash Flows from Operating Activities
Cash Receipts from Electric Retail Sales	$	258,538		$	253,747
Cash Receipts from Gas Retail Sales	50,045			59,849
Cash Receipts from Electric Wholesale Sales	49,877			43,538
Cash Receipts from Operating Springerville Units 3 & 4	20,295			25,032
Cash Receipts from Gas Wholesale Sales	2,222			3,152
Interest Received	4			515
Other Cash Receipts	12,605			6,137
Purchased Energy Costs Paid	(75,688		)	(73,761		)
Fuel Costs Paid	(72,335		)	(76,321		)
Payment of Operations and Maintenance Costs	(68,337		)	(57,173		)
Wages Paid, Net of Amounts Capitalized	(39,692		)	(36,306		)
Taxes Other Than Income Taxes Paid, Net of Amounts Capitalized	(29,864		)	(32,237		)
Interest Paid, Net of Amounts Capitalized	(15,464		)	(17,784		)
Capital Lease Interest Paid	(13,682		)	(16,123		)
Other Cash Payments	(1,739		)	(1,212		)
Net Cash Flows—Operating Activities	76,785			81,053
Cash Flows from Investing Activities
Capital Expenditures	(88,244		)	(81,228		)
Return of Investments in Springerville Lease Debt	—			9,104
Other, net	1,726			(2,393		)
Net Cash Flows—Investing Activities	(86,518		)	(74,517		)
Cash Flows from Financing Activities
Proceeds from Borrowings Under Revolving Credit Facilities	120,000			66,000
Repayments of Borrowings Under Revolving Credit Facilities	(114,000		)	(35,000		)
Proceeds from Issuance of Long-Term Debt	149,168			—
Payments of Capital Lease Obligations	(79,737		)	(81,281		)
Common Stock Dividends Paid	(20,017		)	(18,035		)
Other, net	(801		)	1,762
Net Cash Flows—Financing Activities	54,613			(66,554		)
Net Increase (Decrease) in Cash and Cash Equivalents	44,880			(60,018		)
Cash and Cash Equivalents, Beginning of Year	74,878			123,918
Cash and Cash Equivalents, End of Period	$	119,758		$	63,900

See Note 11 for supplemental cash flow information.

See Notes to Condensed Consolidated Financial Statements.

3

UNS ENERGY CORPORATION

CONDENSED CONSOLIDATED BALANCE SHEETS

	March 31,			December 31,
	2014			2013
	(Unaudited)
	Thousands of Dollars
ASSETS
Utility Plant
Plant in Service	$	5,235,954		$	5,192,122
Utility Plant Under Capital Leases	637,957			637,957
Construction Work in Progress	211,357			201,959
Total Utility Plant	6,085,268			6,032,038
Less Accumulated Depreciation and Amortization	(1,998,610		)	(1,982,524		)
Less Accumulated Amortization of Capital Lease Assets	(519,860		)	(514,677		)
Total Utility Plant—Net	3,566,798			3,534,837
Investments and Other Property
Investments in Lease Equity	36,158			36,194
Other	34,960			34,971
Total Investments and Other Property	71,118			71,165
Current Assets
Cash and Cash Equivalents	119,758			74,878
Accounts Receivable—Customer	91,550			104,596
Unbilled Accounts Receivable	39,037			52,403
Allowance for Doubtful Accounts	(6,867		)	(6,833		)
Materials and Supplies	89,346			88,085
Deferred Income Taxes—Current	62,826			66,906
Regulatory Assets—Current	56,368			52,763
Fuel Inventory	46,113			44,317
Derivative Instruments	10,524			5,629
Other	16,044			15,354
Total Current Assets	524,699			498,098
Regulatory and Other Assets
Regulatory Assets—Noncurrent	156,468			150,584
Derivative Instruments	838			1,180
Other Assets	24,567			24,430
Total Regulatory and Other Assets	181,873			176,194
Total Assets	$	4,344,488		$	4,280,294

See Notes to Condensed Consolidated Financial Statements.

(Continued)

4

UNS ENERGY CORPORATION

CONDENSED CONSOLIDATED BALANCE SHEETS

	March 31,		December 31,
	2014		2013
	(Unaudited)
	Thousands of Dollars
CAPITALIZATION AND OTHER LIABILITIES
Capitalization
Common Stock Equity	$	1,125,824	$	1,130,784
Capital Lease Obligations	73,984		131,370
Long-Term Debt	1,659,278		1,507,070
Total Capitalization	2,859,086		2,769,224
Current Liabilities
Current Obligations Under Capital Leases	163,159		186,056
Borrowings Under Revolving Credit Facilities	25,000		22,000
Accounts Payable—Trade	100,507		117,503
Regulatory Liabilities—Current	54,285		53,935
Accrued Taxes Other than Income Taxes	55,577		43,880
Customer Deposits	28,943		30,671
Accrued Employee Expenses	22,806		28,148
Accrued Interest	21,906		27,786
Derivative Instruments	6,420		7,534
Other	20,394		17,775
Total Current Liabilities	498,997		535,288
Deferred Credits and Other Liabilities
Deferred Income Taxes—Noncurrent	491,212		488,887
Regulatory Liabilities—Noncurrent	308,873		302,482
Pension and Other Retiree Benefits	92,247		90,923
Derivative Instruments	7,355		7,100
Other	86,718		86,390
Total Deferred Credits and Other Liabilities	986,405		975,782
Commitments, Contingencies, and Environmental Matters (Note 6)
Total Capitalization and Other Liabilities	$	4,344,488	$	4,280,294

See Notes to Condensed Consolidated Financial Statements.

(Concluded)

5

UNS ENERGY CORPORATION

CONDENSED CONSOLIDATED STATEMENT OF CHANGES IN STOCKHOLDERS’ EQUITY

	Common Shares Outstanding *	Common Stock			Retained Earnings			Accumulated Other Comprehensive Loss			Total Stockholders’ Equity
	(Unaudited)
	Thousands of Shares	Thousands of Dollars
Balances at December 31, 2013	41,538	$	889,301		$	247,532		$	(6,049	)	$	1,130,784
Net Income					15,475						15,475
Other Comprehensive Income, net of tax								517			517
Dividends Declared					(20,186		)				(20,186		)
Shares Issued for Stock Options	20	594									594
Shares Issued under Performance Share Awards	101	—									—
Share-based Compensation		(1,360		)							(1,360		)
Balances at March 31, 2014	41,659	$	888,535		$	242,821		$	(5,532	)	$	1,125,824

* UNS Energy has 75 million authorized shares of Common Stock.

See Notes to Condensed Consolidated Financial Statements.

6

TUCSON ELECTRIC POWER COMPANY

CONDENSED CONSOLIDATED STATEMENTS OF INCOME

	Three Months Ended
	March 31,
	2014			2013
	(Unaudited)
	Thousands of Dollars
Operating Revenues
Electric Retail Sales	$	186,015		$	184,881
Electric Wholesale Sales	42,084			34,398
Other Revenues	27,414			28,472
Total Operating Revenues	255,513			247,751
Operating Expenses
Fuel	67,630			80,798
Purchased Power	22,615			18,928
Transmission and Other PPFAC Recoverable Costs	3,909			865
Increase (Decrease) to Reflect PPFAC Recovery Treatment	(1,730		)	(2,360		)
Total Fuel and Purchased Energy	92,424			98,231
Operations and Maintenance	81,345			77,824
Depreciation	30,811			28,558
Amortization	7,099			9,222
Taxes Other Than Income Taxes	11,835			11,169
Total Operating Expenses	223,514			225,004
Operating Income	31,999			22,747
Other Income (Deductions)
Interest Income	9			(4		)
Other Income	1,912			1,168
Other Expense	(2,115		)	(2,245		)
Appreciation in Fair Value of Investments	255			1,038
Total Other Income (Deductions)	61			(43		)
Interest Expense
Long-Term Debt	14,240			14,573
Capital Leases	3,921			6,249
Other Interest Expense	313			(360		)
Interest Capitalized	(924		)	(493		)
Total Interest Expense	17,550			19,969
Income Before Income Taxes	14,510			2,735
Income Tax Expense	5,338			1,257
Net Income	$	9,172		$	1,478

See Notes to Condensed Consolidated Financial Statements.

7

TUCSON ELECTRIC POWER COMPANY

CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME

	Three Months Ended
	March 31,
	2014		2013
	(Unaudited)
	Thousands of Dollars
Comprehensive Income
Net Income	$	9,172	$	1,478
Other Comprehensive Income (Loss)
Net Changes in Fair Value of Cash Flow Hedges, net of income tax (expense) benefit of $(346) and $(379)	481		580
SERP Benefit Amortization, net of income tax (expense) benefit of $(15) and $(42)	24		68
Total Other Comprehensive Income (Loss), Net of Tax	505		648
Total Comprehensive Income	$	9,677	$	2,126

See Notes to Condensed Consolidated Financial Statements.

8

TUCSON ELECTRIC POWER COMPANY

CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS

	Three Months Ended
	March 31,
	2014			2013
	(Unaudited)
	Thousands of Dollars
Cash Flows from Operating Activities
Cash Receipts from Electric Retail Sales	$	215,089		$	211,011
Cash Receipts from Electric Wholesale Sales	47,535			40,061
Cash Receipts from Operating Springerville Units 3 & 4	20,295			25,032
Reimbursement of Affiliate Charges	7,831			5,883
Cash Receipts from Gas Wholesale Sales	46			3,114
Interest Received	2			509
Other Cash Receipts	10,595			4,624
Fuel Costs Paid	(72,153		)	(76,560		)
Payment of Operations and Maintenance Costs	(66,154		)	(54,791		)
Wages Paid, Net of Amounts Capitalized	(33,124		)	(30,542		)
Taxes Other Than Income Taxes Paid, Net of Amounts Capitalized	(21,973		)	(23,303		)
Purchased Power Costs Paid	(18,892		)	(17,417		)
Capital Lease Interest Paid	(13,682		)	(16,123		)
Interest Paid, Net of Amounts Capitalized	(9,128		)	(11,239		)
Other Cash Payments	(973		)	(860		)
Net Cash Flows—Operating Activities	65,314			59,399
Cash Flows from Investing Activities
Capital Expenditures	(72,570		)	(61,668		)
Return of Investments in Springerville Lease Debt	—			9,104
Other, net	1,979			(2,911		)
Net Cash Flows—Investing Activities	(70,591		)	(55,475		)
Cash Flows from Financing Activities
Proceeds from Borrowings Under Revolving Credit Facility	105,000			55,000
Repayments of Borrowings Under Revolving Credit Facility	(105,000		)	(35,000		)
Proceeds from Issuance of Long-Term Debt	149,168			—
Payments of Capital Lease Obligations	(79,737		)	(81,281		)
Other, net	(1,468		)	(382		)
Net Cash Flows—Financing Activities	67,963			(61,663		)
Net Increase (Decrease) in Cash and Cash Equivalents	62,686			(57,739		)
Cash and Cash Equivalents, Beginning of Year	25,335			79,743
Cash and Cash Equivalents, End of Period	$	88,021		$	22,004

See Note 11 for supplemental cash flow information.

See Notes to Condensed Consolidated Financial Statements.

9

TUCSON ELECTRIC POWER COMPANY

CONDENSED CONSOLIDATED BALANCE SHEETS

	March 31,			December 31,
	2014			2013
	(Unaudited)
	Thousands of Dollars
ASSETS
Utility Plant
Plant in Service	$	4,493,282		$	4,467,667
Utility Plant Under Capital Leases	637,957			637,957
Construction Work in Progress	196,643			180,485
Total Utility Plant	5,327,882			5,286,109
Less Accumulated Depreciation and Amortization	(1,839,235		)	(1,826,977		)
Less Accumulated Amortization of Capital Lease Assets	(519,860		)	(514,677		)
Total Utility Plant—Net	2,968,787			2,944,455
Investments and Other Property
Investments in Lease Equity	36,158			36,194
Other	33,648			33,488
Total Investments and Other Property	69,806			69,682
Current Assets
Cash and Cash Equivalents	88,021			25,335
Accounts Receivable—Customer	72,458			80,211
Unbilled Accounts Receivable	27,705			34,369
Allowance for Doubtful Accounts	(4,791		)	(4,825		)
Accounts Receivable—Due from Affiliates	4,003			6,064
Materials and Supplies	76,586			75,200
Deferred Income Taxes—Current	66,771			70,722
Fuel Inventory	45,823			44,027
Regulatory Assets—Current	45,962			42,555
Derivative Instruments	3,906			2,137
Other	13,006			12,923
Total Current Assets	439,450			388,718
Regulatory and Other Assets
Regulatory Assets—Noncurrent	146,281			141,030
Derivative Instruments	167			167
Other Assets	19,364			19,233
Total Regulatory and Other Assets	165,812			160,430
Total Assets	$	3,643,855		$	3,563,285

See Notes to Condensed Consolidated Financial Statements.

(Continued)

10

TUCSON ELECTRIC POWER COMPANY

CONDENSED CONSOLIDATED BALANCE SHEETS

	March 31,		December 31,
	2014		2013
	(Unaudited)
	Thousands of Dollars
CAPITALIZATION AND OTHER LIABILITIES
Capitalization
Common Stock Equity	$	935,600	$	925,923
Capital Lease Obligations	73,984		131,370
Long-Term Debt	1,372,278		1,223,070
Total Capitalization	2,381,862		2,280,363
Current Liabilities
Current Obligations Under Capital Leases	163,159		186,056
Accounts Payable—Trade	79,515		88,556
Accounts Payable—Due to Affiliates	5,172		9,153
Accrued Taxes Other than Income Taxes	44,433		34,485
Accrued Employee Expenses	19,941		24,454
Regulatory Liabilities—Current	26,756		23,701
Accrued Interest	20,071		22,785
Customer Deposits	21,542		21,354
Derivative Instruments	5,065		5,531
Other	12,032		9,244
Total Current Liabilities	397,686		425,319
Deferred Credits and Other Liabilities
Deferred Income Taxes—Noncurrent	426,801		428,103
Regulatory Liabilities—Noncurrent	268,826		263,270
Pension and Other Retiree Benefits	85,933		84,936
Derivative Instruments	5,468		5,161
Other	77,279		76,133
Total Deferred Credits and Other Liabilities	864,307		857,603
Commitments, Contingencies, and Environmental Matters (Note 6)
Total Capitalization and Other Liabilities	$	3,643,855	$	3,563,285

See Notes to Condensed Consolidated Financial Statements.

(Concluded)

11

TUCSON ELECTRIC POWER COMPANY

CONDENSED CONSOLIDATED STATEMENT OF CHANGES IN STOCKHOLDER'S EQUITY

	Common Stock		Capital Stock Expense			Accumulated Earnings		Accumulated Other Comprehensive Loss			Total Stockholder’s Equity
	(Unaudited)
	Thousands of Dollars
Balances at December 31, 2013	$	888,971	$	(6,357	)	$	49,185	$	(5,876	)	$	925,923
Net Income						9,172					9,172
Other Comprehensive Income, net of tax								505			505
Balances at March 31, 2014	$	888,971	$	(6,357	)	$	58,357	$	(5,371	)	$	935,600

See Notes to Condensed Consolidated Financial Statements.

12

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

NOTE 1. NATURE OF OPERATIONS AND FINANCIAL STATEMENT PRESENTATION

UNS Energy Corporation (UNS Energy) is a holding company that conducts its business through three regulated public utilities: Tucson Electric Power Company (TEP); UNS Electric, Inc. (UNS Electric); and UNS Gas, Inc. (UNS Gas). References to “we” and “our” are to UNS Energy and its subsidiaries, collectively.

We prepared our condensed consolidated financial statements according to generally accepted accounting principles in the United States of America (GAAP) and the Securities and Exchange Commission's (SEC) interim reporting requirements. These condensed consolidated financial statements exclude some information and footnotes required by GAAP and the SEC for annual financial statement reporting. These condensed consolidated financial statements should be read in conjunction with the consolidated financial statements and footnotes in our 2013 Annual Report on Form 10-K.

The condensed consolidated financial statements are unaudited, but, in management's opinion, include all recurring adjustments necessary for a fair presentation of the results for the interim periods presented. Because weather and other factors cause seasonal fluctuations in sales, our quarterly results are not indicative of annual operating results. UNS Energy and TEP reclassified certain amounts in the financial statements to conform to current year presentation.

REVISION OF PRIOR PERIOD BALANCE SHEETS

UNS Energy and TEP revised their December 31, 2013 balance sheets to correct an error in the classification of capital lease obligations and related deferred income taxes. The correction increased current capital lease obligations and decreased noncurrent capital lease obligations by $18 million and increased current deferred tax assets and noncurrent deferred tax liabilities by $7 million. We do not believe the misclassification was material to the previously issued financial statements.

RECENTLY ADOPTED ACCOUNTING PRONOUNCEMENTS

In the first quarter of 2014, UNS Energy adopted accounting guidance that:

• requires an entity to recognize and disclose in the financial statements its obligation from a joint and several liability arrangement as the sum of the amount the entity agreed with its co-obligors that it will pay and any additional amount the entity expects to pay on behalf of its co-obligors. The adoption of this guidance did not have a material impact on our disclosures, financial condition, results of operations, or cash flows.

• impacts the financial statement presentation of unrecognized tax benefits when a net operating loss carryforward, a similar tax loss, or a tax credit carryforward exists. Although adoption and prospective application of this guidance impacted how such items are classified on our balance sheets, such change was not material. Additionally, there were no material changes in our results of operations or cash flows.

NOTE 2. PENDING MERGER WITH FORTIS

On December 11, 2013, UNS Energy announced that it had entered into an agreement and plan of merger, subject to shareholder and required regulatory approvals, to be acquired by FortisUS Inc., a Delaware corporation (Fortis) for $60.25 per share of Common Stock in cash. Following the merger, UNS Energy will continue as a wholly owned subsidiary of Fortis. The Board of Directors of each of UNS Energy and Fortis Parent have approved the merger. UNS Energy's shareholders approved the merger in March 2014. In April 2014, the Federal Energy Regulatory Commission (FERC) approved the merger.

The merger is subject to the remaining closing conditions:

• the expiration or termination of the applicable waiting period under the Hart-Scott-Rodino Antitrust Improvements Act of 1976, as amended;

• approval of the Arizona Corporation Commission (ACC);

• confirmation of review, without unresolved concerns, by the Committee on Foreign Investment in the United States; and

• the absence of any injunction, order or other law prohibiting the merger.

The merger, if approved, is expected to close by the end of 2014.

13

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)

NOTE 3. REGULATORY MATTERS

The ACC and the FERC each regulate portions of the utility accounting practices and rates of TEP, UNS Electric, and UNS Gas. The ACC regulates rates charged to retail customers, the siting of generation and transmission facilities, the issuance of securities, and transactions with affiliated parties. The FERC regulates terms and prices of transmission services and wholesale electricity sales. The pending merger with Fortis is subject to approval by the ACC. The FERC approved the merger in April 2014.

Purchased Power and Fuel Adjustment Clause

In April 2014, the ACC approved a Purchased Power and Fuel Adjustment Clause (PPFAC) rate for TEP of 0.1 cents per kWh for the period May through September 2014 and 0.5 cents per kWh for the period October 2014 through March 2015. TEP's PPFAC rate was a credit of 0.14 cents per kWh for the period July 2013 through April 2014.

San Juan Mine Fire Insurance Proceeds

In September 2011, a fire at the underground mine providing coal to San Juan Generating Station (San Juan) caused interruptions to mining operations and resulted in increased fuel costs. The 2013 TEP Rate Order required TEP to defer incremental fuel costs of $10 million from recovery under the PPFAC pending final resolution of an insurance claim by the San Juan Coal Company and distribution of insurance proceeds to San Juan participants. In March 2014, TEP received the first installment of its portion of the insurance settlement proceeds of $5 million. The proceeds offset the deferred costs and are reflected in our cash flow statements as an other operating cash receipt.

Energy Efficiency Standards

TEP, UNS Electric, and UNS Gas are required to implement cost-effective Demand Side Management (DSM) programs to comply with the ACC's Energy Efficiency (EE) Standards. The EE Standards provide for a DSM surcharge to recover, from retail customers, the costs to implement DSM programs as well as a performance incentive. In the first quarter of 2014, TEP recorded a DSM performance incentive of $2 million that is included in Electric Retail Sales in the UNS Energy and TEP income statements.

Lost Fixed Cost Recovery Mechanism

The Lost Fixed Cost Recovery (LFCR) mechanism provides recovery of certain non-fuel costs that would go unrecovered due to lost retail kWh sales as a result of implementing ACC approved energy efficiency programs and distributed generation targets.

During separate rate case proceedings in 2013, the ACC authorized LFCR mechanisms for TEP and UNS Electric, subject to a year-over-year cap of 1% of each company’s respective total retail revenues.

TEP and UNS Electric expect to file their first LFCR reports with the ACC on or before May 15, 2014. We expect the new LFCR rates to become effective on July 1, 2014, upon review by the ACC of verified lost retail kWh sales due to energy efficiency programs and distributed generation implemented in 2013.

TEP and UNS Electric recorded LFCR revenues of $5 million and $1 million, respectively, in the first quarter of 2014 related to reductions in retail kWh sales due to energy efficiency programs and distributed generation implemented in 2013.

We recognize LFCR revenue when verifiable regardless of when the lost retail kWh sales occur. LFCR revenue is included in Electric Retail Sales in the income statements.

NOTE 4. BUSINESS SEGMENTS

We have three reportable segments regularly reviewed by our chief operating decision makers to evaluate performance and make operating decisions.

(1) TEP, a regulated electric utility and our largest subsidiary

(2) UNS Electric, a regulated electric utility

14

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)

(3) UNS Gas, a regulated gas distribution utility

We disclose selected financial data for our reportable segments in the following tables:

	Reportable Segments
	TEP		UNS Electric		UNS Gas		Other (2)			Reconciling Adjustments			UNS Energy
	Millions of Dollars
Three Months Ended March 31, 2014:
Operating Revenues-External	$	252	$	40	$	41	$	—		$	—		$	333
Operating Revenues-Intersegment (1)	4		1		—		4			(9		)	—
Income Before Income Taxes	15		3		8		(1		)	—			25
Net Income	9		2		5		(1		)	—			15
Three Months Ended March 31, 2013:
Operating Revenues-External	$	244	$	36	$	52	$	—		$	—		$	332
Operating Revenues-Intersegment (1)	4		1		—		4			(9		)	—
Income Before Income Taxes	3		4		12		—			—			19
Net Income	1		2		8		—			—			11

⁽¹⁾  Operating Revenues-Intersegment includes common costs (system, facilities, etc.) allocated to affiliates on a cost-causative basis and recorded as revenue by TEP, sales of power between TEP and UNS Electric at third-party market prices, control area services provided by TEP to UNS Electric based on a FERC-approved tariff, sales of gas by UNS Gas at third-party market prices for use in UNS Electric's generating facilities, and supplemental workforce charges (primarily meter reading services) provided to the utilities by an unregulated affiliate.

⁽²⁾  Other includes the UNS Energy and UES holding companies, Millennium, and UED.

NOTE 5. DEBT AND CAPITAL LEASE OBLIGATIONS

We summarize below the significant changes to our debt and capital lease obligations from those reported in our 2013 Annual Report on Form 10-K.

2014 TEP UNSECURED NOTES ISSUED

In March 2014, TEP issued $150 million of 5.0% unsecured notes due March 2044. TEP may call the debt prior to September 15, 2043, with a make-whole premium plus accrued interest. After September 15, 2043, TEP may call the debt at par plus accrued interest. TEP used the net proceeds to repay approximately $90 million on the revolving credit facility, with the remaining proceeds to be applied to general corporate purposes. The unsecured notes contain a limitation on the amount of secured debt that TEP may have outstanding.

COVENANT COMPLIANCE

At March 31, 2014, we were in compliance with the terms of our loan and credit agreements.

TEP SPRINGERVILLE COAL HANDLING FACILITIES CAPITAL LEASE PURCHASE COMMITMENT

In April 2014, TEP notified the owner participants and their lessors that TEP has elected to purchase their undivided ownership interests in the Springerville Coal Handling Facilities at the fixed purchase price of $120 million upon the expiration of the lease term in April 2015. Due to TEP’s purchase commitment, TEP will record, in the second quarter of 2014, an increase to both Utility Plant Under Capital Leases and Capital Lease Obligations on its balance sheet in the amount of $109 million.

TEP previously agreed with Tri-State Generation and Transmission Association, Inc. (Tri-State), the lessee of Springerville Unit 3, and Salt River Project Agricultural Improvement and Power District (SRP), the owner of Springerville Unit 4, that if the Springerville Coal Handling Facilities Leases were not renewed, TEP would exercise the purchase option under those contracts. Upon TEP's purchase, SRP is obligated to buy a portion of the Springerville Coal Handling Facilities from TEP for approximately $24 million, and Tri-State is obligated to either 1) buy a portion of the facilities for approximately $24 million or 2) continue to make payments to TEP for the use of the facilities.

15

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)

NOTE 6. COMMITMENTS, CONTINGENCIES, AND ENVIRONMENTAL MATTERS

COMMITMENTS

UNS Energy's commitments represent the obligations of TEP, UNS Electric, and UNS Gas. In addition to those reported in our 2013 Annual Report on Form 10-K, UNS Energy entered into the following long-term commitments through March 31, 2014:

	UNS Energy Purchase Commitments
	2014		2015		2016		2017		2018		Thereafter		Total
	Millions of Dollars
Fuel, including Transportation	$	—	$	1	$	—	$	—	$	—	$	—	$	1
Purchased Power	—		15		—		—		—		—		15
Total Purchase Commitments	$	—	$	16	$	—	$	—	$	—	$	—	$	16

TEP entered into the following long-term commitments:

	TEP Purchase Commitments
	2014		2015		2016		2017		2018		Thereafter		Total
	Millions of Dollars
Purchased Power	$	—	$	7	$	—	$	—	$	—	$	—	$	7

In April 2014, TEP entered into agreements to purchase certain Springerville Coal Handling Facilities leased interests. See Note 5.

TEP CONTINGENCIES

Planned Purchase of Gas-Fired Generation Facility

In 2013, TEP and UNS Electric entered into an agreement to purchase a gas-fired generation facility. See Note 7.

Claim Related to San Juan Generating Station

San Juan Coal Company (SJCC) operates an underground coal mine in an area where certain gas producers have oil and gas leases with the federal government, the State of New Mexico, and private parties. These gas producers allege that SJCC’s underground coal mine interferes with their operations, reducing the amount of natural gas they can recover. SJCC compensated certain gas producers for any remaining production from wells deemed close enough to the mine to warrant plugging and abandoning them. These settlements, however, do not resolve all potential claims by gas producers in the area. TEP owns 50% of Units 1 and 2 at San Juan Generating Station (San Juan), which represents approximately 20% of the total generation capacity at San Juan, and is responsible for its share of any settlements. TEP cannot estimate the impact of any future claims by these gas producers on the cost of coal at San Juan.

In August 2013, the Bureau of Land Management (BLM) proposed regulations that, among other things, redefine the term “underground mine” to exclude high-wall mining operations and impose a higher surface mine coal royalty on high-wall mining. SJCC utilized high-wall mining techniques at its surface mines prior to beginning underground mining operations in January 2003. If the proposed regulations become effective, SJCC may be subject to additional royalties on coal delivered to San Juan between August 2000 and January 2003 totaling approximately $5 million of which TEP’s proportionate share would approximate $1 million. TEP cannot predict the final outcome of the BLM’s proposed regulations.

Claims Related to Four Corners Generating Station

In October 2011, EarthJustice, on behalf of several environmental organizations, filed a lawsuit in the United States District Court for the District of New Mexico against Arizona Public Service Company (APS) and the other Four Corners Generating Station (Four Corners) participants alleging violations of the Prevention of Significant Deterioration (PSD) provisions of the Clean Air Act at Four Corners. In January 2012, EarthJustice amended their complaint alleging violations of New Source Performance Standards resulting from equipment replacements at Four Corners. Among other things, the plaintiffs seek to have the court issue an order to cease operations at Four Corners until any required PSD permits are issued and order the payment of civil penalties, including a beneficial mitigation project. In April 2012, APS filed motions to dismiss with the court for all

16

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)

claims asserted by EarthJustice in the amended complaint. The joint participants have agreed to have the matter stayed until May 15, 2014 in furtherance of settlement talks.

TEP owns 7% of Four Corners Units 4 and 5 and is liable for its share of any resulting liabilities. TEP cannot predict the final outcome of the claims relating to Four Corners, and, due to the general and non-specific nature of the claims and the indeterminate scope and nature of the injunctive relief sought for this claim, TEP cannot determine estimates of the range of loss at this time. TEP accrued estimated losses of less than $1 million in 2011 for this claim based on its share of a settlement offer to resolve the claim.

In May 2013, the New Mexico Taxation and Revenue Department issued a notice of assessment for coal severance tax, penalties, and interest totaling $30 million to the coal supplier at Four Corners. In December 2013, the coal supplier and Four Corners’ operating agent filed a claim contesting the validity of the assessment on behalf of the participants in Four Corners, who will be liable for their share of any resulting liabilities. TEP’s share of the assessment based on its ownership of Four Corners is approximately $1 million. TEP cannot predict the outcome or timing of resolution of this claim.

Mine Closure Reclamation at Generating Stations Not Operated by TEP

TEP pays ongoing reclamation costs related to coal mines that supply generating stations in which TEP has an ownership interest but does not operate. TEP is liable for a portion of final reclamation costs upon closure of the mines servicing Navajo, San Juan, and Four Corners. TEP’s share of reclamation costs at all three mines is expected to be $44 million upon expiration of the coal supply agreements, which expire between 2017 and 2031. The reclamation liability (present value of future liability) recorded was $19 million at March 31, 2014 and $18 million at December 31, 2013.

Amounts recorded for final reclamation are subject to various assumptions, such as estimations of reclamation costs, the dates when final reclamation will occur, and the credit-adjusted risk-free interest rate to be used to discount future liabilities. As these assumptions change, TEP will prospectively adjust the expense amounts for final reclamation over the remaining coal supply agreements’ terms. TEP does not believe that recognition of its final reclamation obligations will be material to TEP in any single year because recognition will occur over the remaining terms of its coal supply agreements.

TEP’s PPFAC allows us to pass through most fuel costs, including final reclamation costs, to customers. Therefore, TEP classifies these costs as a regulatory asset by increasing the regulatory asset and the reclamation liability over the remaining life of the coal supply agreements and recovers the regulatory asset through the PPFAC as final mine reclamation costs are paid to the coal suppliers.

Discontinued Transmission Project

TEP and UNS Electric had initiated a project to jointly construct a 60-mile transmission line from Tucson, Arizona to Nogales, Arizona in response to an order by the ACC to UNS Electric to improve the reliability of electric service in Nogales. TEP and UNS Electric will not proceed with the project based on the cost of the proposed 345-kV line, the difficulty in reaching agreement with the United States Forest Service on a path for the line, and concurrence by the ACC of recent transmission plans filed by TEP and UNS Electric supporting elimination of this project. As part of the 2013 TEP Rate Order, TEP agreed to seek recovery of the project costs from FERC before seeking rate recovery from the ACC. In 2012, TEP wrote off $5 million of the capitalized costs believed not probable of recovery and recorded a regulatory asset of $5 million for the balance deemed probable of recovery.

Performance Guarantees

The participants in each of the remote generating stations in which TEP participates, including TEP, have guaranteed certain performance obligations of the other participants. Specifically, in the event of payment default of a participant, the non-defaulting participants have agreed to bear a proportionate share of expenses otherwise payable by the defaulting participant. In exchange, the non-defaulting participants are entitled to receive their proportionate share of the generating capacity of the defaulting participants. TEP's joint participation agreements expire in 2016 through 2046.

UNS ELECTRIC CONTINGENCIES

Planned Purchase of Gas-Fired Generation Facility

In 2013, TEP and UNS Electric entered into an agreement to purchase a gas-fired generation facility. See Note 7.

17

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)

ENVIRONMENTAL MATTERS

Environmental Regulation

The Environmental Protection Agency (EPA) limits the amount of sulfur dioxide (SO₂), nitrogen oxide (NOx), particulate matter, mercury and other emissions released into the atmosphere by power plants. TEP may incur added costs to comply with future changes in federal and state environmental laws, regulations, and permit requirements at its power plants. Complying with these changes may reduce operating efficiency. TEP expects to recover the cost of environmental compliance from its ratepayers.

Hazardous Air Pollutant Requirements

In February 2012, the EPA issued final rules for the control of mercury emissions and other hazardous air pollutants from power plants. Based on the EPA's final Mercury and Air Toxics (MATS) rules, additional emission control equipment will be required by April 2015. The operator of Navajo has received an extension until April 2016 to comply with the MATS rules. TEP's share of the estimated costs to comply with the MATS rules include the following:

Estimated Mercury Emissions Control Costs:	Navajo		Four Corners		Springerville
	Millions of Dollars
Capital Expenditures	$	1	$	1	$	5
Annual O&M Expenses	1		1		3

TEP expects Sundt and San Juan's current emission controls to be adequate to comply with the EPA's MATS rules.

Regional Haze Rules

The EPA's Regional Haze Rules require emission controls known as Best Available Retrofit Technology (BART) for certain industrial facilities emitting air pollutants that reduce visibility in national parks and wilderness areas. The rules call for all states to establish goals and emission reduction strategies for improving visibility. States must submit these goals and strategies to the EPA for approval. Because Navajo and Four Corners are located on the Navajo Indian Reservation, they are not subject to state oversight; the EPA oversees regional haze planning for these power plants.

In the western U.S., Regional Haze BART determinations have focused on controls for NOx, often resulting in a requirement to install selective catalytic reduction (SCR). Complying with the EPA’s BART rules, and with other future environmental rules, may make it economically impractical to continue operating the Navajo, San Juan, and Four Corners power plants or for individual owners to continue to participate in these power plants. TEP cannot predict the ultimate outcome of these matters.

TEP's estimated costs involved in meeting these rules are:

Estimated NOx Emissions Control Costs:	Navajo (1)		San Juan (2)		Four Corners (3)		Sundt (4)
	Millions of Dollars
Capital Expenditures	$	42	$	35	$	35	$	12
Annual O&M Expenses	1		1		2		5-6

⁽¹⁾ The EPA is considering a better-than-BART plan wherein: one unit at Navajo will be shut down by 2020; SCR (or the equivalent) will be installed on the remaining two units by 2030; and conventional coal-fired generation will cease by December 2044. TEP expects the EPA to reach a decision in 2014. In addition, the installation of SCR technology could increase particulates which may require that baghouses be installed. TEP owns 7.5% of Navajo. TEP's share of the capital cost of baghouses in addition to the SCR costs reflected in the table above is approximately $43 million with O&M on the baghouses expected to be less than $1 million per year.

⁽²⁾ The Federal Implementation Plan (FIP) for San Juan requires SCRs for which TEP estimates its share of capital costs will be $180-$200 million with annual O&M of $6 million. As part of a proposal for an alternative, Public Service Company of New Mexico (PNM), the State of New Mexico, and the EPA signed a non-binding agreement in which PNM agreed to close Units 2 and 3 by December 31, 2017 and install selective non-catalytic reduction (SNCR) on Units 1 and 4 by January 2016 or later depending on the timing of EPA approvals. These estimated costs are reflected in the table above. The State of New Mexico has submitted this plan to the EPA for approval. TEP expects the EPA will reach a decision in 2014. TEP owns 50% of San Juan Unit 2. At March 31, 2014, the net book value of TEP's share in San Juan Unit 2 was $112 million. If Unit 2 is retired early, TEP expects to request ACC approval to recover, over a reasonable time period, all costs associated with the early closure of the unit.

18

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)

⁽³⁾ In December 2013, APS, on behalf of the co-owners of Four Corners, notified the EPA that they have chosen an alternative BART compliance strategy; as a result, APS closed Units 1, 2, and 3 in December 2013 and has agreed to the installation of SCR on Units 4 & 5 by July 31, 2018. TEP owns 7% of Four Corners Units 4 and 5.

⁽⁴⁾ In January 2014, the EPA issued a proposal that would require TEP to either (i) install SNCR and dry sorbent injection technology on Unit 4 by mid-2017 or (ii) eliminate the use of coal by the end of 2017 as a better-than-BART alternative. Under the proposal, TEP would be required to notify the EPA of its decision by July 31, 2015. The EPA is expected to issue a final BART determination by July 2014. At March 31, 2014, the net book value of the Sundt coal handling facilities was $27 million. If the coal handling facilities are retired early, TEP expects to request ACC approval to recover, over a reasonable time period, all the remaining costs of the coal handling facilities.

BART provisions of Regional Haze Rules requiring emission control upgrades do not apply to Springerville because the plant was built after the BART-applicable dates.

NOTE 7. PLANNED PURCHASE OF GAS-FIRED GENERATION FACILITY

On December 23, 2013, TEP and UNS Electric entered into a purchase agreement with a subsidiary of Entegra to purchase Gila River Generating Station Unit 3 for $219 million, subject to certain closing adjustments. Gila River Unit 3, a gas-fired combined cycle unit with a nominal capacity rating of 550 MW, is located in Gila Bend, Arizona. TEP expects to purchase a 75% undivided interest in Gila River Unit 3 (413 MW) for approximately $164 million, and UNS Electric expects to purchase the remaining 25% undivided interest (137 MW) for approximately $55 million. TEP and UNS Electric expect the transaction to close in December 2014, subject to regulatory approvals and other closing conditions. In December 2013, UNS Electric filed an application for an accounting order with the ACC requesting authorization for UNS Electric to defer for future recovery specific non-fuel operating costs associated with Gila River Unit 3.

TEP expects to provide, in the second quarter of 2014, a letter of credit (LOC) for $15 million to the seller of Gila River Unit 3 to satisfy a condition of the purchase agreement. The seller would be entitled to draw upon the LOC and apply such amount as liquidated damages if it has validly terminated the purchase agreement as a result of misrepresentations by TEP and UNS Electric or the failure of TEP and UNS Electric to close the transaction when the closing conditions have been satisfied. Upon the close of the transaction, the LOC would be canceled.

NOTE 8. EMPLOYEE BENEFIT PLANS

UNS Energy’s net periodic benefit plan cost, comprised primarily of TEP's cost, includes the following components:

	Pension Benefits						Other Retiree Benefits
	Three Months Ended March 31,
	2014			2013			2014		2013
	Millions of Dollars
Service Cost	$	3		$	3		$	1	$	1
Interest Cost	4			4			1		1
Expected Return on Plan Assets	(6		)	(5		)	—		—
Actuarial Loss Amortization	1			2			—		—
Net Periodic Benefit Cost	$	2		$	4		$	2	$	2

NOTE 9. SHARE-BASED COMPENSATION PLANS

RESTRICTED STOCK UNITS

In February 2014, the UNS Energy Compensation Committee granted 16,910 restricted stock units to certain management employees at a grant date fair value, based on the grant date closing share price, of $60.39 per share. The restricted stock units vest on the third anniversary of grant and are distributed in shares of UNS Energy's Common Stock (Common Stock) upon vesting. We recognize compensation expense equal to the fair value on the grant date over the vesting period. These restricted stock units accrue dividend equivalents during the vesting period, which are distributed in shares of Common Stock upon vesting.

19

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)

PERFORMANCE SHARES

In February 2014, the UNS Energy Compensation Committee granted 33,820 performance share awards to certain management employees. Half of the performance share awards had a grant date fair value, based on a Monte Carlo simulation, of $57.47 per share. Those awards will be paid out in Common Stock based on UNS Energy’s compound annualized total shareholder return relative to the companies included in the Edison Electric Institute Utility Index for the three-year performance period ended December 31, 2016. We recognize compensation expense equal to the fair value on the grant date over the vesting period if the requisite service period is fulfilled, whether or not the threshold is achieved. The remaining half had a grant date fair value, based on the grant date closing share price, of $60.39 per share and will be paid out in Common Stock based on cumulative net income for the three-year performance period ended December 31, 2016. We recognize compensation expense equal to the fair value on the grant date over the requisite service period only for the awards that ultimately vest.

The performance shares vest based on the achievement of these goals by the end of the three-year performance period; any unearned awards are forfeited. Performance shares accrue dividend equivalents during the performance period, which are paid upon vesting.

SHARE-BASED COMPENSATION EXPENSE

UNS Energy and TEP recorded share-based compensation expense of less than $1 million for the three months ended March 31, 2014 and March 31, 2013.

At March 31, 2014, the total unrecognized compensation cost related to non-vested share-based compensation was $5 million, which will be recorded as compensation expense over the remaining vesting periods through February 2017. At March 31, 2014, less than 0.5 million shares were awarded but not yet issued, including target performance shares, under the share-based compensation plans.

NOTE 10. UNS ENERGY EARNINGS PER SHARE

We compute basic Earnings Per Share (EPS) by dividing Net Income by the weighted average number of common shares outstanding during the period. Diluted EPS reflects the potential dilution that could result if outstanding stock options or share-based compensation awards were exercised or converted into Common Stock. We excluded anti-dilutive contingently issuable shares from the calculation of diluted EPS.

The following table illustrates the effect of dilutive securities on net income and weighted average Common Stock outstanding:

	Three Months Ended March 31,
	2014		2013
	Thousands of Dollars
Numerator: Net Income	$	15,475	$	11,345
	Thousands of Shares
Denominator:
Weighted Average Shares of Common Stock Outstanding:
Common Shares Issued	41,619		41,381
Fully Vested Deferred Stock Units	118		159
Total Weighted Average Common Stock Outstanding — Basic	41,737		41,540
Effect of Dilutive Securities:
Options and Stock Issuable Under Share-Based Compensation Plans	347		335
Total Weighted Average Common Stock Outstanding — Diluted	42,084		41,875

For the three months ended March 31, 2013, we excluded 24,000 contingently issuable shares from our diluted EPS computation as their effect would be anti-dilutive.

20

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)

NOTE 11. SUPPLEMENTAL CASH FLOW INFORMATION

A reconciliation of Net Income to Net Cash Flows from Operating Activities follows:

	UNS Energy
	Three Months Ended March 31,
	2014			2013
	Thousands of Dollars
Net Income	$	15,475		$	11,345
Adjustments to Reconcile Net Income
To Net Cash Flows from Operating Activities
Depreciation Expense	39,081			36,300
Amortization Expense	6,176			8,289
Depreciation and Amortization Recorded to Fuel and O&M Expense	1,990			1,759
Amortization of Deferred Debt-Related Costs included in Interest Expense	785			750
Provision for Retail Customer Bad Debts	537			318
Use of Renewable Energy Credits for Compliance	5,528			3,870
Deferred Income Taxes	10,131			22,078
Pension and Retiree Expense	3,942			5,696
Pension and Retiree Funding	(1,694		)	(1,734		)
Share-Based Compensation Expense	985			722
Allowance for Equity Funds Used During Construction	(1,898		)	(1,175		)
Decrease to Reflect PPFAC/PGA Recovery	(8,920		)	(5,368		)
Changes in Assets and Liabilities which Provided (Used)
Cash Exclusive of Changes Shown Separately
Accounts Receivable	27,778			19,003
Materials and Fuel Inventory	(3,057		)	1,574
Accounts Payable	(12,387		)	(13,458		)
Income Taxes	(146		)	(16,028		)
Interest Accrued	(6,426		)	(9,974		)
Taxes Other Than Income Taxes	11,697			12,534
Other	(12,792		)	4,552
Net Cash Flows – Operating Activities	$	76,785		$	81,053

21

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)

	TEP
	Three Months Ended March 31,
	2014			2013
	Thousands of Dollars
Net Income	$	9,172		$	1,478
Adjustments to Reconcile Net Income
To Net Cash Flows from Operating Activities
Depreciation Expense	30,811			28,558
Amortization Expense	7,099			9,222
Depreciation and Amortization Recorded to Fuel and O&M Expense	1,704			1,493
Amortization of Deferred Debt-Related Costs Included in Interest Expense	635			601
Provision for Retail Customer Bad Debts	342			246
Use of RECs for Compliance	4,844			3,540
Deferred Income Taxes	5,635			12,276
Pension and Retiree Expense	3,412			4,970
Pension and Retiree Funding	(1,657		)	(1,676		)
Share-Based Compensation Expense	792			575
Allowance for Equity Funds Used During Construction	(1,721		)	(850		)
Decrease to Reflect PPFAC Recovery	(1,730		)	(2,360		)
Changes in Assets and Liabilities which Provided (Used)
Cash Exclusive of Changes Shown Separately
Accounts Receivable	16,274			11,408
Materials and Fuel Inventory	(3,182		)	1,654
Accounts Payable	(3,425		)	(6,094		)
Income Taxes	(5		)	(10,877		)
Interest Accrued	(3,260		)	(6,826		)
Taxes Other Than Income Taxes	9,948			10,068
Other	(10,374		)	1,993
Net Cash Flows – Operating Activities	$	65,314		$	59,399

NON-CASH TRANSACTIONS

In March 2013, TEP issued $91 million of tax-exempt bonds and used the proceeds to redeem debt using a trustee. Since the cash flowed through a trust account, the issuance and redemption of debt resulted in a non-cash transaction.

NOTE 12. FAIR VALUE MEASUREMENTS AND DERIVATIVE INSTRUMENTS

We categorize our assets and liabilities accounted for at fair value into the three-level hierarchy based on inputs used to determine the fair value. Level 1 inputs are unadjusted quoted prices for identical assets or liabilities in an active market. Level 2 inputs include quoted prices for similar assets or liabilities, quoted prices in non-active markets, and pricing models whose inputs are observable, directly or indirectly. Level 3 inputs are unobservable and supported by little or no market activity. Transfers between levels are recorded at the end of a reporting period. There were no transfers between levels in the periods presented.

22

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)

FINANCIAL INSTRUMENTS MEASURED AT FAIR VALUE ON A RECURRING BASIS

The following tables present, by level within the fair value hierarchy, UNS Energy’s and TEP’s assets and liabilities accounted for at fair value on a recurring basis. These assets and liabilities are classified in their entirety based on the lowest level of input that is significant to the fair value measurement.

	UNS Energy
	Total			Level 1		Level 2			Level 3			Counterparty Netting of Energy Contracts Not Offset on the Balance Sheets(5)			Net Amount
	March 31, 2014
	Millions of Dollars
Assets
Cash Equivalents(1)	$	74		$	74	$	—		$	—		$	—		$	74
Restricted Cash(1)	2			2		—			—			—			2
Rabbi Trust Investments(2)	23			—		23			—			—			23
Energy Contracts - Regulatory Recovery(3)	11			—		5			6			(5		)	6
Total Assets	110			76		28			6			(5		)	105
Liabilities
Energy Contracts - Regulatory Recovery(3)	(7		)	—		(2		)	(5		)	5			(2		)
Energy Contracts - Cash Flow Hedge(3)	(1		)	—		—			(1		)	—			(1		)
Interest Rate Swaps(4)	(6		)	—		(6		)	—			—			(6		)
Total Liabilities	(14		)	—		(8		)	(6		)	5			(9		)
Net Total Assets (Liabilities)	$	96		$	76	$	20		$	—		$	—		$	96

	UNS Energy
	Total			Level 1		Level 2			Level 3			Counterparty Netting of Energy Contracts Not Offset on the Balance Sheets(5)			Net Amount
	December 31, 2013
	Millions of Dollars
Assets
Cash Equivalents(1)	$	14		$	14	$	—		$	—		$	—		$	14
Restricted Cash(1)	2			2		—			—			—			2
Rabbi Trust Investments(2)	22			—		22			—			—			22
Energy Contracts - Regulatory Recovery(3)	7			—		3			4			(5		)	2
Total Assets	45			16		25			4			(5		)	40
Liabilities
Energy Contracts - Regulatory Recovery(3)	(7		)	—		(2		)	(5		)	5			(2		)
Energy Contracts - Cash Flow Hedge(3)	(1		)	—		—			(1		)	—			(1		)
Interest Rate Swaps(4)	(7		)	—		(7		)	—			—			(7		)
Total Liabilities	(15		)	—		(9		)	(6		)	5			(10		)
Net Total Assets (Liabilities)	$	30		$	16	$	16		$	(2	)	$	—		$	30

23

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)

	TEP
	Total			Level 1		Level 2			Level 3			Counterparty Netting of Energy Contracts Not Offset on the Balance Sheets(5)			Net Amount
	March 31, 2014
	Millions of Dollars
Assets
Cash Equivalents(1)	$	62		$	62	$	—		$	—		$	—		$	62
Restricted Cash(1)	2			2		—			—			—			2
Rabbi Trust Investments(2)	23			—		23			—			—			23
Energy Contracts - Regulatory Recovery(3)	4			—		2			2			(2		)	2
Total Assets	91			64		25			2			(2		)	89
Liabilities
Energy Contracts - Regulatory Recovery(3)	(4		)	—		(1		)	(3		)	2			(2		)
Energy Contracts - Cash Flow Hedge(3)	(1		)	—		—			(1		)	—			(1		)
Interest Rate Swaps(4)	(6		)	—		(6		)	—			—			(6		)
Total Liabilities	(11		)	—		(7		)	(4		)	2			(9		)
Net Total Assets (Liabilities)	$	80		$	64	$	18		$	(2	)	$	—		$	80

	TEP
	Total			Level 1		Level 2			Level 3			Counterparty Netting of Energy Contracts Not Offset on the Balance Sheets(5)			Net Amount
	December 31, 2013
	Millions of Dollars
Assets
Cash Equivalents(1)	$	—		$	—	$	—		$	—		$	—		$	—
Restricted Cash(1)	2			2		—			—			—			2
Rabbi Trust Investments(2)	22			—		22			—			—			22
Energy Contracts - Regulatory Recovery(3)	2			—		1			1			(1		)	1
Total Assets	26			2		23			1			(1		)	25
Liabilities
Energy Contracts - Regulatory Recovery(3)	(2		)	—		—			(2		)	1			(1		)
Energy Contracts - Cash Flow Hedge(3)	(1		)	—		—			(1		)	—			(1		)
Interest Rate Swaps(4)	(7		)	—		(7		)	—			—			(7		)
Total Liabilities	(10		)	—		(7		)	(3		)	1			(9		)
Net Total Assets (Liabilities)	$	16		$	2	$	16		$	(2	)	$	—		$	16

⁽¹⁾  Cash Equivalents and Restricted Cash represent amounts held in money market funds and certificates of deposit valued at cost, including interest. Cash Equivalents are included in Cash and Cash Equivalents on the balance sheets. Restricted Cash is included in Investments and Other Property – Other on the balance sheets.

⁽²⁾  Rabbi Trust Investments include amounts related to deferred compensation and Supplement Executive Retirement Plan (SERP) benefits held in mutual and money market funds valued at quoted prices traded in active markets. These investments are included in Investments and Other Property – Other on the balance sheets.

⁽³⁾  Energy Contracts include gas swap agreements (Level 2), power options (Level 2), gas options (Level 3), and forward power purchase and sales contracts (Level 3) entered into to reduce exposure to energy price risk. These contracts are included in Derivative Instruments on the UNS Energy and TEP balance sheets. The valuation techniques are described below.

(4) Interest Rate Swaps are valued based on the 3-month or 6-month LIBOR index or the Securities Industry and Financial Markets Association municipal swap index. These interest rate swaps are included in Derivative Instruments on the balance sheets.

⁽⁵⁾  All energy contracts are subject to legally enforceable master netting arrangements to mitigate credit risk. We have presented the effect of offset by counterparty; however, we present derivatives on a gross basis on the balance sheets.

24

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)

DERIVATIVE INSTRUMENTS

We enter into various derivative and non-derivative contracts to reduce our exposure to energy price risk associated with our gas and purchased power requirements. The objectives for entering into such contracts include: creating price stability; meeting load and reserve requirements; and reducing exposure to price volatility that may result from delayed recovery under the PPFAC or PGA.

We primarily apply the market approach for recurring fair value measurements. When we have observable inputs for substantially the full term of the asset or liability or use quoted prices in an inactive market, we categorize the instrument in Level 2. We categorize derivatives in Level 3 when we use an aggregate pricing service or published prices that represent a consensus reporting of multiple brokers.

For both power and gas prices we obtain quotes from brokers, major market participants, exchanges, or industry publications and rely on our own price experience from active transactions in the market. We primarily use one set of quotations each for power and for gas and then validate those prices using other sources. We believe that the market information provided is reflective of market conditions as of the time and date indicated.

Published prices for energy derivative contracts may not be available due to the nature of contract delivery terms such as non-standard time blocks and non-standard delivery points. In these cases, we apply adjustments based on historical price curve relationships, transmission, and line losses.

We estimate the fair value of our gas options using a Black-Scholes-Merton option pricing model which includes inputs such as implied volatility, interest rates, and forward price curves. In the first quarter of 2013, we also used this pricing model to value our power options.

We also consider the impact of counterparty credit risk using current and historical default and recovery rates, as well as our own credit risk using credit default swap data.

Our assessments of the significance of a particular input to the fair value measurements require judgment and may affect the valuation of fair value assets and liabilities and their placement within the fair value hierarchy levels. We review the assumptions underlying our price curves monthly.

Cash Flow Hedges

We enter into interest rate swaps to mitigate the exposure to volatility in variable interest rates on debt. The interest rate swap agreements expire through January 2020. We also have a power purchase swap to hedge the cash flow risk associated with a long-term power supply agreement. The power purchase swap agreement expires in September 2015. The after-tax unrealized gains and losses on cash flow hedge activities and amounts reclassified to earnings are reported in the statements of other comprehensive income and Note 13. The loss expected to be reclassified to earnings within the next twelve months is estimated to be $4 million for UNS Energy and $3 million for TEP.

Financial Impact of Energy Contracts

We record unrealized gains and losses on energy contracts that are recoverable through the PPFAC or PGA on the balance sheets as a regulatory asset or a regulatory liability rather than reporting the transaction in the income statements or in the statements of other comprehensive income, as shown in following tables:

	UNS Energy				TEP
	Three Months Ended March 31,
	2014		2013		2014		2013
	Millions of Dollars
Unrealized Net Gain (Loss) Recorded to Regulatory Assets/Liabilities	$	4	$	9	$	1	$	2

Realized gains and losses on settled contracts are fully recoverable through the PPFAC or PGA. At March 31, 2014, UNS Energy and TEP have energy contracts that will settle through the first quarter of 2017.

25

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)

Derivative Volumes

The volumes associated with our energy contracts were as follows:

	UNS Energy		TEP
	March 31, 2014	December 31, 2013	March 31, 2014	December 31, 2013
Power Contracts GWh	1,901	1,583	896	779
Gas Contracts GBtu	45,173	33,371	15,821	9,615

Level 3 Fair Value Measurements

The following table provides quantitative information regarding significant unobservable inputs in UNS Energy’s Level 3 fair value measurements:

		Fair Value at
		March 31, 2014						Range of
	Valuation Approach	Assets		Liabilities			Unobservable Inputs	Unobservable Input
		Millions of Dollars
Forward Contracts(1)	Market approach	$	3	$	(5	)	Market price per MWh	$	25.05		-	$	60.10
Option Contracts(2)	Option model	3		(1		)	Market price per MMbtu	$	3.77		-	$	4.66
							Gas volatility	19.81		%	-	31.62		%
Level 3 Energy Contracts		$	6	$	(6	)

⁽¹⁾  TEP comprises $1 million of the forward contract assets and $4 million of the forward contract liabilities.

⁽²⁾  TEP comprises $1 million of the option contract assets.

Changes in one or more of the unobservable inputs could have a significant impact on the fair value measurement depending on the magnitude of the change and the direction of the change for each input. The impact of changes to fair value, including changes from unobservable inputs, are subject to recovery or refund through the PPFAC or PGA mechanisms and are reported as a regulatory asset or regulatory liability, or as a component of other comprehensive income, rather than in the income statement.

The following tables present a reconciliation of changes in the fair value of assets and liabilities classified as Level 3 in the fair value hierarchy:

	UNS Energy			TEP
	Millions of Dollars
Balances at December 31, 2013	$	(2	)	$	(2	)
Realized/Unrealized Gains/(Losses) Recorded to:
Net Regulatory Assets/Liabilities – Derivative Instruments	3			(1		)
Settlements	(1		)	1
Balances at March 31, 2014	$	—		$	(2	)
Total Gains/(Losses) Attributable to the Change in Unrealized Gains/(Losses) Relating to Assets/Liabilities Still Held at the End of the Period	$	2		$	—

26

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)

	UNS Energy			TEP
	Millions of Dollars
Balances at December 31, 2012	$	(5	)	$	—
Realized/Unrealized Gains/(Losses) Recorded to:
Net Regulatory Assets/Liabilities – Derivative Instruments	1			(1		)
Settlements	1			—
Balances at March 31, 2013	$	(3	)	$	(1	)
Total Gains/(Losses) Attributable to the Change in Unrealized Gains/(Losses) Relating to Assets/Liabilities Still Held at the End of the Period	$	1		$	(1	)

CREDIT RISK

The use of contractual arrangements to manage the risks associated with changes in energy commodity prices creates credit risk exposure resulting from the possibility of non-performance by counterparties pursuant to the terms of their contractual obligations. We enter into contracts for the physical delivery of energy and gas which contain remedies in the event of non-performance by the supply counterparties. In addition, volatile energy prices can create significant credit exposure from energy market receivables and subsequent measurement at fair value.

We have contractual agreements for energy procurement and hedging activities that contain certain provisions requiring each company to post collateral under certain circumstances. These circumstances include: exposures in excess of unsecured credit limits provided to TEP, UNS Electric, or UNS Gas; credit rating downgrades; or a failure to meet certain financial ratios. In the event that such credit events were to occur, we would have to provide certain credit enhancements in the form of cash or LOCs to fully collateralize our exposure to these counterparties.

We consider the effect of counterparty credit risk in determining the fair value of derivative instruments that are in a net asset position after incorporating collateral posted by counterparties and allocate the credit risk adjustment to individual contracts. We also consider the impact of our own credit risk after considering collateral posted on instruments that are in a net liability position and allocate the credit risk adjustment to all individual contracts.

Material adverse changes could trigger credit risk-related contingent features. At March 31, 2014, the value of derivative instruments in a net liability position under contracts with credit risk-related contingent features, including contracts under the normal purchase normal sale exception, was $12 million for UNS Energy and $6 million for TEP. The additional collateral to be posted if credit-risk contingent features were triggered would be $12 million for UNS Energy and $6 million for TEP.

FINANCIAL INSTRUMENTS NOT CARRIED AT FAIR VALUE

The fair value of a financial instrument is the market price to sell an asset or transfer a liability at the measurement date. We use the following methods and assumptions for estimating the fair value of our financial instruments:

• The carrying amounts of our current liabilities, including current maturities of long-term debt, and amounts outstanding under our credit agreements approximate the fair values due to the short-term nature of these financial instruments. These items have been excluded from the table below.

• For Investment in Lease Equity, we estimate the price at which an investor would realize a target internal rate of return. Our estimates include: the mix of debt and equity an investor would use to finance the purchase; the cost of debt; the required return on equity; and income tax rates. The estimate assumes a residual value based on an appraisal of Springerville Unit 1 conducted in 2011.

• For Long-Term Debt, we use quoted market prices, when available, or calculate the present value of remaining cash flows at the balance sheet date. When calculating present value, we use current market rates for bonds with similar characteristics such as credit rating and time-to-maturity. We consider the principal amounts of variable rate debt outstanding to be reasonable estimates of the fair value. We also incorporate the impact of our own credit risk using a credit default swap rate.

27

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)

The use of different estimation methods and/or market assumptions may yield different estimated fair value amounts. The carrying values recorded on the balance sheets and the estimated fair values of our financial instruments include the following:

		March 31, 2014				December 31, 2013
	Fair Value Hierarchy	Carrying Value		Fair Value		Carrying Value		Fair Value
		Millions of Dollars
Assets:
TEP Investment in Lease Equity	Level 3	$	36	$	25	$	36	$	25
Liabilities:
Long-Term Debt
UNS Energy	Level 2	$	1,659	$	1,722	$	1,507	$	1,521
TEP	Level 2	1,372		1,407		1,223		1,214

NOTE 13. CHANGES IN ACCUMULATED OTHER COMPREHENSIVE INCOME BY COMPONENT

The realized changes in AOCI by component are as follows:

	UNS Energy
Details About Accumulated Other Comprehensive Income Components	Amount Reclassified from Other Comprehensive Income						Affected Line Item in the Income Statement
	Three Months Ended March 31,
	2014			2013
	Thousands of Dollars
Realized Losses on Cash Flow Hedges
Interest Rate Swaps - Debt	$	(353	)	$	(331	)	Interest Expense Long-Term Debt
Interest Rate Swaps - Capital Leases	(596		)	(604		)	Interest Expense Capital Leases
Tax Benefit	304			370
Realized Losses on Cash Flow Hedges, Net of Taxes	(645		)	(565		)
Amortization of SERP
Prior Service Costs and Net Loss	(39		)	(110		)	Operations and Maintenance
Tax Benefit	15			42
Amortization, Net of Taxes	(24		)	(68		)
Total Reclassifications from Other Comprehensive Income for the Period	$	(669	)	$	(633	)

28

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Concluded)

	TEP
Details About Accumulated Other Comprehensive Income Components	Amount Reclassified from Other Comprehensive Income						Affected Line Item in the Income Statement
	Three Months Ended March 31,
	2014			2013
	Thousands of Dollars
Realized Losses on Cash Flow Hedges
Interest Rate Swaps - Debt	$	(298	)	$	(281	)	Interest Expense Long-Term Debt
Interest Rate Swaps - Capital Leases	(596		)	(604		)	Interest Expense Capital Leases
Tax Benefit	284			350
Realized Losses on Cash Flow Hedges, Net of Taxes	(610		)	(535		)
Amortization of SERP
Prior Service Costs and Net Loss	(39		)	(110		)	Other Expense
Tax Benefit	15			42
Amortization, Net of Taxes	(24		)	(68		)
Total Reclassifications from Other Comprehensive Income for the Period	$	(634	)	$	(603	)

NOTE 14. RECENTLY ISSUED ACCOUNTING PRONOUNCEMENTS

In April 2014, the Financial Accounting Standards Board (FASB) issued an accounting standards update that changes the threshold for reporting discontinued operations and adds new disclosures. This guidance will be effective in the first quarter of 2015. We are evaluating the impact to our financial statements and disclosures.

29

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

Management’s Discussion and Analysis explains the results of operations, the general financial condition, and the outlook for UNS Energy and its three primary business segments. It includes the following:

• outlook and strategies;

• operating results during the first quarter of 2014 compared with the first quarter of 2013;

• factors affecting our results and outlook;

• liquidity, capital needs, capital resources, and contractual obligations;

• dividends; and

• critical accounting estimates.

UNS ENERGY CORPORATION

OVERVIEW OF CONSOLIDATED BUSINESS

UNS Energy is a utility services holding company engaged, through its subsidiaries, in the electric generation and energy delivery business. Each of UNS Energy’s subsidiaries is a separate legal entity with its own assets and liabilities. UNS Energy owns 100% of TEP, UniSource Energy Services, Inc. (UES), Millennium Energy Holdings, Inc. (Millennium), and UniSource Energy Development Company (UED).

TEP is a regulated utility and UNS Energy’s largest operating subsidiary, representing approximately 84% of UNS Energy’s total assets at March 31, 2014. TEP generates, transmits and distributes electricity to approximately 414,000 retail electric customers in a 1,155 square mile area in southeastern Arizona. TEP also sells electricity to other utilities and power marketing entities, located primarily in the western United States. In addition, TEP operates Springerville Generating Station (Springerville) Unit 3 on behalf of Tri-State and Springerville Unit 4 on behalf of SRP.

UES holds the common stock of two regulated utilities, UNS Electric and UNS Gas. UNS Electric is a regulated utility, which generates, transmits and distributes electricity to approximately 93,000 retail customers in Mohave and Santa Cruz counties in Arizona. UNS Gas is a regulated gas distribution company, which services approximately 150,000 retail customers in Mohave, Yavapai, Coconino, Navajo, and Santa Cruz counties in Arizona.

UED and Millennium’s investments in unregulated businesses represent less than 1% of UNS Energy’s assets as of March 31, 2014.

References in this report to “we” and “our” are to UNS Energy and its subsidiaries, collectively.

OUTLOOK AND STRATEGIES

Agreement and Plan of Merger

In December 2013, UNS Energy entered into an Agreement and Plan of Merger (Merger Agreement) with Fortis Parent, Fortis and Color Acquisition Sub, Inc. The Boards of Directors of each of UNS Energy and Fortis Parent have approved the Merger. At the completion of the Merger, each outstanding share of UNS Energy Common Stock will be converted into the right to receive $60.25 in cash and UNS Energy will become a wholly-owned subsidiary of Fortis.

UNS Energy's shareholders approved the merger at a meeting on March 26, 2014.

On April 2, 2014, the FERC issued an order approving the merger.

The merger is subject to the remaining closing conditions:

• the expiration or termination of the applicable waiting period under the Hart-Scott-Rodino Antitrust Improvements Act of 1976, as amended;

• approval of the ACC;

• confirmation of review, without unresolved concerns, from the Committee on Foreign Investment in the United States; and

• the absence of any injunction, order or other law prohibiting the merger.

30

In January 2014, UNS Energy and Fortis Parent filed an application and supporting testimony with the ACC requesting approval of the merger. Settlement discussions are scheduled to begin on May 5, 2014 and hearings before an ACC administrative law judge are expected to begin on June 16, 2014. The merger is expected to close by the end of 2014. If the merger is completed, UNS Energy expects to record approximately $19 million of merger-related expenses in 2014.

Operating Plans and Strategies

Our financial prospects and outlook are affected by many factors including: national, regional, and local economic conditions; volatility in the financial markets; environmental laws and regulations; and other regulatory factors. Our plans and strategies include the following:

• Completing the proposed merger with Fortis including obtaining all necessary approvals;

• Completing the purchases of Gila River Unit 3 and certain interests in Springerville Unit 1, which are both key components of our long-term diversification strategy for our generating portfolio. The focus of our resource strategy is to provide long-term rate stability for our customers, mitigate environmental impacts, comply with regulatory requirements, and leverage our existing utility infrastructure.

• Strengthening the underlying financial condition of our utility subsidiaries by achieving constructive regulatory outcomes, improving our capital structure and our credit ratings, and promoting economic development in our service territories.

• Developing strategic responses to new environmental regulations and potential new legislation, including potential limits on greenhouse gas emissions. We are evaluating TEP's existing mix of generation resources and defining steps to achieve environmental objectives that protect the financial stability of our utility businesses.

• Focusing on our core utility businesses through operational excellence, investing in utility rate base, emphasizing customer service, and maintaining a strong community presence.

• Developing strategic responses to Arizona’s requirements for renewable energy, distributed generation, and energy efficiency that protect the financial stability of our business while providing benefits for our customers.

RESULTS OF OPERATIONS

Contribution by Business Segment

The table below shows the contributions to our consolidated net income by business segment:

	Three Months Ended March 31,
	2014			2013
	Millions of Dollars
TEP	$	9		$	1
UNS Electric	2			2
UNS Gas	5			8
Other Non-Reportable Segments and Adjustments (1)	(1		)	—
Consolidated Net Income	$	15		$	11

⁽¹⁾  Includes: UNS Energy parent company expenses; Millennium; UED; and inter-company eliminations.

31

Executive Overview

First quarter2014 compared with first quarter2013

TEP

TEP reported net income of $9 million in first quarter of 2014 compared with net income of $1 million in the same period last year. The increase in net income is due to: a $7 million increase in retail margin revenues due to a Base Rate increase effective July 1, 2013; $5 million of LFCR revenues related to reductions in retail kWh sales due to energy efficiency programs and distributed generation implemented in 2013 (See Tucson Electric Power, Factors Affecting Results of Operations, 2013 TEP Rate Order and Note 3); a $1 million increase in the margin on long-term wholesale sales due to higher market prices for wholesale power; and a $2 million decrease in interest expense due in part to a reduction in capital lease obligation balances; partially offset by a $4 million increase in Base O&M due in part to planned maintenance on TEP's generating facilities, as well as merger-related expenses of $1 million; and a $1 million increase in taxes other than income taxes due in part to an increase in property tax rates and higher asset balances. See Tucson Electric Power, Results of Operations.

UNS Electric

UNS Electric reported net income of $2 million in both the first quarters of 2014 and 2013. See UNS Electric, Results of Operations.

UNS Gas

UNS Gas reported net income of $5 million in first quarter of 2014 compared with net income of $8 million in the same period last year. The decrease in net income is due primarily to lower sales volumes resulting from mild winter weather, which contributed to a decline in retail margin revenues. See UNS Gas, Results of Operations.

Operations and Maintenance Expense

The table below summarizes the items included in UNS Energy’s Operations and Maintenance (O&M) expense. Base O&M in first quarter of 2014 includes merger-related expenses of $1 million.

	Three Months Ended March 31,
	2014		2013
	Millions of Dollars
UNS Energy Base O&M (Non-GAAP)(1)	$	73	$	69
Reimbursed Expenses Related to Springerville Units 3 and 4	14		14
Expenses Related to Customer-Funded Renewable Energy and DSM Programs(2)	6		7
Total UNS Energy O&M (GAAP)	$	93	$	90

⁽¹⁾  Base O&M, a non-GAAP financial measure, should not be considered as an alternative to O&M, which is determined in accordance with GAAP. We believe Base O&M provides useful information to investors because it represents the fundamental level of operating and maintenance expense related to our core business. Base O&M excludes expenses that are directly offset by revenues collected from customers and other third parties.

⁽²⁾  Represents expenses related to customer-funded renewable energy and DSM programs; these expenses are being collected from customers and the corresponding amounts are recorded in retail revenue.

32

LIQUIDITY AND CAPITAL RESOURCES

UNS Energy Consolidated Liquidity

Cash flows may vary during the year, with cash flow from operations typically the lowest in the first quarter and highest in the third quarter due to TEP’s summer peaking load. As a result of the varied seasonal cash flow, UNS Energy will use, as needed, its revolving credit facility to assist in funding its business activities. The table below provides a summary of the liquidity position of UNS Energy and each of its segments:

Balances at March 31, 2014	Cash and  Cash Equivalents		Borrowings under Revolving Credit Facility(1)		Amount Available under Revolving Credit Facility
	Millions of Dollars
UNS Energy Stand-Alone	$	2	$	57	$	68
TEP	88		1		199
UNS Electric(2)	6		25		45
UNS Gas(2)	21		—		70
Other(3)	3		N/A		N/A
Total	$	120

⁽¹⁾  Includes LOCs issued under revolving credit facilities.

⁽²⁾  Either UNS Gas or UNS Electric may borrow up to a maximum of $70 million; the total combined amount borrowed by both companies cannot exceed $100 million.

⁽³⁾  Includes cash and cash equivalents at Millennium and UED.

TEP expects to provide, in the second quarter of 2014, an LOC for $15 million to the seller of Gila River Unit 3 to satisfy a condition of the purchase agreement. TEP's borrowing capacity under the TEP Credit Agreement would be reduced by $15 million until the Gila River transaction closes and the LOC is terminated.

Dividends from UNS Energy’s subsidiaries represent the parent company’s main source of liquidity.

Dividends from Subsidiaries

UNS Energy received $10 million of dividends from UNS Gas in first three months of 2014 and 2013.

Short-term Investments

UNS Energy’s short-term investment policy governs the investment of excess cash balances. We regularly review and update this policy in response to market conditions. At March 31, 2014, UNS Energy’s short-term investments included highly-rated and liquid money market funds and certificates of deposit.

Access to Revolving Credit Facilities

We have access to working capital through revolving credit agreements with lenders. Each of these agreements is a committed facility that expires in November 2016. The TEP Revolving Credit Facility and UNS Electric/UNS Gas Revolver may be used for revolving borrowings as well as to issue LOCs. TEP, UNS Electric, and UNS Gas each issue LOCs from time to time to provide credit enhancement to counterparties for their energy procurement and hedging activities. The UNS Credit Agreement also may be used to issue LOCs for general corporate purposes.

We believe that we have sufficient liquidity under our revolving credit facilities to meet short-term working capital needs and to provide credit enhancement as necessary under energy procurement and hedging agreements. See Item 3 Quantitative and Qualitative Disclosures about Market Risk.

33

UNS Energy Consolidated Cash Flows

	Three Months Ended March 31,
	2014			2013
	Millions of Dollars
Operating Activities	$	77		$	81
Investing Activities	(87		)	(75		)
Financing Activities	55			(66		)
Net Increase (Decrease) in Cash	45			(60		)
Beginning Cash	75			124
Ending Cash	$	120		$	64

UNS Energy’s operating cash flows are generated primarily by retail and wholesale energy sales at TEP, UNS Electric, and UNS Gas, net of the related payments for fuel and purchased power. Generally, cash from operations is lowest in the first quarter and highest in the third quarter due to TEP’s summer-peaking load. TEP, UNS Electric, and UNS Gas typically use their revolving credit facilities to assist in funding their business activities during periods when sales are seasonally lower.

Capital expenditures at TEP, UNS Electric, and UNS Gas represent the primary use of cash for investing activities.

Cash used for investing and financing activities can fluctuate year-to-year depending on: capital expenditures; repayments and borrowings under revolving credit facilities; debt issuances or retirements; capital lease payments by TEP; and dividends paid by UNS Energy to its shareholders.

Operating Activities

In the first three months of 2014, net cash flows from operating activities were $4 million lower than they were in the same period last year. The following items affected the quarter-over-quarter change in operating cash flows: an $11 million decrease in operating cash flows at UNS Gas due to the return of the over-collected PGA balance to customers; partially offset by a $2 million increase in cash receipts from retail and wholesale sales, net of fuel and purchased power costs paid, due to Base Rate increases at TEP and UNS Electric; a $2 million decrease in interest paid on capital lease obligations due to a decline in the balance of capital lease obligations; and a $2 million decrease in taxes paid, net of amounts capitalized, due to a decrease in sales tax rates effective in June 2013.

Investing Activities

Net cash flows used for investing activities increased $12 million in the first three months of 2014 compared with the same period last year due in part to a $9 million decrease in the return of investment in Springerville lease debt and a $7 million increase in capital expenditures.

Financing Activities

Net cash flows from financing activities were $121 million higher in the first three months of 2014 when compared with the same period last year due to: the issuance of $150 million of long-term debt by TEP in March 2014; partially offset by a $25 million decrease in borrowings (net of repayments) under the revolving credit facilities; and a $2 million increase in dividends paid on Common Stock.

UNS Credit Agreement

The UNS Credit Agreement, which expires in November 2016, consists of a $125 million revolving credit and LOC facility. At March 31, 2014, there was $57 million outstanding at a weighted-average interest rate of 1.41%. The UNS Credit Agreement restricts additional indebtedness, liens, mergers, and sales of assets. The UNS Credit Agreement also requires UNS Energy to meet a minimum cash flow to debt service coverage ratio determined on a UNS Energy stand-alone basis. Additionally, UNS Energy cannot exceed a maximum leverage ratio determined on a consolidated basis. Under the terms of the UNS Credit Agreement, UNS Energy may pay dividends so long as it maintains compliance with the agreement. UNS Energy’s obligations under the agreement are secured by a pledge of the common stock of Millennium, UES, and UED.

At March 31, 2014, we were in compliance with the terms of the UNS Credit Agreement.

34

Interest Rate Risk

UNS Energy is subject to interest rate risk resulting from changes in interest rates on its borrowings under the revolving credit facility. The interest paid on revolving credit borrowings is variable. UNS Energy may be required to pay higher rates of interest on borrowings under its revolving credit facility if LIBOR and other benchmark interest rates increase. See Item 3. Quantitative and Qualitative Disclosures about Market Risk.

Contractual Obligations

There are no changes in our contractual obligations or other commercial commitments from those reported in our 2013 Annual Report on Form 10-K, other than the following changes in 2014:

• In March 2014, TEP issued $150 million of 5.0% unsecured notes due March 2044. See Note 5.

• In April 2014, TEP notified the owner participants and their lessors that TEP has elected to purchase its undivided ownership interests in the Springerville Coal Handling Facilities at the fixed purchase price of $120 million upon the expiration of the lease term in April 2015. Upon TEP's purchase, SRP is obligated to buy a portion of the Springerville Coal Handling Facilities from TEP for approximately $24 million, and Tri-State is then obligated to either 1) buy a portion of the facilities for $24 million or 2) continue to make payments to TEP for the use of the facilities. See Note 5.

• We entered into new forward purchased power commitments with minimum payment obligations of $15 million in 2015. See Note 6.

• We entered into new forward energy commitments with minimum payment obligations of $1 million in 2015. See Note 6.

Dividends on Common Stock

In first three months of 2014, UNS Energy paid dividends on Common Stock of $20 million. The following table shows the dividends declared to UNS Energy shareholders for 2014:

Declaration Date	Record Date	Payment Date	Dividend Amount Per Share  of Common Stock
February 24, 2014	March 13, 2014	March 25, 2014	$	0.48

Income Tax Position

The 2010 Federal Tax Relief Act and the American Taxpayer Relief Act of 2012 include provisions that make qualified property placed in service between 2010 and 2013 eligible for bonus depreciation for tax purposes. In addition, the IRS issued new guidance related to the treatment of expenditures to maintain, replace, or improve property. These provisions are an acceleration of tax benefits UNS Energy and TEP otherwise would have received over 20 years. As a result of these provisions, UNS Energy and TEP do not expect to pay any federal or state income taxes through 2017.

35

TUCSON ELECTRIC POWER COMPANY

RESULTS OF OPERATIONS

TEP’s financial condition and results of operations are the principal factors affecting the financial condition and results of operations of UNS Energy. The following discussion relates to TEP, unless otherwise noted.

First quarterof2014 compared with the first quarterof2013

TEP reported net income of $9 million in the first quarter of 2014 compared with net income of $1 million in the first quarter of 2013. The following factors affected TEP’s results in the first quarter of 2014:

• a $7 million increase in retail margin revenues due to a Base Rate increase that was effective on July 1, 2013;

• $5 million of LFCR revenues recorded in the first quarter of 2014 related to reductions in retail kWh sales due to energy efficiency programs and distributed generation implemented in 2013. See Factors Affecting Results of Operations, 2013 TEP Rate Order, below, and Note 3;

• a $1 million increase in the margin on long-term wholesale sales due in part to an increase in the market price for wholesale power; and

• a $2 million decrease in interest expense due to a reduction in the balance of capital lease obligations;

partially offset by

• a $4 million increase in Base O&M due in part to scheduled generating plant maintenance expense, as well as merger-related expenses of $1 million; and

• a $1 million increase in taxes other than income taxes due in part to an increase in property tax rates and higher asset balances.

36

Utility Sales and Revenues

The table below provides a summary of TEP’s retail kWh sales, revenues, and weather data during the first quarters of 2014 and 2013:

	Three Months Ended March 31,				Increase (Decrease)
	2014		2013		Amount			Percent(1)
Energy Sales, kWh (in Millions):
Electric Retail Sales:
Residential	668		793		(125		)	(15.8	)%
Commercial(2)	444		451		(7		)	(1.6	)%
Industrial	471		473		(2		)	(0.4	)%
Mining	279		270		9			3.3	%
Other(2)	9		8		1			12.5	%
Total Electric Retail Sales	1,871		1,995		(124		)	(6.2	)%
Retail Margin Revenues (in Millions):
Residential	$	51	$	50	$	1		2.0	%
Commercial	34		34		—			—	%
Industrial	22		19		3			15.8	%
Mining	9		6		3			50.0	%
Other	1		1		—			—	%
Total Retail Margin Revenues (Non-GAAP)(3)	117		110		7			6.4	%
Fuel and Purchased Power Revenues	53		64		(11		)	(17.2	)%
RES, DSM, ECA, and LFCR Revenues	16		11		5			45.5	%
Total Retail Revenues (GAAP)	$	186	$	185	$	1		0.5	%
Average Retail Margin Rate (Cents / kWh):(1)
Residential	7.63		6.29		1.34			21.3	%
Commercial	7.66		7.54		0.12			1.6	%
Industrial	4.67		4.10		0.57			13.9	%
Mining	3.23		2.41		0.82			34.0	%
Other	11.11		12.50		(1.39		)	(11.1	)%
Average Retail Margin Revenue	6.25		5.51		0.74			13.4	%
Average Fuel and Purchased Power Revenue	2.83		3.22		(0.39		)	(12.1	)%
Average RES, DSM, ECA and LFCR Revenue	0.86		0.54		0.32			59.3	%
Total Average Retail Revenue	9.94		9.27		0.67			7.2	%
Weather Data:
Heating Degree Days
Three Months Ended March 31,	429		953		(524		)	(55.0	)%
10-Year Average	777		821		NM			NM

⁽¹⁾  Calculated on un-rounded data and may not correspond exactly to data shown in table.

⁽²⁾  Retail kWh sales to commercial and other customers for 2013 have been adjusted to reflect a change in the methodology for counting customers resulting from rate design changes from the 2013 TEP Rate Order.

⁽³⁾  Retail Margin Revenues, a non-GAAP financial measure, should not be considered as an alternative to Total Retail Revenues, which is determined in accordance with GAAP. Retail Margin Revenues exclude: (i) revenues collected from retail customers that are directly offset by expenses recorded in other line items; and (ii) revenues collected from third parties that are unrelated to kWh sales to retail customers. We believe the change in Retail Margin Revenues between periods provides useful information to investors because it demonstrates the underlying revenue trend and performance of our core utility business. Retail Margin Revenues represents the portion of retail operating revenues available to cover the non-fuel operating expenses of our core utility business.

37

Retail kWh Sales and Margin Revenues

TEP's total retail kWh sales decreased by 6.2% in the first quarter of 2014 primarily due to a 55.0% decrease in heating degree days compared with the first quarter of 2013. Despite the mild weather, total retail margin revenues increased by $7 million, or 6.4%, due to a Base Rate increase that was effective on July 1, 2013.

Mining kWh sales increased by 3.3% compared with the first quarter of 2013 due to one of TEP's customers performing maintenance on its facilities last year.

Wholesale Sales and Transmission Revenues

	Three Months Ended March 31,
	2014		2013
	Millions of Dollars
Long-Term Wholesale Revenues:
Long-Term Wholesale Margin Revenues (Non-GAAP)(1)	$	3	$	2
Fuel and Purchased Power Expense Allocated to Long- Term Wholesale Revenues	5		6
Total Long-Term Wholesale Revenues	8		8
Transmission Revenues	4		4
Short-Term Wholesale Revenues	30		22
Electric Wholesale Sales (GAAP)	$	42	$	34

⁽¹⁾  Long-term Wholesale Margin Revenues, a non-GAAP financial measure, should not be considered as an alternative to Electric Wholesale Sales, which is determined in accordance with GAAP. We believe the change in Long-Term Wholesale Margin Revenues between periods provides useful information to investors because it demonstrates the underlying profitability of TEP’s long-term wholesale sales contracts. Long-Term Wholesale Margin Revenues represents the portion of long-term wholesale revenues available to cover the operating expenses of our core utility business.

Long-Term Wholesale Margin Revenues in first quarter of 2014 were higher when compared with first quarter of 2013 due in part to higher market prices for wholesale power.

All revenues from short-term wholesale sales and 10% of the profits from wholesale trading activity are credited against the fuel and purchased power costs eligible for recovery in the PPFAC.

Other Revenues

	Three Months Ended March 31,
	2014		2013
	Millions of Dollars
Revenue related to Springerville Units 3 and 4(1)	$	21	$	21
Other Revenue	6		7
Total Other Revenue	$	27	$	28

⁽¹⁾ Represents revenues and reimbursements from Tri-State and SRP, owners of Springerville Units 3 and 4, respectively, to TEP related to the operation of these plants.

In addition to reimbursements related to Springerville Units 3 and 4, TEP’s other revenues include inter-company revenues from UNS Gas and UNS Electric for corporate services provided by TEP, and miscellaneous service-related revenues such as rent on power pole attachments, damage claims, and customer late fees.

Operating Expenses

Generating Output and Fuel and Purchased Power Expense

Total generating output decreased in the first quarter of 2014 when compared with first quarter of 2013 due in part to lower retail kWh sales than the same period last year.

38

TEP’s fuel and purchased power expense and energy resources for the first quarters of 2014 and 2013 are detailed below:

	Generation and Purchased Power				Fuel and Purchased Power Expense
	Three Months Ended March 31,
	2014		2013		2014			2013
	Millions of kWh				Millions of Dollars
Coal-Fired Generation	2,296		2,471		$	56		$	71
Gas-Fired Generation	239		186		11			8
Renewable Generation	10		11		—			—
Reimbursed Fuel Expense for Springerville Units 3 and 4	—		—		1			2
Total Fuel	2,545		2,668		68			81
Total Purchased Power	441		428		22			19
Transmission and Other PPFAC Recoverable Costs	—		—		4			1
Increase (Decrease) to Reflect PPFAC Recovery Treatment	—		—		(2		)	(3		)
Total Resources	2,986		3,096		$	92		$	98
Less Line Losses and Company Use	(169	)	(170	)
Total Energy Sold	2,817		2,926

The table below summarizes TEP’s average fuel cost per kWh generated or purchased:

	Three Months Ended March 31,
	2014	2013
	cents per kWh
Coal	2.42	2.87
Gas	4.61	4.36
Purchased Power	5.13	4.42
All Sources	3.34	3.44

O&M

The table below summarizes the items included in TEP’s O&M expense. Base O&M in first quarter of 2014 includes merger-related expenses of $1 million.

	Three Months Ended March 31,
	2014			2013
	Millions of Dollars
Base O&M (Non-GAAP)(1)	$	64		$	60
O&M Recorded in Other Expense	(2		)	(2		)
Reimbursed Expenses Related to Springerville Units 3 and 4	14			14
Expenses Related to Customer Funded Renewable Energy and DSM Programs(2)	5			6
Total O&M (GAAP)	$	81		$	78

⁽¹⁾  Base O&M is a non-GAAP financial measure and should not be considered as an alternative to O&M, which is determined in accordance with GAAP. TEP believes that Base O&M, which is O&M less reimbursed expenses and expenses related to customer-funded renewable energy and DSM programs, provides useful information to investors because it represents the fundamental level of operating and maintenance expense related to our core business.

⁽²⁾  Represents expenses related to customer-funded renewable energy and DSM programs; these expenses are being collected from customers and the corresponding amounts are recorded in retail revenue.

39

The table below summarizes TEP’s pension and other retiree benefit expenses included in TEP's Base O&M in the first quarters of 2014 and 2013:

	Three Months Ended March 31,
	2014		2013
	Millions of Dollars
Pension Expense Charged to O&M	$	2	$	3
Retiree Benefit Expense Charged to O&M	1		1
Total	$	3	$	4

FACTORS AFFECTING RESULTS OF OPERATIONS

2013 TEP Rate Order

In June 2013, the ACC issued an order (2013 TEP Rate Order) that approved new rates effective July 1, 2013. The provisions of the 2013 TEP Rate Order include, but are not limited to:

• An increase in Base Rates of approximately $76 million.

• A revision in depreciation rates from an average rate of 3.32% to 3.0% for generation and distribution plant regulated by the ACC, primarily due to revised estimates of asset removal costs, which will have the effect of reducing depreciation expense by approximately $11 million annually.

• An LFCR mechanism that allows TEP to recover certain non-fuel costs that would otherwise go unrecovered due to reduced retail kWh sales attributed to energy efficiency programs and distributed generation. The LFCR rate will be adjusted annually and is subject to ACC review and a year-over-year cap of 1% of TEP's total retail revenues. TEP expects to file its first LFCR report with the ACC on or before May 15, 2014. We expect the new LFCR rate to become effective on July 1, 2014. TEP recorded LFCR revenues of $5 million in the first quarter of 2014 related to reductions in retail kWh sales due to energy efficiency programs and distributed generation implemented in 2013. See Note 3.  TEP estimates that it will record total LFCR revenues of approximately $10 million during 2014.  

• An Environmental Compliance Adjustor (ECA) mechanism that allows TEP to recover the costs of complying with environmental standards required by federal or other governmental agencies between rate cases. The ECA will be adjusted annually to recover environmental compliance costs and is subject to ACC approval and a cap of $0.00025 per kWh, which approximates 0.25% of TEP's total retail revenues. TEP filed its first ECA report in March 2014 to recover the return on and of qualified investments of approximately $3 million. TEP expects the new ECA rate to become effective on May 1, 2014. TEP estimates that it will record total ECA revenues of less than $1 million in 2014.

Coal-Fired Generating Resources

At March 31, 2014 , approximately 70% of TEP's generating capacity was fueled by coal (of which 120 MW can be converted to 156 MW of natural gas capacity at Sundt Unit 4). Existing and proposed federal environmental regulations, as well potential changes in state regulation, may increase the cost of operating coal-fired generating facilities. TEP is evaluating various strategies for reducing the proportion of coal in its fuel mix. TEP's ability to reduce its coal-fired generating capacity will depend on several factors, including, but not limited to:

• the resolution of the non-binding agreement between the State of New Mexico, the EPA, and PNM as it relates to San Juan, see Part II, Item. 5 - Other Information, Environmental Matters;

• TEP's option to permanently convert Sundt Unit 4 to be fueled by natural gas, see Part II, Item. 5 - Other Information, Environmental Matters;

• TEP's future ownership interest in Springerville Unit 1, see Springerville Unit 1, below; and

• the planned purchase of Gila River Unit 3, a combined cycle natural gas plant, see Gila River Generating Station Unit 3, below.

40

Springerville Unit 1

TEP leases Unit 1 of the Springerville Generating Station and an undivided one-half interest in certain Springerville Common Facilities (collectively Springerville Unit 1) under seven separate lease agreements (Springerville Unit 1 Leases) that are accounted for as capital leases. The leases expire in January 2015 and include fair market value renewal and purchase options. In 2006, TEP purchased a 14.1% undivided ownership interest in Springerville Unit 1, representing approximately 55 MW of capacity.

In 2011, TEP and the owner participants of Springerville Unit 1 completed a formal appraisal procedure to determine the fair market value purchase price of Springerville Unit 1 in accordance with the Springerville Unit 1 Leases. The purchase price was determined to be $478 per kW of capacity based on a capacity rating of 387 MW.

During 2013, TEP agreed to purchase undivided ownership interests in Springerville Unit 1 totaling 35.4%, or 137 MW. The purchase price is the same as the appraisal value of $478 per kW, or approximately $65 million.

Upon the close of these lease option purchases in December 2014 and January 2015, TEP will own 49.5% of Springerville Unit 1, or 192 MW of capacity. Due to TEP’s purchase commitments, TEP and UNS Energy recorded an increase to both Utility Plant Under Capital Leases and Capital Lease Obligations on their balance sheets in the aggregate amount of approximately $55 million.

TEP does not expect that its final undivided ownership interest in Springerville Unit 1 will exceed 49.5%, or 192 MW of capacity. The remaining 50.5% of Springerville Unit 1, or 195 MW of capacity, will be owned by third parties. TEP is not obligated to purchase any of the remaining power from Springerville Unit 1; however, TEP is obligated to operate Springerville Unit 1 for the remaining third-party owners following the expiration of the leases. TEP expects to replace the 195 MW of expiring leased capacity with the purchase of Gila River Unit 3. See Gila River Generating Station Unit 3, below.

Gila River Generating Station Unit 3

In December 2013, TEP and UNS Electric entered into an agreement (the Purchase Agreement) to purchase Gila River Unit 3 for $219 million from a subsidiary of Entegra. The purchase price is subject to adjustments to prorate certain fees and expenses through the closing and in respect of certain operational matters. It is anticipated that TEP will purchase a 75% undivided interest in Gila River Unit 3 (413 MW) for approximately $164 million and UNS Electric will purchase the remaining 25% undivided interest (137 MW) for approximately $55 million, although TEP and UNS Electric may modify the percentage ownership allocation between them. We expect the transaction to close in December 2014.

The Purchase Agreement is subject to, among other things:

• the expiration or termination of the applicable waiting period under the Hart-Scott-Rodino Antitrust Improvements Act of 1976, as amended;

• the approval of the FERC;

• an amendment satisfactory to TEP, UNS Electric and the owners of the other units of the Gila River Power Station of the agreement with the other unit owners to address the ownership, operations and maintenance of common facilities and future generation located at the station;

• the completion of certain other agreements associated with the operation of Gila River Unit 3; and

• other customary closing conditions.

TEP expects to provide, in the second quarter of 2014, a LOC for $15 million to the seller of Gila River Unit 3 to satisfy a condition of the Purchase Agreement. The seller of Gila River Unit 3 would be entitled to draw upon the LOC and apply such amount as liquidated damages if it has validly terminated the Purchase Agreement as a result of misrepresentations by TEP and UNS Electric or the failure of TEP and UNS Electric to close the transaction when the closing conditions have been satisfied. Upon the close of the transaction, the LOC would be canceled.

The purchase of Gila River Unit 3, which would replace the expiring coal-fired leased capacity from Springerville Unit 1 and the expected reduction of coal-fired generating capacity from San Juan Unit 2, is consistent with TEP's strategy to diversify its generation fuel mix. See Note 6.

In December 2013, UNS Electric filed an application requesting the ACC to approve an accounting order that would authorize UNS Electric to defer for future recovery specific non-fuel operating costs associated with its anticipated ownership of 25% of

41

Gila River Unit 3. See UNS Electric, Factors Affecting Results of Operations, Gila River Generating Station Unit 3 and Note 7.

Springerville Coal Handling Facilities Leases

TEP leases interests in the coal handling facilities at the Springerville Generating Station (Springerville Coal Handling Facilities) under two separate lease agreements (Springerville Coal Handling Facilities Leases). The lease agreements have an initial term that expires in April 2015 and provide TEP the option to renew the leases or to purchase the leased interests at the aggregate fixed price of $120 million.

In April 2014, TEP notified the owner participants and their lessors that TEP has elected to purchase their undivided ownership interests in the facilities at the fixed purchase price of $120 million upon the expiration of the lease term in April 2015. Due to TEP’s purchase commitment, TEP will record, in the second quarter of 2014, an increase to both Utility Plant Under Capital Leases and Capital Lease Obligations on its balance sheets in the amount of $109 million.

TEP previously agreed with Tri-State, the lessee of Springerville Unit 3, and SRP, the owner of Springerville Unit 4, that if the Springerville Coal Handling Facilities Leases were not renewed, TEP would exercise the purchase option under those contracts. Upon TEP’s purchase, SRP is obligated to buy a portion of the Springerville Coal Handling Facilities from TEP for approximately $24 million and Tri-State is obligated to either 1) buy a portion of the facilities for approximately $24 million or 2) continue to make payments to TEP for the use of the facilities.

Sales to Mining Customers

TEP's mining customers have indicated they are taking initial steps to increase production either through expansion of their current mining operations or by the re-opening of non-operational mine sites. If efforts to increase production are successful, TEP's mining load could increase by up to 100 MW over the next several years. The market price for copper and the ability to obtain necessary permits could affect the mining industry's expansion plans.

In addition to the mining customers that TEP currently serves, Augusta Resources Corporation filed a plan of operations with the United States Forest Service in 2007 for the proposed Rosemont Copper Mine near Tucson, Arizona.  The Rosemont Copper Mine requires electric service from TEP via a 138 kilo-volt (kV) transmission line for the construction and ongoing operation of the mine. The state line siting committee approved a Certificate of Environmental Compatibility (CEC) in 2011 for the 138 kV transmission line. In 2012, the ACC finalized the CEC. If the Rosemont Copper Mine is constructed and reaches full production, it would be expected to become TEP's largest retail customer, with TEP serving the mine's estimated load of approximately 85 MW.

TEP cannot predict if or when existing mines will expand operations or new or re-opened mines will commence operations.

Springerville Units 3 and 4

TEP receives annual benefits in the form of rental payments and other fees and cost savings from operating Springerville Unit 3 on behalf of Tri-State and Unit 4 on behalf of SRP.

The table below summarizes the income statement line items in which TEP records revenues and expenses related to Springerville Units 3 and 4:

	Three Months Ended March 31,
	2014			2013
	Millions of Dollars
Other Revenues	$	21		$	21
Fuel Expense	(1		)	(2		)
O&M Expense	(14		)	(14		)

Interest Rates

See Item 3. Quantitative and Qualitative Disclosures about Market Risk.

Fair Value Measurements

See Note 12.

42

LIQUIDITY AND CAPITAL RESOURCES

TEP Cash Flows

The tables below show TEP's net cash flows after capital expenditures, scheduled lease debt payments, and payments on capital lease obligations:

	Three Months Ended March 31,
	2014			2013
	Millions of Dollars
Net Cash Flows – Operating Activities (GAAP)	$	65		$	59
Less: Capital Expenditures	(73		)	(62		)
Net Cash Flows after Capital Expenditures (Non-GAAP)(1)	(8		)	(3		)
Less: Payments of Capital Lease Obligations	(80		)	(81		)
Plus: Proceeds from Investment in Lease Debt	—			9
Net Cash Flows after Capital Expenditures and Required Payments on Lease Debt and Capital Lease Obligations (Non-GAAP)(1)	$	(88	)	$	(75	)

	Three Months Ended March 31,
	2014			2013
	Millions of Dollars
Net Cash Flows – Operating Activities (GAAP)	$	65		$	59
Net Cash Flows – Investing Activities (GAAP)	(70		)	(55		)
Net Cash Flows – Financing Activities (GAAP)	68			(62		)
Net Increase (Decrease) in Cash	63			(58		)
Beginning Cash	25			80
Ending Cash	$	88		$	22

⁽¹⁾  Net Cash Flows after Capital Expenditures and Net Cash Flows after Capital Expenditures and Required Payments on Lease Debt and Capital Lease Obligations, both non-GAAP measures of liquidity, should not be considered as alternatives to Net Cash Flows—Operating Activities, which is determined in accordance with GAAP. We believe that Net Cash Flows after Capital Expenditures and Net Cash Flows after Capital Expenditures and Required Payments on Lease Debt and Capital Lease Obligations provide useful information to investors as measures of TEP’s ability to fund capital requirements, make required payments on lease debt and capital lease obligations, and pay dividends to UNS Energy before consideration of financing activities.

Liquidity Outlook

Cash flows may vary during the year, with cash flow from operations typically the lowest in the first quarter and highest in the third quarter due to TEP’s summer peaking load. As a result of the varied seasonal cash flow, TEP will use, as needed, its revolving credit facility to assist in funding its business activities.

If the Merger Agreement is approved by all necessary parties, Fortis will contribute $200 million of equity capital to UNS Energy upon closing. If the contribution is made by December 2014, UNS Energy may then contribute this capital to TEP and UNS Electric to help fund the Gila River Unit 3 and Springerville Unit 1 purchase commitments.

Operating Activities

In the first three months of 2014, net cash flows from operating activities were $6 million higher than in the same period last year. The increase was due primarily to: a Base Rate increase at TEP that was effective on July 1, 2013; and lower interest paid on capital leases; partially offset by an increase in O&M paid due to planned maintenance outages and merger-related costs.

Investing Activities

Net cash flows used for investing activities increased by $15 million in the first three months of 2014 compared with the same period last year due primarily to an $11 million increase in capital expenditures related primarily to scheduled outage work performed on our generating facilities.

43

Financing Activities

In the first three months of 2014, net cash from financing activities was $130 million higher than the same period last year due to proceeds from the issuance of $150 million of long-term debt offset by $20 million more in repayments (net of borrowings) under the TEP Revolving Credit Facility.

2014 Bond Issuances

In March 2014, TEP issued $150 million of unsecured notes. The bonds bear interest at a fixed rate of 5.0%, mature in March 2044, and may be redeemed at par on or after September 15, 2043. The proceeds of the bond issuance were used to repay approximately $90 million outstanding under TEP's revolving credit facility, with the remaining proceeds to be applied to general corporate purposes. See Note 5.

TEP Credit Agreement

The TEP Credit Agreement consists of a $200 million revolving credit, revolving LOC facility and an $82 million LOC facility to support tax-exempt bonds. The TEP Credit Agreement expires in November 2016.

TEP expects to provide, in the second quarter of 2014, an LOC for $15 million to the seller of Gila River Unit 3 to satisfy a condition of the purchase agreement. TEP's borrowing capacity under the TEP Credit Agreement would be reduced by $15 million until the Gila River transaction closes and the LOC is terminated.

At March 31, 2014, there were no outstanding borrowings and there were $1 million of LOCs issued under the TEP Revolving Credit Facility.

The TEP Credit Agreement contains restrictions on mergers and sale of assets. The TEP Credit Agreement also requires TEP not to exceed a maximum leverage ratio. If TEP complies with the terms of the TEP Credit Agreement, TEP may pay dividends to UNS Energy. At March 31, 2014, TEP was in compliance with the terms of the TEP Credit Agreement. See Note 5.

2010 TEP Reimbursement Agreement

In December 2010, TEP entered into a four-year $37 million reimbursement agreement (2010 TEP Reimbursement Agreement). A $37 million LOC was issued pursuant to the 2010 TEP Reimbursement Agreement. The LOC supports $37 million aggregate principal amount of variable rate tax-exempt pollution control bonds that were issued on behalf of TEP in December 2010.

In February 2014, TEP amended the 2010 TEP Reimbursement Agreement to extend the expiration date of the LOC from 2014 to 2019.

The 2010 TEP Reimbursement Agreement contains substantially the same restrictive covenants as the TEP Credit Agreement described above. At March 31, 2014, TEP was in compliance with the terms of the 2010 TEP Reimbursement Agreement. See Note 5.

Capital Lease Obligations

At March 31, 2014, TEP had $237 million of total capital lease obligations on its balance sheet. The table below provides a summary of the outstanding lease obligations:

	Capital Lease  Obligation Balance As Of
Capital Leases	March 31, 2014		Expiration	Renewal/Purchase Option
	Millions of Dollars
Springerville Unit 1(1)	$	128	2015	Fair market value
Springerville Coal Handling Facilities	22		2015	Fixed price purchase option of $120 million(2)
Springerville Common Facilities(3)	87		2017 and 2021	Fixed price purchase option of $106 million(3)
Total Capital Lease Obligations	$	237

⁽¹⁾  The Springerville Unit 1 Leases cover both Unit 1 and an undivided one-half interest in certain Springerville Common Facilities. The $128 million balance includes the present value of the lease purchase options agreed to in 2013.

44

⁽²⁾  The $22 million balance does not include the $109 million present value of the lease purchase options elected in April 2014. Upon TEP’s purchase, SRP is obligated to buy a portion of the Springerville Coal Handling Facilities from TEP for approximately $24 million and Tri-State is obligated to either 1) buy a portion of the facilities for approximately $24 million or 2) continue to make payments to TEP for the use of the facilities. See Factors Affecting Results of Operations, Springerville Coal Handling Facilities Leases. Also see Note 5.

⁽³⁾  The Springerville Common Facilities Leases cover an undivided one-half interest in certain Springerville Common Facilities.

TEP's capital lease obligation balances decline over time due to the normal capital lease payments made by TEP.

Income Tax Position

See UNS Energy Consolidated, Liquidity and Capital Resources, Income Tax Position.

Contractual Obligations

There have been no changes in TEP's contractual obligations or other commercial commitments from those reported in our 2013 Annual Report on Form 10-K, other than the following changes in 2014:

• In March 2014, TEP issued $150 million of 5.0% unsecured notes due March 2044. See Note 5.

• In April 2014, TEP notified the owner participants and their lessors that TEP has elected to purchase its undivided ownership interests in the Springerville Coal Handling Facilities at the fixed purchase price of $120 million upon the expiration of the lease term in April 2015. Upon TEP's purchase, SRP is obligated to buy a portion of the Springerville Coal Handling Facilities from TEP for approximately $24 million, and Tri-State is obligated to either 1) buy a portion of the facilities for $24 million or 2) continue to make payments to TEP for the use of the facilities. See Note 5.

• TEP entered into new forward purchased power commitments with minimum payment obligations of $7 million in 2015. See Note 6.

See UNS Energy Consolidated, Liquidity and Capital Resources, Contractual Obligations, for a description of these obligations.

We have reviewed our contractual obligations and provide the following additional information:

• The TEP Credit Agreement, the 2010 Reimbursement Agreement, and the 2013 Covenants Agreement contain pricing based on TEP’s credit ratings. A change in TEP’s credit ratings can cause an increase or decrease in the amount of interest TEP pays on its borrowings, and the amount of fees it pays for its LOCs and unused commitments. A downgrade in TEP’s credit ratings would not cause a restriction in TEP’s ability to borrow under its revolving credit facility.

• The TEP Credit Agreement, the 2010 Reimbursement Agreement, and the 2013 Covenants Agreement contain certain financial and other restrictive covenants, including a leverage test. Failure to comply with these covenants would entitle the lenders to accelerate the maturity of all amounts outstanding. At March 31, 2014, TEP was in compliance with these covenants. See TEP Credit Agreement, above.

• TEP conducts its wholesale marketing and risk management activities under certain master agreements whereby TEP may be required to post credit enhancements in the form of cash or an LOC due to exposures exceeding unsecured credit limits provided to TEP, changes in contract values, a change in TEP’s credit ratings, or if there has been a material change in TEP’s creditworthiness. As of March 31, 2014, TEP had posted less than $1 million in LOCs as collateral with counterparties for credit enhancement.

Dividends on Common Stock

TEP did not pay any dividends to UNS Energy in the first quarters of 2014 or 2013.

TEP can pay dividends to UNS Energy if it maintains compliance with the TEP Credit Agreement, the 2010 TEP Reimbursement Agreement and the 2013 Covenants Agreement. At March 31, 2014, TEP was in compliance with the terms of the TEP Credit Agreement, the 2010 TEP Reimbursement Agreement and the 2013 Covenants Agreement.

45

UNS ELECTRIC

RESULTS OF OPERATIONS

UNS Electric reported net income of $2 million in both the first quarter of 2014 and first quarter of 2013.

Like TEP, UNS Electric’s operations are typically seasonal in nature, with peak energy demand occurring in the summer months. The table below provides summary financial information for UNS Electric:

	Three Months Ended March 31,
	2014		2013
	Millions of Dollars
Retail Electric Revenues	$	39	$	36
Wholesale Electric Revenues	2		1
Total Operating Revenues	41		37
Purchased Energy Expense	18		17
Fuel Expense	—		1
Transmission Expense	3		3
Increase (Decrease) to Reflect PPFAC Recovery	1		(2		)
O&M	7		7
Depreciation and Amortization Expense	5		5
Taxes Other Than Income Taxes	2		1
Total Operating Expenses	36		32
Operating Income	5		5
Interest Expense	2		1
Income Tax Expense	1		2
Net Income	$	2	$	2

46

The table below shows UNS Electric’s kWh sales and margin revenues:

	Three Months Ended March 31,
	2014		2013		Amount			Percent(1)
Electric Retail Sales, kWh (in Millions):
Residential	159		190		(31		)	(16.3	)%
Commercial	131		128		3			2.3	%
Industrial	44		42		2			4.8	%
Mining	14		13		1			7.7	%
Other	1		1		—			—	%
Total Electric Retail Sales	349		374		(25		)	(6.7	)%
Retail Margin Revenues (in Millions):
Residential	$	7	$	7	$	—		—	%
Commercial	6		6		—			—	%
Industrial	2		2		—			—	%
Mining	1		2		(1		)	(50.0	)%
Other	—		—		—			—	%
Total Retail Margin Revenues (Non-GAAP)(2)	16		17		(1		)	(5.9	)%
Fuel and Purchased Power Revenues	20		17		3			17.6	%
RES, DSM, & LFCR Revenues	3		2		1			50.0	%
Total Retail Revenues (GAAP)	$	39	$	36	$	3		8.3	%
Weather Data:
Heating Degree Days
Three Months Ended March 31,	748		1,160		(412		)	(35.5	)%
10-Year Average	1,088		1,102		NM			NM

⁽¹⁾  Percent change calculated on un-rounded data and may not correspond exactly to data shown in table.

⁽²⁾  Total Retail Margin Revenues, a non-GAAP financial measure, should not be considered as an alternative to Total Retail Revenues, which is determined in accordance with GAAP. Total Retail Margin Revenues exclude revenues collected from retail customers that are directly offset by expenses recorded in other line items. We believe the change in Total Retail Margin Revenues between periods provides useful information to investors because it demonstrates the underlying revenue trend and performance of our core utility business. Total Retail Margin Revenues represents the portion of retail operating revenues available to cover the non-fuel operating expenses of our core utility business.

In the first quarter of 2014, total retail kWh sales decreased by 6.7% compared with the first quarter of 2013 due primarily to a 36% decrease in heating-degree days. Despite lower retail kWh sales, retail margin revenues decreased by just $1 million, or 5.9%, due to a Base Rate increase that was effective on January 1, 2014. UNS Electric recorded LFCR revenues of $1 million in the first quarter of 2014, a portion of which relates to reductions in 2013 retail kWh sales due to energy efficiency programs and distributed generation.

FACTORS AFFECTING RESULTS OF OPERATIONS

2013 UNS Electric Rate Order

In December 2013, the ACC approved a new rate structure for UNS Electric that became effective on January 1, 2014 (2013 UNS Electric Rate Order). The provisions of the 2013 UNS Electric Rate Order include, but are not limited to:

• an increase in Base Rates of approximately $3 million;

• an LFCR mechanism that will allow UNS Electric to recover certain non-fuel costs that would otherwise go unrecovered due to reduced retail kWh sales attributed to compliance with the ACC's Electric EE Standards and distributed generation requirements under the ACC's RES. The LFCR rate will be adjusted annually and is subject to ACC review and a year-over-year cap of 1% of UNS Electric's total retail revenues. The LFCR is not a full

47

decoupling mechanism because it is not intended to recover lost fixed costs attributable to weather or economic conditions. UNS Electric expects to file its first LFCR report with the ACC on or before May 15, 2014. We expect the new LFCR rate to become effective on July 1, 2014. UNS Electric recorded LFCR revenues of $1 million in the first quarter of 2014 related to reductions in retail kWh sales due to energy efficiency programs and distributed generation implemented in 2013. See Note 3. UNS Electric estimates that it will record total LFCR revenues of approximately $2 million during 2014; and

• a Transmission Cost Adjustment Mechanism (TCA) that will allow more timely recovery of transmission costs associated with serving retail customers at the level approved by FERC. UNS Electric's approved Base Rates include a transmission component based on UNS Electric’s current FERC Open Access Transmission Tariff (OATT) rate. The OATT rates are adjusted annually and the TCA will be limited to the recovery (or refund) of costs associated with future changes in UNS Electric’s OATT rate. UNS Electric expects to make an informational TCA filing with the ACC on or before May 1, 2014. The filing will include an updated retail transmission rate calculated pursuant to UNS Electric's OATT rate. UNS Electric expects the new TCA rate to be effective in June 2014.

Gila River Generating Station Unit 3

In December 2013, TEP and UNS Electric entered into an agreement to purchase Gila River Unit 3 for $219 million. It is anticipated that TEP will purchase a 75% undivided interest in Gila River Unit 3 (413 MW) for approximately $164 million and UNS Electric will purchase the remaining 25% undivided interest (137 MW) for approximately $55 million, although TEP and UNS Electric may modify the percentage ownership allocation between them. We expect the transaction to close in December 2014. See Tucson Electric Power, Factors Affecting Results of Operations, Gila River Generating Station Unit 3 and Note 7.

Also in December 2013, UNS Electric filed an application requesting the ACC to approve an accounting order that would authorize UNS Electric to defer for future recovery specific non-fuel operating costs associated with Gila River Unit 3. If UNS Electric purchases 25% of Gila River Unit 3, the deferred costs, including depreciation, amortization, property taxes, O&M expense and a carrying cost on UNS Electric's investment in Gila River Unit 3, are expected to total approximately $9 million annually. We cannot predict if the ACC will approve UNS Electric's request.

Fair Value Measurements

See Note 12.

LIQUIDITY AND CAPITAL RESOURCES

Liquidity Outlook

UNS Electric expects operating cash flows to fund a portion of its construction expenditures during 2014. Additional sources of funding capital expenditures could include draws on the UNS Electric/UNS Gas Revolver, additional credit lines, the issuance of long-term debt, or capital contributions from UNS Energy.

48

Cash Flows and Capital Expenditures

The table below provides summary cash flow information for UNS Electric:

	Three Months Ended March 31,
	2014			2013
	Millions of Dollars
Cash Provided By (Used In):
Operating Activities	$	10		$	8
Investing Activities	(12		)	(16		)
Financing Activities	3			7
Net Increase/(Decrease) in Cash	1			(1		)
Beginning Cash	5			8
Ending Cash	$	6		$	7

Operating Activities

Cash provided by operating activities increased by $2 million in the first three months of 2014 when compared with the same period last year due primarily to a Base Rate increase that was effective on January 1, 2014.

Investing Activities

UNS Electric had capital expenditures of $12 million in the first quarter of 2014 compared with $15 million in the first quarter of 2013. The decrease is related to the completion of construction of a transmission line in 2013 to increase reliability to UNS Electric's service territory in Nogales, Arizona.

Financing Activities

Cash provided by financing activities at UNS Electric in the first three months of 2014 decreased by $4 million when compared with the same period last year. Financing activities in the first three months of 2014 included $3 million of borrowings under the UNS Electric/UNS Gas Revolver (net of repayments) whereas activity in the same period last year included $5 million of borrowings under the UNS Electric/UNS Gas Revolver (net of repayments) and a $2 million receipt related to a contribution in aid of construction from a large customer.

UNS Electric/UNS Gas Credit Agreement

The UNS Electric/UNS Gas Credit Agreement consists of a $100 million unsecured revolving credit and revolving LOC facility. Either company can borrow up to a maximum of $70 million as long as the combined amount borrowed does not exceed $100 million. The UNS Electric/UNS Gas Credit Agreement expires November 2016.

UNS Electric is only liable for UNS Electric’s borrowings, and similarly, UNS Gas is only liable for UNS Gas' borrowings under the UNS Electric/UNS Gas Credit Agreement.

The UNS Electric/UNS Gas Credit Agreement restricts additional indebtedness, liens, and mergers. It also requires each borrower not to exceed a maximum leverage ratio. Each borrower may pay dividends so long as it maintains compliance with the agreement. At March 31, 2014, UNS Electric and UNS Gas each were in compliance with the terms of the UNS Electric/UNS Gas Credit Agreement.

UNS Electric expects to draw upon the UNS Electric/UNS Gas Revolver from time to time for seasonal working capital purposes, to fund a portion of its capital expenditures or to issue LOCs to provide credit enhancement for its energy procurement and hedging activities. At March 31, 2014, UNS Electric had $25 million of outstanding borrowings and less than $1 million of LOCs issued under the UNS Electric/UNS Gas Credit Agreement.

Contractual Obligations

There are no changes in UNS Electric's contractual obligations or other commercial commitments from those reported in our 2013 Annual Report on Form 10-K, other than the following changes in 2014:

• UNS Electric entered into new forward purchased power commitments with minimum payment obligations of $8 million in 2015. See Note 6.

49

Dividends on Common Stock

UNS Electric did not pay any dividends to UNS Energy, through UES, in first quarters of 2014 and 2013. UNS Electric’s ability to pay future dividends will depend on the cash needs for capital expenditures and various other factors.

The note purchase agreement for UNS Electric contains restrictions on dividends. UNS Electric may pay dividends so long as 1) no default or event of default exists, and 2) it could incur additional debt under the debt incurrence test. At March 31, 2014, UNS Electric was in compliance with the terms of its note purchase agreement and the terms of the UNS Electric/UNS Gas Revolver.

UNS GAS

RESULTS OF OPERATIONS

UNS Gas reported net income of $5 million in the first quarter of 2014 compared with $8 million in the first quarter of 2013. Mild weather during the first quarter of 2014 led to lower retail sales volumes and retail margin revenues.

The table below provides summary financial information for UNS Gas:

	Three Months Ended March 31,
	2014			2013
	Millions of Dollars
Gas Revenues	$	39		$	51
Other Revenues	2			1
Total Operating Revenues	41			52
Purchased Gas Expense	30			30
Increase (Decrease) to Reflect PGA Recovery Treatment	(8		)	(1		)
O&M	6			6
Depreciation and Amortization	2			2
Taxes Other Than Income Taxes	1			1
Total Operating Expenses	31			38
Operating Income	10			14
Interest Expense	2			2
Income Tax Expense	3			4
Net Income	$	5		$	8

50

The table below includes UNS Gas' therm sales and margin revenues:

	Three Months Ended March 31,				Increase (Decrease)
	2014		2013		Amount			Percent(1)
Gas Retail Sales, Therms (in Millions):
Residential	27		35		(8		)	(22.9	)%
Commercial	10		11		(1		)	(9.1	)%
All Other	3		4		(1		)	(25.0	)%
Total Gas Retail Sales	40		50		(10		)	(20.0	)%
Negotiated Sales Program (NSP)	5		7		(2		)	(28.6	)%
Total Gas Sales	45		57		(12		)	(21.1	)%
Retail Margin Revenues (in Millions):
Residential	$	13	$	16	$	(3	)	(18.8	)%
Commercial	3		4		(1		)	(25.0	)%
All Other	1		1		—			—	%
Total Retail Margin Revenues (Non-GAAP)(2)	17		21		(4		)	(19.0	)%
Transport and NSP	4		4		—			—	%
Retail Fuel Revenues	18		26		(8		)	(30.8	)%
Total Gas Revenues (GAAP)	$	39	$	51	$	(12	)	(23.5	)%
Weather Data:
Heating Degree Days
Three Months Ended March 31,	1,722		2,188		(466		)	(21.3	)%
10-Year Average	2,110		2,096		NM			NM

⁽¹⁾  Percent change calculated on un-rounded data and may not correspond exactly to data shown in table.

⁽²⁾  Total Retail Margin Revenues, a non-GAAP financial measure, should not be considered as an alternative to Total Gas Revenues, which is determined in accordance with GAAP. Total Retail Margin Revenues excludes revenues collected from retail customers that are directly offset by expenses recorded in other line items. We believe the change in Total Retail Margin Revenues between periods provides useful information to investors because it demonstrates the underlying revenue trend and performance of our core utility business. Total Retail Margin Revenues represents the portion of retail operating revenues available to cover the non-fuel operating expenses of our core utility business.

Retail therm sales in the first quarter of 2014 decreased by 20.0% when compared with the first quarter of 2013 due to a 21.3% decrease in Heating Degree Days. The decrease in retail therm sales contributed to a decrease in retail margin revenues of 19.0%, or $4 million, when compared with the first quarter of 2013.

FACTORS AFFECTING RESULTS OF OPERATIONS

Fair Value Measurements

See Note 12.

LIQUIDITY AND CAPITAL RESOURCES

Liquidity Outlook

UNS Gas expects operating cash flows to fund all of its construction expenditures during 2014. If natural gas prices rise and UNS Gas is not allowed to recover its projected gas costs or PGA bank balance on a timely basis, UNS Gas may require additional funding to meet operating and capital requirements in future periods. Sources of funding future capital expenditures could include existing cash balances, draws on the UNS Electric/UNS Gas Revolver, additional credit lines, the issuance of long-term debt, or capital contributions from UNS Energy.

Cash Flows and Capital Expenditures

51

The table below provides summary cash flow information for UNS Gas:

	Three Months Ended March 31,
	2014			2013
	Millions of Dollars
Cash Provided By (Used In):
Operating Activities	$	2		$	13
Investing Activities	(4		)	(4		)
Financing Activities	(10		)	(10		)
Net Decrease in Cash	(12		)	(1		)
Beginning Cash	33			31
Ending Cash	$	21		$	30

UNS Gas' operating cash flows during the first quarter of 2014 were $11 million lower than the first quarter of 2013 due in part to the return of the over-collected PGA balance to customers and lower retail therm sales.

UNS Electric/UNS Gas Credit Agreement

At March 31, 2014, UNS Gas had no outstanding borrowings under the UNS Electric/UNS Gas Credit Agreement.

See UNS Electric, Liquidity and Capital Resources, UNS Electric/UNS Gas Credit Agreement.

Interest Rate Risk

See Item 3. Quantitative and Qualitative Disclosures about Market Risk.

Contractual Obligations

There are no changes in UNS Gas' contractual obligations or other commercial commitments from those reported in our 2013 Annual Report on Form 10-K, other than the following changes in 2014:

• UNS Gas entered into new forward energy commitments with minimum payment obligations of $1 million in 2015. See Note 6.

Dividends on Common Stock

UNS Gas paid dividends to UNS Energy, through UES, of $10 million in the first quarters of 2014 and 2013. UNS Gas’ ability to pay future dividends will depend on the cash needs for capital expenditures and various other factors.

The note purchase agreement for UNS Gas contains restrictions on dividends. UNS Gas may pay dividends so long as 1) no default or event of default exists, and 2) it could incur additional debt under the debt incurrence test. At March 31, 2014, UNS Gas was in compliance with the terms of its note purchase agreement and had sufficient additional debt under the debt incurrence test to pay dividends.

52

CRITICAL ACCOUNTING POLICIES

There have been no significant changes in our accounting policies from those disclosed in our 2013 Annual Report on Form 10-K.

RECENTLY ISSUED ACCOUNTING PRONOUNCEMENTS

In April 2014, the Financial Accounting Standards Board (FASB) issued an accounting standards update that changes the threshold for reporting discontinued operations and adds new disclosures. This guidance will be effective in the first quarter of 2015. We are evaluating the impact to our financial statements and disclosures.

SAFE HARBOR FOR FORWARD-LOOKING STATEMENTS

This Quarterly Report on Form 10-Q contains forward-looking statements as defined by the Private Securities Litigation Reform Act of 1995. UNS Energy and TEP are including the following cautionary statements to make applicable and take advantage of the safe harbor provisions of the Private Securities Litigation Reform Act of 1995 for any forward-looking statements made by or for UNS Energy or TEP in this Quarterly Report on Form 10-Q. Forward-looking statements include statements concerning plans, objectives, goals, strategies, future events or performance and underlying assumptions, and other statements that are not statements of historical facts. Forward-looking statements may be identified by the use of words such as anticipates, estimates, expects, intends, plans, predicts, projects, and similar expressions. From time to time, we may publish or otherwise make available forward-looking statements of this nature. All such forward-looking statements, whether written or oral, and whether made by or on behalf of UNS Energy or TEP, are expressly qualified by these cautionary statements and any other cautionary statements which may accompany the forward-looking statements. In addition, UNS Energy and TEP disclaim any obligation to update any forward-looking statements to reflect events or circumstances after the date of this report.

Forward-looking statements involve risks and uncertainties, which could cause actual results or outcomes to differ materially from those expressed therein. We express our expectations, beliefs, and projections in good faith and believe them to have a reasonable basis. However, we make no assurances that management’s expectations, beliefs or projections will be achieved or accomplished. We have identified the following important factors that could cause actual results to differ materially from those discussed in our forward-looking statements. These may be in addition to other factors and matters discussed in: Part II, Item 1A. Risk Factors; Part I, Item 2. Management’s Discussion and Analysis; and other parts of this report. These factors include: state and federal regulatory and legislative decisions and actions; regional economic and market conditions which could affect customer growth and energy usage; weather variations affecting energy usage; the cost of debt and equity capital and access to capital markets; the performance of the stock market and changing interest rate environment, which affect the value of our pension and other retiree benefit plan assets and the related contribution requirements and expense; unexpected increases in O&M expense; resolution of pending litigation matters; changes in accounting standards; changes in critical accounting estimates; the ongoing restructuring of the electric industry; changes to long-term contracts; the cost of fuel and power supplies; cyber attacks or challenges to our information security; and the performance of TEP's generating plants.

ITEM 3. – QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK

UNS Energy’s and TEP’s primary market risks include fluctuations in interest rates, commodity prices and volumes, and counterparty credit. Fluctuations in interest rates can affect earnings and cash flows. We enter into interest rate swaps and financing transactions to manage changes in interest rates. Fluctuations in commodity prices and volumes and counterparty credit losses may temporarily affect cash flows, but are not expected to affect earnings due to expected recovery through regulatory mechanisms.

There have been no additional risks and no material changes to market risks disclosed in Part II, Item 3 in our Annual Report on Form 10-K for the year ended December 31, 2013.

53

ITEM 4. – CONTROLS AND PROCEDURES

UNS Energy’s and TEP’s Chief Executive Officer and Chief Financial Officer supervised and participated in UNS Energy’s and TEP’s evaluation of their disclosure controls and procedures as such term is defined under Rule 13a – 15(e) or Rule 15d – 15(e) under the Securities Exchange Act of 1934, as amended (the Exchange Act), as of the end of the period covered by this report. Disclosure controls and procedures are controls and procedures designed to ensure that information required to be disclosed in UNS Energy’s and TEP’s periodic reports filed or submitted under the Exchange Act, is recorded, processed, summarized, and reported within the time periods specified in the Securities and Exchange Commission’s rules and forms. These disclosure controls and procedures are also designed to ensure that information required to be disclosed by UNS Energy and TEP in the reports that they file or submit under the Exchange Act is accumulated and communicated to management, including the principal executive and principal financial officers, or person performing similar functions, as appropriate to allow timely decisions regarding required disclosure. Based upon the evaluation performed, UNS Energy’s and TEP’s Chief Executive Officer and Chief Financial Officer concluded that UNS Energy’s and TEP’s disclosure controls and procedures are effective.

While UNS Energy and TEP continually strive to improve their disclosure controls and procedures to enhance the quality of their financial reporting, there has been no change in UNS Energy’s or TEP’s internal control over financial reporting during the first quarter of 2014 that has materially affected, or is reasonably likely to materially affect, UNS Energy’s or TEP’s internal control over financial reporting.

54

PART II - OTHER INFORMATION

ITEM 1. – LEGAL PROCEEDINGS

See the legal proceedings described in Item 3. – Legal Proceedings in our 2013 Annual Report on Form 10-K and in Note 6 and in Item 2. – Management’s Discussion and Analysis of Financial Condition and Results of Operations, which descriptions in Note 6 and Item 2 are incorporated herein by reference.

Shareholder Lawsuits

Five putative shareholder class action lawsuits challenging the merger have been filed, four in the Superior Court of Pima County, Arizona: (i) Phillip Malenovshy v. UNS Energy Corporation, et al. (Case No. C20136942); (ii) Paul Parshall v. UNS Energy Corporation, et al. (Case No. C20136943); (iii) Hillary Kramer v. Paul J. Bonavia, et al. (Case No. C2014-0026); and (iv) Vandermeer Trust U/A DTD 03/11/1997 v. UNS Energy Corporation, et al. (Case No. C2014-0107); and one in federal court in the United States District Court for the District of Arizona: Milton Pfeiffer v. Paul J. Bonavia, et al. (Case No. 4:13-CV-02619-JGZ).

The lawsuits generally allege, among other things, that the directors of UNS Energy breached their fiduciary duties to shareholders of UNS Energy purportedly by agreeing to a transaction pursuant to an inadequate process and for failing to obtain the highest value for UNS Energy shareholders. The lawsuits allege that the Fortis entities also aided and abetted the directors of UNS Energy in the alleged breach of their fiduciary duties.

The lawsuits seek, in general, and among other things, (i) injunctive relief enjoining the transactions contemplated by the merger agreement, (ii) rescission or an award of rescissory damages in the event a merger is consummated, (iii) an award of plaintiffs’ costs including reasonable attorneys’ and experts’ fees, (iv) an accounting by the defendants to plaintiffs for all damages caused by the defendants, and (v) such further relief as the court deems just and proper.

On March 13, 2014, plaintiffs Malenovshy and Parshall voluntarily dismissed their cases.

On March 18, 2014, solely to avoid the costs, risks and uncertainties inherent in litigation, UNS Energy and the other named defendants signed a memorandum of understanding (“MOU”) with the remaining plaintiffs in the consolidated shareholder class action lawsuits filed in the Superior Court of Pima County, Arizona. This MOU provides, among other things, that the parties will seek to enter into a stipulation of settlement which provides for the release of all asserted claims. The asserted claims will not be released until such stipulation of settlement is approved by the court. There can be no assurance that the court will approve such settlement. Additionally, as part of the MOU, UNS Energy and Fortis agreed to make certain additional disclosures related to the proposed merger, which are set forth in a Form 8-K filed with the SEC on March 19, 2014. Finally, in connection with the proposed settlement, counsel for plaintiffs intend to seek an award of attorneys’ fees and expenses, subject to court approval. Nothing in this Report on Form 10-Q, the MOU or any stipulation of settlement shall be deemed an admission of the legal necessity or materiality under applicable laws of any of the disclosure set forth herein.

On April 15, 2014, plaintiff Pfeiffer voluntarily dismissed his case.

ITEM 1A. – RISK FACTORS

The business and financial results of UNS Energy and TEP are subject to numerous risks and uncertainties. There are no significant changes to the risks and uncertainties reported in our 2013 Annual Report on Form 10-K.

55

ITEM 5. – OTHER INFORMATION

RATIO OF EARNINGS TO FIXED CHARGES

The following table reflects the ratio of earnings to fixed charges for UNS Energy and TEP:

	Three Months Ended March 31, 2014	Twelve Months Ended March 31, 2014
UNS Energy	1.901	2.815
TEP	1.561	2.789

For purposes of this computation, earnings are defined as pre-tax earnings plus interest expense and amortization of debt discount and expense. Fixed charges are interest expense, including amortization of debt discount and expense.

ENVIRONMENTAL MATTERS

See Note 6.

Hazardous Air Pollutant Requirements

The Clean Air Act requires the EPA to develop emission limit standards for hazardous air pollutants that reflect the maximum achievable control technology. In February 2012, the EPA issued final rules to set the standards for the control of mercury emissions and other hazardous air pollutants from power plants (MATS rules).

Navajo

Based on the MATS rules, Navajo may require mercury and particulate matter emission control equipment by April 2016. TEP’s share of the estimated capital cost of this equipment is less than $1 million for mercury control and about $43 million if the installation of baghouses to control particulates is necessary. The operator of Navajo is currently analyzing the need for baghouses under various regulatory scenarios, which will be affected by final Best Available Retrofit Technology (BART) rules when issued. TEP expects its share of the annual operating costs for mercury control and baghouses to be less than $1 million each.

San Juan

TEP expects San Juan’s current emission controls to be adequate to comply with the MATS rules.

Four Corners

Based on the MATS rules, Four Corners may require mercury emission control equipment by April 2015. TEP's share of the estimated capital cost of this equipment is less than $1 million. TEP expects its share of the annual operating cost of the mercury emission control equipment to be less than $1 million.

Springerville Generating Station

Based on the MATS rules, Springerville Generating Station (Springerville) may require mercury emission control equipment by April 2015. The estimated capital cost of this equipment for Springerville Units 1 and 2 is about $5 million. TEP expects the annual operating cost of the mercury emission control equipment to be about $3 million. TEP will own 49.5% of Springerville Unit 1 upon close of the lease option purchases by early 2015; after the completion of such purchases, third party owners will be responsible for 50.5% of environmental costs attributed to Springerville Unit 1.

Sundt Generating Station

TEP expects the MATS rules will have little effect on capital expenditures at Sundt.

Regional Haze Rules

The EPA's Regional Haze Rules require emission controls known as BART for certain industrial facilities emitting air pollutants that reduce visibility in national parks and wilderness areas. The rules call for all states to establish goals and emission reduction strategies for improving visibility. States must submit these goals and strategies to the EPA for approval. BART applies to plants built between August 1962 and August 1977. Because Navajo and Four Corners are located on the

56

Navajo Indian Reservation, they are not subject to state oversight; the EPA oversees regional haze planning for these power plants.

Complying with the EPA’s BART findings, and with other future environmental rules, may make it economically impractical to continue operating the Navajo, San Juan, and Four Corners power plants or for individual owners to continue to participate in these power plants. TEP cannot predict the ultimate outcome of these matters.

Navajo

In January 2013, the EPA proposed a BART determination that would require the installation of Selective Catalytic Reduction (SCR) technology on all three units at Navajo by 2023. In July 2013, SRP, along with other stakeholders including impacted government agencies, environmental organizations, and tribal representatives, submitted an agreement to the EPA that would achieve greater NOx emission reductions than the EPA's proposed BART rule. In September 2013, the EPA issued a supplemental proposal incorporating the provisions of the agreement as a better-than-BART alternative.

Among other things, the agreement calls for the shut-down of one unit or an equivalent reduction in emissions by 2020. The shutdown of one unit will not impact the total amount of energy delivered to TEP from Navajo. Additionally, the remaining Navajo participants would be required to install SCR or an equivalent technology on the remaining two units by 2030. As part of the agreement, the current owners have committed to cease their operation of conventional coal-fired generation at Navajo no later than December 2044. The Navajo Nation can continue operation after 2044 at its election. If SCR technology is ultimately implemented at Navajo, TEP estimates its share of the capital cost will be $42 million. Also, the installation of SCR technology at Navajo could increase the power plant's particulate emissions which may require that baghouses be installed. TEP estimates that its share of the capital expenditure for baghouses would be about $43 million. TEP's share of annual operating costs for SCR and baghouses is estimated at less than $1 million each. The EPA could issue their decision as early as 2014.

San Juan

In August 2011, the EPA issued a Federal Implementation Plan (FIP) establishing new emission limits for air pollutants at San Juan. These requirements are more stringent than those proposed by the State of New Mexico. The FIP requires the installation of SCR technology with sorbent injection on all four units to reduce NOx and control sulfuric acid emissions by September 2016. TEP estimates its share of the cost to install SCR technology with sorbent injection to be between $180 million and $200 million. TEP expects its share of the annual operating costs for SCR technology to be approximately $6 million.

In 2011, PNM filed a petition for review of, and a motion to stay, the FIP with the United States Court of Appeals for the Tenth Circuit (Tenth Circuit). In addition, the operator filed a request for reconsideration of the rule with the EPA and a request to stay the effectiveness of the rule pending the EPA's reconsideration and review by the Tenth Circuit. The State of New Mexico filed similar motions with the Tenth Circuit and the EPA. Several environmental groups were granted permission to join in opposition to PNM's petition to review in the Tenth Circuit. In addition, WildEarth Guardians filed a separate appeal against the EPA challenging the FIP's five-year implementation schedule. PNM was granted permission to join in opposition to that appeal. In March 2012, the Tenth Circuit denied PNM's and the State of New Mexico's motion for stay. Oral argument on the appeal was heard in October 2012.

In February 2013, the State of New Mexico, the EPA, and PNM signed a non-binding agreement (Settlement Agreement) that outlines an alternative to the FIP. The terms of the Settlement Agreement include: the retirement of San Juan Units 2 and 3 by December 31, 2017; the replacement by PNM of those units with non-coal generation sources; and the installation of SNCR on San Juan Units 1 and 4 by January 2016 or later depending on the timing of EPA approvals. The New Mexico Environmental Department (NMED) prepared a revision to the regional haze State Implementation Plan (SIP) incorporating the provisions of the Settlement Agreement, and in September 2013, the New Mexico Environmental Improvement Board approved the SIP revision. The SIP revision now awaits final EPA approval. The EPA is expected to issue a final BART determination in 2014.  TEP estimates its share of the cost to install SNCR technology on San Juan Unit 1 would be approximately $35 million. TEP's share of incremental annual operating costs for SNCR is estimated at $1 million. TEP owns 340 MW, or 50%, of San Juan Units 1 and 2. If San Juan Unit 2 is retired, TEP's coal-fired generating capacity would be reduced by 170 MW.

In connection with the implementation of the SIP revision and the retirement of San Juan Units 2 and 3, some of the San Juan owner participants (Participants) have expressed a desire to exit their ownership in the plant. As a result, the Participants are attempting to negotiate a restructuring of the ownership in San Juan, as well as addressing the obligations of the exiting Participants for plant decommissioning, mine reclamation, environmental matters, and certain ongoing operating costs, among other items. The Participants have engaged a mediator to assist in facilitating the resolution of these matters among the owners. The owners of the affected units also may seek approvals of their utility commissions or governing boards. We are unable to predict the outcome of the negotiations and mediation.

57

On October 17, 2013, the Tenth Circuit ruled on a motion filed by PNM for abatement of the pending petitions for review and seeking deferral of briefing on a simultaneously-filed motion to stay the FIP. The Tenth Circuit placed the pending petitions for review in abeyance and set a schedule for the parties to file status reports. The court ruled that, if at any time the Settlement Agreement is not implemented as contemplated, any party to the litigation may file a motion seeking to lift the abatement.

At March 31, 2014, the book value of TEP's share of San Juan Unit 2 was$112 million. If Unit 2 is retired early, we expect to request ACC approval to recover, over a reasonable time period, all costs associated with the early closure of the unit. TEP cannot predict the ultimate outcome of this matter.

Four Corners

In 2012, the EPA finalized the regional haze FIP for Four Corners. The final FIP requires SCR technology to be installed on all five units by 2017. In December 2013, APS (the operator) decided to shut down Units 1, 2, and 3 and install SCRs on Units 4 and 5. Under this scenario, the installation of SCR technology can be delayed until July 2018. TEP's estimated share of the capital costs to install SCR technology on Units 4 and 5 is approximately $35 million. TEP's share of incremental annual operating costs for SCR is estimated at $2 million.

Springerville

The BART provisions of the Regional Haze Rules requiring emission control upgrades do not apply to Springerville Units 1 and 2 since they were constructed in the 1980s which is after the time frame as designated by the rules. Other provisions of the Regional Haze Rules requiring further emission reduction are not likely to impact Springerville operations until after 2018.

Sundt

In July 2013, the EPA rejected the Arizona state implementation plan determination that Sundt Unit 4 is not subject to the BART provisions of the Regional Haze Rule and developed a timeline to issue a federal implementation plan for emissions sources including Sundt Unit 4. While TEP does not agree that Sundt Unit 4 is subject to BART, it submitted a better-than-BART proposal in November 2013 which called for the elimination of coal as a fuel source at Sundt by the end of 2017. In January 2014, the EPA issued a BART proposal that would require TEP to either (i) install, by mid-2017, SNCR and dry sorbent injection if Sundt Unit 4 continues to use coal as a fuel source, or (ii) permanently eliminate coal as a fuel source as a better-than-BART alternative by the end of 2017. TEP estimates that the cost to install SNCR and DSI would be approximately $12 million, and the incremental annual operating costs would be $5 million to $6 million. Under the proposal, TEP would be required to notify the EPA of its decision by July 31, 2015. The EPA is expected to issue a final BART determination by July 2014. At March 31, 2014, the net book value of the Sundt coal handling facilities was $27 million. If the coal handling facilities are retired early, we expect to request ACC approval to recover, over a reasonable time period, all the remaining costs of the coal handling facilities.

Greenhouse Gas Regulation

In June 2013, President Obama directed the EPA to move forward with carbon emission regulations for both new and existing fossil-fueled power plants.

In January 2014, the EPA published a re-proposed rule for new power plants. UNS Energy does not anticipate that a final rule related to new fossil-fueled power plant sources will have a significant impact on operations.

For existing power plants, the President ordered the EPA to:

• propose carbon emission standards by June 1, 2014;

• finalize those standards by June 1, 2015; and

• require states to submit their implementation plans to meet the standards by June 30, 2016.

UNS Energy will continue to work with federal and state regulatory agencies to promote compliance flexibility in the rules impacting existing fossil-fuel fired power plants. We cannot predict the ultimate outcome of these matters.

ITEM 6. – EXHIBITS

See Exhibit Index.

58

SIGNATURES

Pursuant to the requirements of the Securities Exchange Act of 1934, each registrant has duly caused this report to be signed on its behalf by the undersigned thereunto duly authorized. The signature for each undersigned company shall be deemed to relate only to matters having reference to such company or its subsidiaries.

		UNS ENERGY CORPORATION
		(Registrant)
Date:	April 28, 2014	/s/ Kevin P. Larson
		Kevin P. Larson
		Senior Vice President and Chief
		Financial Officer
		TUCSON ELECTRIC POWER COMPANY
		(Registrant)
Date:	April 28, 2014	/s/ Kevin P. Larson
		Kevin P. Larson
		Senior Vice President and Chief
		Financial Officer

59

EXHIBIT INDEX

12(a)	—	Computation of Ratio of Earnings to Fixed Charges – UNS Energy.
12(b)	—	Computation of Ratio of Earnings to Fixed Charges – TEP.
31(a)	—	Certification Pursuant to Section 302 of the Sarbanes-Oxley Act – UNS Energy, by Paul J. Bonavia.
31(b)	—	Certification Pursuant to Section 302 of the Sarbanes-Oxley Act – UNS Energy, by Kevin P. Larson.
31(c)	—	Certification Pursuant to Section 302 of the Sarbanes-Oxley Act – TEP, by Paul J. Bonavia.
31(d)	—	Certification Pursuant to Section 302 of the Sarbanes-Oxley Act – TEP, by Kevin P. Larson.
**32(a)	—	Statements of Corporate Officers (pursuant to Section 906 of the Sarbanes-Oxley Act of 2002) - UNS Energy.
**32(b)	—	Statements of Corporate Officers (pursuant to Section 906 of the Sarbanes-Oxley Act of 2002) - TEP.
101	—	The following materials from UNS Energy’s and TEP’s Annual Report on Form 10-K for the fiscal year ended December 31, 2013, formatted in XBRL (Extensible Business Reporting Language):
		(a)	UNS Energy’s and TEP’s (i) Consolidated Statements of Income, (ii) Consolidated Statements of Comprehensive Income (iii) Consolidated Statements of Cash Flows, (iv) Consolidated Balance Sheets, (v) Consolidated Statements of Capitalization, (vi) Consolidated Statements of Changes in Stockholders’ Equity; and
		(b)	Notes to Consolidated Financial Statements.

(*) Previously filed as indicated and incorporated herein by reference.

** Pursuant to Item 601(b)(32)(ii) of Regulation S-K, this certificate is not being “filed” for purposes of Section 18 of the Securities Exchange Act of 1934, as amended.

60